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		September 30, 2021
		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 November 1, 2021:

Sempra Energy	319,337,462 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

2

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	51
	Note 3. Revenues	51
	Note 4. Regulatory Matters	55
	Note 5. Acquisitions, Divestitures and Discontinued Operations	59
	Note 6. Investments in Unconsolidated Entities	60
	Note 7. Debt and Credit Facilities	62
	Note 8. Derivative Financial Instruments	65
	Note 9. Fair Value Measurements	71
	Note 10. San Onofre Nuclear Generating Station	78
	Note 11. Commitments and Contingencies	80
	Note 12. Segment Information	91
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	93
	Overview	94
	Results of Operations	94
	Capital Resources and Liquidity	106
	Critical Accounting Policies and Estimates	121
	New Accounting Standards	121
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	121
Item 4.	Controls and Procedures	122
PART II – OTHER INFORMATION
Item 1.	Legal Proceedings	123
Item 1A.	Risk Factors	123
Item 6.	Exhibits	125
Signatures		128

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 reporting entity makes statements herein only as to itself and its consolidated entities and makes no statement whatsoever as to any other reporting 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. Separate Part I – Item 1 sections are 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
2019 GRC FD	final decision in the California Utilities’ 2019 General Rate Case
AB	California Assembly Bill
AFUDC	allowance for funds used during construction
AMP	Arrearage Management Payment Plan
Annual Report	Annual Report on Form 10-K for the year ended December 31, 2020
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
Bechtel	Bechtel Oil, Gas and Chemicals, Inc.
Blade	Blade Energy Partners
bps	basis points
CalGEM	California Geologic Energy Management Division
California Utilities	San Diego Gas & Electric Company and Southern California Gas Company, collectively
Cameron LNG JV	Cameron LNG Holdings, LLC
CCM	cost of capital adjustment mechanism
CENACE	Centro Nacional de Control de Energía (Mexico’s National Energy Control Center)
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
Chilquinta Energía	Chilquinta Energía S.A. and its subsidiaries
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
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
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.)
Eletrans	Eletrans S.A., Eletrans II S.A. and Eletrans III S.A., collectively
EPC	engineering, procurement and construction
EPS	earnings (losses) per common share
ERCOT	Electric Reliability Council of Texas, Inc., the independent system operator and the regional coordinator of various electricity systems within Texas
ESJ	Energía Sierra Juárez, S. de R.L. de C.V.
ETR	effective income tax rate
FERC	U.S. Federal Energy Regulatory Commission
Fitch	Fitch Ratings, Inc.
FTA	Free Trade Agreement
Gazprom	Gazprom Marketing & Trading México S. de R.L. de C.V.
GRC	General Rate Case
HMRC	Her Majesty’s Revenue and Customs (United Kingdom’s Revenue and Customs Department)
IEnova	Infraestructura Energética Nova, S.A.B. de C.V., renamed Infraestructura Energética Nova, S.A.P.I. de C.V. on November 1, 2021
IMG JV	Infraestructura Marina del Golfo
IOU	investor-owned utility
ISO	Independent System Operator

4

GLOSSARY (CONTINUED)
JV	joint venture
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
LIBOR	London Interbank Offered Rate
LNG	liquefied natural gas
LPG	liquid petroleum gas
Luz del Sur	Luz del Sur S.A.A. and its subsidiaries
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
OIR	Order Instituting a Rulemaking
Oncor	Oncor Electric Delivery Company LLC
Oncor Holdings	Oncor Electric Delivery Holdings Company LLC
OSC	Order to Show Cause
PG&E	Pacific Gas and Electric Company
PP&E	property, plant and equipment
PPA	power purchase agreement
PSEP	Pipeline Safety Enhancement Plan
PUCT	Public Utility Commission of Texas
PXiSE	PXiSE Energy Solutions, LLC
RBS	The Royal Bank of Scotland plc
RBS SEE	RBS Sempra Energy Europe
RBS Sempra Commodities	RBS Sempra Commodities LLP
ROE	return on equity
ROU	right-of-use
RSU	restricted stock unit
S&P	S&P Global Ratings
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
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 Global	holding company for most of Sempra’s subsidiaries not subject to California or Texas utility regulation, renamed Sempra Infrastructure Partners on September 30, 2021
SENER	Secretaría de Energía de México (Mexico’s Ministry of Energy)
series A preferred stock	Sempra’s 6% mandatory convertible preferred stock, series A

5

GLOSSARY (CONTINUED)
series B preferred stock	Sempra’s 6.75% mandatory convertible preferred stock, series B
series C preferred stock	Sempra’s 4.875% fixed-rate reset cumulative redeemable perpetual preferred stock, series C
Shell Mexico	Shell México Gas Natural, S. de R.L. de C.V.
SoCalGas	Southern California Gas Company
SONGS	San Onofre Nuclear Generating Station
Support Agreement	support agreement, dated July 28, 2020 and amended on June 29, 2021, among Sempra and Sumitomo Mitsui Banking Corporation
TAG JV	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.
Tecnored	Tecnored S.A.
Tecsur	Tecsur S.A.
TO4	Electric Transmission Owner Formula Rate, effective through May 31, 2019
TO5	Electric Transmission Owner Formula Rate, effective June 1, 2019
TTI	Texas Transmission Investment LLC
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

6

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 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,” “anticipates,” “plans,” “estimates,” “projects,” “forecasts,” “should,” “could,” “would,” “will,” “confident,” “may,” “can,” “potential,” “possible,” “proposed,” “in process,” “under construction,” “in development,” “target,” “outlook,” “maintain,” “continue,” “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 described in any forward-looking statements 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 costs from insurance, the Wildfire Fund or in rates from customers

▪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) states, counties, cities and other jurisdictions in the U.S., Mexico and other countries in which we do business

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

▪the resolution of civil and criminal litigation, regulatory inquiries, investigations and proceedings, and arbitrations, including those related to the Leak

▪changes to laws, including proposed changes to the Mexican constitution that could materially limit access to the electric generation market and changes to Mexico’s trade rules that could materially limit our ability to import and export hydrocarbons

▪failure of foreign governments and state-owned entities to honor their contracts and commitments and property disputes

▪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 substantial debt service obligations

▪the impact of energy and climate goals, policies, legislation and rulemaking, 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

▪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 business

▪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 property damage or personal injuries, fines and penalties, some of which may not be covered by insurance, may be disputed by insurers or may otherwise not be recoverable through regulatory mechanisms or may impact our ability to obtain satisfactory levels of affordable insurance

▪the availability of electric power and 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

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

▪cybersecurity threats 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-party vendors and other parties with which we conduct business

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

7

▪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

▪volatility in foreign currency exchange, inflation and interest rates and commodity prices and our ability to effectively hedge these risks and with respect to interest rates, the impact on the California Utilities’ cost of capital

▪changes in tax and trade policies, laws and regulations, including tariffs and revisions to international trade agreements that may increase our costs, reduce our competitiveness, or impair our ability to resolve trade disputes

▪other uncertainties, some of which may be difficult to predict and are 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 September 30,				Nine months ended September 30,
	2021		2020		2021		2020
	(unaudited)
REVENUES
Utilities	$	2,560	$	2,301	$	7,839	$	7,199
Energy-related businesses	453		343		1,174		1,000
Total revenues	3,013		2,644		9,013		8,199
EXPENSES AND OTHER INCOME
Utilities:
Cost of natural gas	(282)		(114)		(892)		(582)
Cost of electric fuel and purchased power	(312)		(429)		(828)		(918)
Energy-related businesses cost of sales	(220)		(90)		(448)		(200)
Operation and maintenance	(1,073)		(1,018)		(3,098)		(2,767)
Aliso Canyon litigation and regulatory matters	(1,571)		(27)		(1,571)		(127)
Depreciation and amortization	(471)		(418)		(1,376)		(1,242)
Franchise fees and other taxes	(151)		(139)		(442)		(397)
Other (expense) income, net	(55)		29		52		(163)
Interest income	16		27		50		76
Interest expense	(259)		(264)		(776)		(818)
(Loss) income from continuing operations before income taxes and equity earnings	(1,365)		201		(316)		1,061
Income tax benefit (expense)	342		(99)		45		(60)
Equity earnings	391		326		1,022		822
(Loss) income from continuing operations, net of income tax	(632)		428		751		1,823
(Loss) income from discontinued operations, net of income tax	—		(7)		—		1,850
Net (loss) income	(632)		421		751		3,673
Earnings attributable to noncontrolling interests	(5)		(22)		(48)		(201)
Preferred dividends	(11)		(48)		(52)		(121)
Preferred dividends of subsidiary	—		—		(1)		(1)
(Losses) earnings attributable to common shares	$	(648)	$	351	$	650	$	3,350
Basic EPS:
(Losses) earnings from continuing operations	$	(2.03)	$	1.23	$	2.10	$	5.17
(Losses) earnings from discontinued operations	$	—	$	(0.02)	$	—	$	6.31
(Losses) earnings	$	(2.03)	$	1.21	$	2.10	$	11.48
Weighted-average common shares outstanding	319,144		289,490		309,350		291,771
Diluted EPS:
(Losses) earnings from continuing operations	$	(2.03)	$	1.23	$	2.09	$	5.15
(Losses) earnings from discontinued operations	$	—	$	(0.02)	$	—	$	6.28
(Losses) earnings	$	(2.03)	$	1.21	$	2.09	$	11.43
Weighted-average common shares outstanding	319,144		290,582		310,854		292,935

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  benefit (expense)		Net-of-tax amount		Noncontrolling interests (after tax)		Total
	(unaudited)
	Three months ended September 30, 2021 and 2020
2021:
Net (loss) income	$	(979)	$	342	$	(637)	$	5	$	(632)
Other comprehensive income (loss):
Foreign currency translation adjustments	(4)		—		(4)		(2)		(6)
Financial instruments	38		(9)		29		—		29
Pension and other postretirement benefits	(7)		2		(5)		—		(5)
Total other comprehensive income (loss)	27		(7)		20		(2)		18
Comprehensive (loss) income	$	(952)	$	335	$	(617)	$	3	$	(614)
2020:
Net income	$	489	$	(90)	$	399	$	22	$	421
Other comprehensive income (loss):
Foreign currency translation adjustments	9		—		9		(1)		8
Financial instruments	36		(16)		20		5		25
Pension and other postretirement benefits	6		(1)		5		—		5
Total other comprehensive income	51		(17)		34		4		38
Comprehensive income	$	540	$	(107)	$	433	$	26	$	459
	Nine months ended September 30, 2021 and 2020
2021:
Net income	$	658	$	45	$	703	$	48	$	751
Other comprehensive income (loss):
Foreign currency translation adjustments	(4)		—		(4)		(2)		(6)
Financial instruments	145		(36)		109		9		118
Pension and other postretirement benefits	11		(2)		9		—		9
Total other comprehensive income	152		(38)		114		7		121
Comprehensive income	810		7		817		55		872
Preferred dividends of subsidiary	(1)		—		(1)		—		(1)
Comprehensive income, after preferred dividends of subsidiary	$	809	$	7	$	816	$	55	$	871
2020:
Net income	$	4,718	$	(1,246)	$	3,472	$	201	$	3,673
Other comprehensive income (loss):
Foreign currency translation adjustments	533		—		533		(16)		517
Financial instruments	(167)		41		(126)		(9)		(135)
Pension and other postretirement benefits	27		(3)		24		—		24
Total other comprehensive income (loss)	393		38		431		(25)		406
Comprehensive income	5,111		(1,208)		3,903		176		4,079
Preferred dividends of subsidiary	(1)		—		(1)		—		(1)
Comprehensive income, after preferred dividends of subsidiary	$	5,110	$	(1,208)	$	3,902	$	176	$	4,078

See Notes to Condensed Consolidated Financial Statements.    

10

SEMPRA ENERGY
CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	September 30,		December 31,
	2021		2020(1)
	(unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	873	$	960
Restricted cash	31		22
Accounts receivable – trade, net	1,416		1,578
Accounts receivable – other, net	470		403
Due from unconsolidated affiliates	30		20
Income taxes receivable	93		113
Inventories	371		308
Regulatory assets	290		190
Greenhouse gas allowances	546		553
Other current assets	473		364
Total current assets	4,593		4,511
Other assets:
Restricted cash	3		3
Due from unconsolidated affiliates	684		780
Regulatory assets	2,280		1,822
Nuclear decommissioning trusts	1,003		1,019
Investment in Oncor Holdings	12,475		12,440
Other investments	1,483		1,388
Goodwill	1,602		1,602
Other intangible assets	376		202
Dedicated assets in support of certain benefit plans	539		512
Insurance receivable for Aliso Canyon costs	414		445
Deferred income taxes	151		136
Greenhouse gas allowances	356		101
Right-of-use assets – operating leases	499		543
Wildfire fund	342		363
Other long-term assets	914		753
Total other assets	23,121		22,109
Property, plant and equipment:
Property, plant and equipment	57,474		53,928
Less accumulated depreciation and amortization	(14,716)		(13,925)
Property, plant and equipment, net	42,758		40,003
Total assets	$	70,472	$	66,623

(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)
	September 30,		December 31,
	2021		2020(1)
	(unaudited)
LIABILITIES AND EQUITY
Current liabilities:
Short-term debt	$	3,068	$	885
Accounts payable – trade	1,400		1,359
Accounts payable – other	179		154
Due to unconsolidated affiliates	42		45
Dividends and interest payable	592		551
Accrued compensation and benefits	454		446
Regulatory liabilities	515		140
Current portion of long-term debt and finance leases	2,994		1,540
Reserve for Aliso Canyon costs	1,962		150
Greenhouse gas obligations	546		553
Other current liabilities	1,192		1,016
Total current liabilities	12,944		6,839
Long-term debt and finance leases	20,042		21,781
Deferred credits and other liabilities:
Due to unconsolidated affiliates	286		234
Pension and other postretirement benefit plan obligations, net of plan assets	964		1,059
Deferred income taxes	2,882		2,871
Regulatory liabilities	3,378		3,372
Reserve for Aliso Canyon costs	14		301
Greenhouse gas obligations	190		—
Asset retirement obligations	3,187		3,113
Deferred credits and other	1,981		2,119
Total deferred credits and other liabilities	12,882		13,069
Commitments and contingencies (Note 11)
Equity:
Preferred stock (50 million shares authorized):
Mandatory convertible preferred stock, series A (17.25 million shares outstanding at December 31, 2020)	—		1,693
Mandatory convertible preferred stock, series B (5.75 million shares outstanding at December 31, 2020)	—		565
Preferred stock, series C (0.9 million shares outstanding)	889		889
Common stock (750 million shares authorized; 319 million and 288 million shares outstanding at September 30, 2021 and December 31, 2020, respectively; no par value)	10,791		7,053
Retained earnings	13,292		13,673
Accumulated other comprehensive income (loss)	(418)		(500)
Total Sempra Energy shareholders’ equity	24,554		23,373
Preferred stock of subsidiary	20		20
Other noncontrolling interests	30		1,541
Total equity	24,604		24,934
Total liabilities and equity	$	70,472	$	66,623

(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)
	Nine months ended September 30,
	2021		2020
	(unaudited)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	751	$	3,673
Less: Income from discontinued operations, net of income tax	—		(1,850)
Income from continuing operations, net of income tax	751		1,823
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,376		1,242
Deferred income taxes and investment tax credits	(159)		(12)
Equity earnings	(1,022)		(822)
Foreign currency transaction losses, net	10		95
Share-based compensation expense	48		57
Fixed-price contracts and other derivatives	338		25
Other	70		107
Reserve for Aliso Canyon costs	1,525		259
Net change in other working capital components	(186)		(396)
Distributions from investments	727		429
Insurance receivable for Aliso Canyon costs	31		(165)
Changes in other noncurrent assets and liabilities, net	(528)		38
Net cash provided by continuing operations	2,981		2,680
Net cash used in discontinued operations	—		(1,051)
Net cash provided by operating activities	2,981		1,629
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(3,606)		(3,313)
Expenditures for investments and acquisitions	(216)		(229)
Proceeds from sale of assets	—		22
Distributions from investments	365		761
Purchases of nuclear decommissioning trust assets	(729)		(1,091)
Proceeds from sales of nuclear decommissioning trust assets	729		1,091
Advances to unconsolidated affiliates	(8)		(32)
Repayments of advances to unconsolidated affiliates	—		7
Other	9		13
Net cash used in continuing operations	(3,456)		(2,771)
Net cash provided by discontinued operations	—		5,186
Net cash (used in) provided by investing activities	(3,456)		2,415

See Notes to Condensed Consolidated Financial Statements.

13

SEMPRA ENERGY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (CONTINUED)
(Dollars in millions)
	Nine months ended September 30,
	2021		2020
	(unaudited)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	$	(981)	$	(872)
Preferred dividends paid	(77)		(107)
Issuances of preferred stock	—		890
Issuances of common stock	5		10
Repurchases of common stock	(39)		(565)
Issuances of debt (maturities greater than 90 days)	1,992		5,934
Payments on debt (maturities greater than 90 days) and finance leases	(2,315)		(4,387)
Increase (decrease) in short-term debt, net	1,999		(1,871)
Advances from unconsolidated affiliates	40		64
Proceeds from sales of noncontrolling interests	7		—
Purchases of noncontrolling interests	(221)		(178)
Other	(13)		(29)
Net cash provided by (used in) continuing operations	397		(1,111)
Net cash provided by discontinued operations	—		401
Net cash provided by (used in) financing activities	397		(710)
Effect of exchange rate changes in continuing operations	—		(2)
Effect of exchange rate changes in discontinued operations	—		(3)
Effect of exchange rate changes on cash, cash equivalents and restricted cash	—		(5)
(Decrease) increase in cash, cash equivalents and restricted cash, including discontinued operations	(78)		3,329
Cash, cash equivalents and restricted cash, including discontinued operations, January 1	985		217
Cash, cash equivalents and restricted cash, including discontinued operations, September 30	$	907	$	3,546
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	$	741	$	781
Income tax payments, including discontinued operations, net of refunds	101		1,376
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Increase in Cameron LNG JV investment for guarantee	$	22	$	—
Accrued capital expenditures	572		460
Increase in ARO for investment in PP&E, net	33		—
Increase in finance lease obligations for investment in PP&E	35		72
Derecognized PP&E for net investment in sales-type lease	44		—
Issuance of common stock in exchange for NCI and related AOCI	1,373		—
Contribution to Cameron LNG JV	—		50
Distribution from Cameron LNG JV	—		50
Distribution from Oncor Holdings	8		—
Equitization of long-term debt for deficit held by NCI	—		22
Conversion of mandatory convertible preferred stock	2,258		—
Preferred dividends declared but not paid	22		50
Common dividends issued in stock	—		23
Common dividends declared but not paid	351		301

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 September 30, 2021
Balance at June 30, 2021	$	1,454	$	10,150	$	14,291	$	(444)	$	25,451	$	241	$	25,692
Net (loss) income					(637)				(637)		5		(632)
Other comprehensive income (loss)							20		20		(2)		18
Share-based compensation expense			14						14				14
Dividends declared:
Series C preferred stock ($12.19/share)					(11)				(11)				(11)
Common stock ($1.10/share)					(351)				(351)				(351)
Conversion of series B preferred stock	(565)		565						—				—
Repurchases of common stock			(1)						(1)				(1)
Noncontrolling interest activities:
Purchases			63				6		69		(194)		(125)
Balance at September 30, 2021	$	889	$	10,791	$	13,292	$	(418)	$	24,554	$	50	$	24,604
	Three months ended September 30, 2020
Balance at June 30, 2020	$	3,147	$	7,490	$	13,511	$	(542)	$	23,606	$	1,780	$	25,386
Net income					399				399		22		421
Other comprehensive income							34		34		4		38
Share-based compensation expense			19						19				19
Dividends declared:
Series A preferred stock ($1.50/share)					(26)				(26)				(26)
Series B preferred stock ($1.68/share)					(10)				(10)				(10)
Series C preferred stock ($14.08/share)					(12)				(12)				(12)
Common stock ($1.05/share)					(302)				(302)				(302)
Repurchases of common stock			(501)						(501)				(501)
Noncontrolling interest activities:
Purchases			26				(5)		21		(178)		(157)
Balance at September 30, 2020	$	3,147	$	7,034	$	13,560	$	(513)	$	23,228	$	1,628	$	24,856

See Notes to Condensed Consolidated Financial Statements.

15

SEMPRA ENERGY
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (CONTINUED)
(Dollars in millions)
	Preferred stock		Common stock		Retained earnings		Accumulated other comprehensive income (loss)		Sempra Energy shareholders' equity		Non- controlling interests		Total equity
	(unaudited)
	Nine months ended September 30, 2021
Balance at December 31, 2020	$	3,147	$	7,053	$	13,673	$	(500)	$	23,373	$	1,561	$	24,934
Net income					703				703		48		751
Other comprehensive income							114		114		7		121
Share-based compensation expense			48						48				48
Dividends declared:
Series B preferred stock ($3.38/share)					(19)				(19)				(19)
Series C preferred stock ($36.57/share)					(33)				(33)				(33)
Common stock ($3.30/share)					(1,031)				(1,031)				(1,031)
Preferred dividends of subsidiary					(1)				(1)				(1)
Conversion of series A preferred stock	(1,693)		1,693						—				—
Conversion of series B preferred stock	(565)		565						—				—
Issuances of common stock			5						5				5
Repurchases of common stock			(39)						(39)				(39)
Noncontrolling interest activities:
Purchases			1,462				(32)		1,430		(1,567)		(137)
Sales			4						4		1		5
Balance at September 30, 2021	$	889	$	10,791	$	13,292	$	(418)	$	24,554	$	50	$	24,604
	Nine months ended September 30, 2020
Balance at December 31, 2019	$	2,258	$	7,480	$	11,130	$	(939)	$	19,929	$	1,876	$	21,805
Adoption of ASU 2016-13					(7)				(7)		(2)		(9)
Adjusted balance at December 31, 2019	2,258		7,480		11,123		(939)		19,922		1,874		21,796
Net income					3,472				3,472		201		3,673
Other comprehensive income (loss)							431		431		(25)		406
Share-based compensation expense			57						57				57
Dividends declared:
Series A preferred stock ($4.50/share)					(78)				(78)				(78)
Series B preferred stock ($5.06/share)					(29)				(29)				(29)
Series C preferred stock ($15.71/share)					(14)				(14)				(14)
Common stock ($3.14/share)					(913)				(913)				(913)
Preferred dividends of subsidiary					(1)				(1)				(1)
Issuance of series C preferred stock	889								889				889
Issuances of common stock			33						33				33
Repurchases of common stock			(565)						(565)				(565)
Noncontrolling interest activities:
Distributions											(1)		(1)
Purchases			29				(5)		24		(208)		(184)
Acquisition											1		1
Equitization of long-term debt for deficit held by NCI											22		22
Deconsolidation											(236)		(236)
Balance at September 30, 2020	$	3,147	$	7,034	$	13,560	$	(513)	$	23,228	$	1,628	$	24,856

See Notes to Condensed Consolidated Financial Statements.

16

SAN DIEGO GAS & ELECTRIC COMPANY
CONDENSED STATEMENTS OF OPERATIONS
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
	(unaudited)
Operating revenues
Electric	$	1,307	$	1,338	$	3,534	$	3,478
Natural gas	157		134		585		498
Total operating revenues	1,464		1,472		4,119		3,976
Operating expenses
Cost of electric fuel and purchased power	324		430		869		921
Cost of natural gas	37		27		159		118
Operation and maintenance	389		414		1,152		1,050
Depreciation and amortization	226		200		659		598
Franchise fees and other taxes	93		86		264		237
Total operating expenses	1,069		1,157		3,103		2,924
Operating income	395		315		1,016		1,052
Other income (expense), net	4		(2)		61		47
Interest income	—		1		1		2
Interest expense	(104)		(103)		(307)		(307)
Income before income taxes	295		211		771		794
Income tax expense	(90)		(33)		(168)		(161)
Net income/Earnings attributable to common shares	$	205	$	178	$	603	$	633

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 September 30, 2021 and 2020
2021:
Net income	$	295	$	(90)	$	205
Other comprehensive income (loss):
Pension and other postretirement benefits	1		—		1
Total other comprehensive income	1		—		1
Comprehensive income	$	296	$	(90)	$	206
2020:
Net income/Comprehensive income	$	211	$	(33)	$	178
	Nine months ended September 30, 2021 and 2020
2021:
Net income	$	771	$	(168)	$	603
Other comprehensive income (loss):
Pension and other postretirement benefits	1		—		1
Total other comprehensive income	1		—		1
Comprehensive income	$	772	$	(168)	$	604
2020:
Net income	$	794	$	(161)	$	633
Other comprehensive income (loss):
Pension and other postretirement benefits	5		(1)		4
Total other comprehensive income	5		(1)		4
Comprehensive income	$	799	$	(162)	$	637

See Notes to Condensed Financial Statements.

18

SAN DIEGO GAS & ELECTRIC COMPANY
CONDENSED BALANCE SHEETS
(Dollars in millions)
	September 30,		December 31,
	2021		2020(1)
	(unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	239	$	262
Accounts receivable – trade, net	642		573
Accounts receivable – other, net	96		143
Due from unconsolidated affiliates	1		—
Income taxes receivable, net	18		—
Inventories	112		104
Prepaid expenses	197		153
Regulatory assets	253		174
Fixed-price contracts and other derivatives	73		56
Greenhouse gas allowances	113		113
Other current assets	4		22
Total current assets	1,748		1,600
Other assets:
Regulatory assets	751		534
Nuclear decommissioning trusts	1,003		1,019
Greenhouse gas allowances	83		83
Right-of-use assets – operating leases	82		102
Wildfire fund	342		363
Other long-term assets	213		189
Total other assets	2,474		2,290
Property, plant and equipment:
Property, plant and equipment	25,824		24,436
Less accumulated depreciation and amortization	(6,263)		(6,015)
Property, plant and equipment, net	19,561		18,421
Total assets	$	23,783	$	22,311

(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)
	September 30,		December 31,
	2021		2020(1)
	(unaudited)
LIABILITIES AND EQUITY
Current liabilities:
Short-term debt	$	375	$	—
Accounts payable	602		553
Due to unconsolidated affiliates	61		64
Interest payable	74		46
Accrued compensation and benefits	138		135
Accrued franchise fees	59		56
Regulatory liabilities	53		61
Current portion of long-term debt and finance leases	48		611
Customer deposits	33		56
Greenhouse gas obligations	113		113
Asset retirement obligations	130		117
Other current liabilities	233		199
Total current liabilities	1,919		2,011
Long-term debt and finance leases	7,587		6,866
Deferred credits and other liabilities:
Pension obligation, net of plan assets	61		92
Deferred income taxes	2,203		2,019
Deferred investment tax credits	13		13
Regulatory liabilities	2,311		2,195
Greenhouse gas obligations	30		—
Asset retirement obligations	744		759
Deferred credits and other	581		626
Total deferred credits and other liabilities	5,943		5,704
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	6,683		6,080
Accumulated other comprehensive income (loss)	(9)		(10)
Total shareholder’s equity	8,334		7,730
Total liabilities and shareholder's equity	$	23,783	$	22,311

(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)
	Nine months ended September 30,
	2021		2020
	(unaudited)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	603	$	633
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	659		598
Deferred income taxes and investment tax credits	133		36
Other	(1)		13
Net change in working capital components	(187)		(184)
Changes in noncurrent assets and liabilities, net	(183)		(113)
Net cash provided by operating activities	1,024		983
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,560)		(1,323)
Purchases of nuclear decommissioning trust assets	(729)		(1,091)
Proceeds from sales of nuclear decommissioning trust assets	729		1,091
Other	7		8
Net cash used in investing activities	(1,553)		(1,315)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	—		(200)
Issuances of debt (maturities greater than 90 days)	1,120		1,598
Payments on debt (maturities greater than 90 days) and finance leases	(606)		(252)
Decrease in short-term debt, net	—		(80)
Debt issuance costs	(8)		(11)
Net cash provided by financing activities	506		1,055
(Decrease) increase in cash and cash equivalents	(23)		723
Cash and cash equivalents, January 1	262		10
Cash and cash equivalents, September 30	$	239	$	733
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	$	275	$	276
Income tax payments, net of refunds	64		20
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	$	217	$	184
Increase in ARO for investment in PP&E	18		—
Increase in finance lease obligations for investment in PP&E	23		26

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 September 30, 2021
Balance at June 30, 2021	$	1,660	$	6,478	$	(10)	$	8,128
Net income			205				205
Other comprehensive income					1		1
Balance at September 30, 2021	$	1,660	$	6,683	$	(9)	$	8,334
	Three months ended September 30, 2020
Balance at June 30, 2020	$	1,660	$	5,711	$	(12)	$	7,359
Net income			178				178
Balance at September 30, 2020	$	1,660	$	5,889	$	(12)	$	7,537
	Nine months ended September 30, 2021
Balance at December 31, 2020	$	1,660	$	6,080	$	(10)	$	7,730
Net income			603				603
Other comprehensive income					1		1
Balance at September 30, 2021	$	1,660	$	6,683	$	(9)	$	8,334
	Nine months ended September 30, 2020
Balance at December 31, 2019	$	1,660	$	5,456	$	(16)	$	7,100
Net income			633				633
Other comprehensive income					4		4
Common stock dividends declared ($1.72/share)			(200)				(200)
Balance at September 30, 2020	$	1,660	$	5,889	$	(12)	$	7,537

See Notes to Condensed Financial Statements.

22

SOUTHERN CALIFORNIA GAS COMPANY
CONDENSED STATEMENTS OF OPERATIONS
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
	(unaudited)
Operating revenues	$	1,106	$	842	$	3,738	$	3,247
Operating expenses
Cost of natural gas	240		92		736		476
Operation and maintenance	546		494		1,574		1,399
Aliso Canyon litigation and regulatory matters	1,571		27		1,571		127
Depreciation and amortization	180		165		533		486
Franchise fees and other taxes	54		48		163		142
Total operating expenses	2,591		826		4,577		2,630
Operating (loss) income	(1,485)		16		(839)		617
Other (expense) income, net	(39)		(7)		(2)		21
Interest income	—		—		—		2
Interest expense	(39)		(39)		(118)		(119)
(Loss) income before income taxes	(1,563)		(30)		(959)		521
Income tax benefit (expense)	437		6		335		(95)
Net (loss) income	(1,126)		(24)		(624)		426
Preferred dividends	—		—		(1)		(1)
(Losses) earnings attributable to common shares	$	(1,126)	$	(24)	$	(625)	$	425

See Notes to Condensed Financial Statements.

23

SOUTHERN CALIFORNIA GAS COMPANY
CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
	Pretax amount		Income tax benefit (expense)		Net-of-tax amount
	(unaudited)
	Three months ended September 30, 2021 and 2020
2021:
Net loss	$	(1,563)	$	437	$	(1,126)
Other comprehensive income (loss):
Pension and other postretirement benefits	1		—		1
Total other comprehensive income	1		—		1
Comprehensive loss	$	(1,562)	$	437	$	(1,125)
2020:
Net loss/Comprehensive loss	$	(30)	$	6	$	(24)
	Nine months ended September 30, 2021 and 2020
2021:
Net loss	$	(959)	$	335	$	(624)
Other comprehensive income (loss):
Pension and other postretirement benefits	2		—		2
Total other comprehensive income	2		—		2
Comprehensive loss	$	(957)	$	335	$	(622)
2020:
Net income	$	521	$	(95)	$	426
Other comprehensive income (loss):
Pension and other postretirement benefits	1		—		1
Total other comprehensive income	1		—		1
Comprehensive income	$	522	$	(95)	$	427

See Notes to Condensed Financial Statements.

24

SOUTHERN CALIFORNIA GAS COMPANY
CONDENSED BALANCE SHEETS
(Dollars in millions)
	September 30,		December 31,
	2021		2020(1)
	(unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	226	$	4
Accounts receivable – trade, net	462		786
Accounts receivable – other, net	86		64
Due from unconsolidated affiliates	11		22
Income taxes receivable, net	16		—
Inventories	168		153
Regulatory assets	37		16
Greenhouse gas allowances	384		390
Other current assets	62		47
Total current assets	1,452		1,482
Other assets:
Regulatory assets	1,449		1,208
Insurance receivable for Aliso Canyon costs	414		445
Greenhouse gas allowances	262		9
Right-of-use assets – operating leases	61		74
Other long-term assets	575		499
Total other assets	2,761		2,235
Property, plant and equipment:
Property, plant and equipment	22,445		21,180
Less accumulated depreciation and amortization	(6,739)		(6,437)
Property, plant and equipment, net	15,706		14,743
Total assets	$	19,919	$	18,460

(1)    Derived from audited financial statements.

See Notes to Condensed Financial Statements.

25

SOUTHERN CALIFORNIA GAS COMPANY
CONDENSED BALANCE SHEETS (CONTINUED)
(Dollars in millions)
	September 30,		December 31,
	2021		2020(1)
	(unaudited)
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities:
Short-term debt	$	—	$	113
Accounts payable – trade	488		600
Accounts payable – other	133		122
Due to unconsolidated affiliates	45		31
Accrued compensation and benefits	203		189
Regulatory liabilities	462		79
Current portion of long-term debt and finance leases	10		10
Customer deposits	15		48
Reserve for Aliso Canyon costs	1,962		150
Greenhouse gas obligations	384		390
Asset retirement obligations	58		59
Other current liabilities	310		291
Total current liabilities	4,070		2,082
Long-term debt and finance leases	4,769		4,763
Deferred credits and other liabilities:
Pension obligation, net of plan assets	784		853
Deferred income taxes	1,032		1,406
Deferred investment tax credits	7		8
Regulatory liabilities	1,067		1,177
Reserve for Aliso Canyon costs	14		301
Greenhouse gas obligations	140		—
Asset retirement obligations	2,377		2,309
Deferred credits and other	413		417
Total deferred credits and other liabilities	5,834		6,471
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)	1,666		866
Retained earnings	3,587		4,287
Accumulated other comprehensive income (loss)	(29)		(31)
Total shareholders’ equity	5,246		5,144
Total liabilities and shareholders’ equity	$	19,919	$	18,460

(1)    Derived from audited financial statements.

See Notes to Condensed Financial Statements.

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SOUTHERN CALIFORNIA GAS COMPANY
CONDENSED STATEMENTS OF CASH FLOWS
(Dollars in millions)
	Nine months ended September 30,
	2021		2020
	(unaudited)
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income	$	(624)	$	426
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depreciation and amortization	533		486
Deferred income taxes and investment tax credits	(467)		(38)
Other	47		42
Reserve for Aliso Canyon costs	1,525		259
Net change in other working capital components	385		254
Insurance receivable for Aliso Canyon costs	31		(165)
Changes in other noncurrent assets and liabilities, net	(393)		124
Net cash provided by operating activities	1,037		1,388
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,417)		(1,345)
Net cash used in investing activities	(1,417)		(1,345)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(75)		(50)
Preferred dividends paid	(1)		(1)
Equity contribution from Sempra Energy	800		—
Issuances of debt (maturities greater than 90 days)	—		949
Payments on finance leases	(9)		(9)
Decrease in short-term debt, net	(113)		(630)
Debt issuance costs	—		(8)
Net cash provided by financing activities	602		251
Increase in cash and cash equivalents	222		294
Cash and cash equivalents, January 1	4		10
Cash and cash equivalents, September 30	$	226	$	304
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	$	119	$	114
Income tax payments, net of refunds	170		1
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	$	205	$	146
Increase in finance lease obligations for investment in PP&E	12		46
Common dividends declared but not paid	—		50

See Notes to Condensed Financial Statements.

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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 September 30, 2021
Balance at June 30, 2021	$	22	$	866	$	4,713	$	(30)	$	5,571
Net loss					(1,126)				(1,126)
Other comprehensive income							1		1
Dividends declared:
Preferred stock ($0.38/share)					—				—
Equity contribution from Sempra Energy			800						800
Balance at September 30, 2021	$	22	$	1,666	$	3,587	$	(29)	$	5,246
	Three months ended September 30, 2020
Balance at June 30, 2020	$	22	$	866	$	4,282	$	(22)	$	5,148
Net loss					(24)				(24)
Dividends declared:
Preferred stock ($0.38/share)					—				—
Common stock ($0.55/share)					(50)				(50)
Balance at September 30, 2020	$	22	$	866	$	4,208	$	(22)	$	5,074
	Nine months ended September 30, 2021
Balance at December 31, 2020	$	22	$	866	$	4,287	$	(31)	$	5,144
Net loss					(624)				(624)
Other comprehensive income							2		2
Dividends declared:
Preferred stock ($1.13/share)					(1)				(1)
Common stock ($0.82/share)					(75)				(75)
Equity contribution from Sempra Energy			800						800
Balance at September 30, 2021	$	22	$	1,666	$	3,587	$	(29)	$	5,246
	Nine months ended September 30, 2020
Balance at December 31, 2019	$	22	$	866	$	3,883	$	(23)	$	4,748
Net income					426				426
Other comprehensive income							1		1
Dividends declared:
Preferred stock ($1.13/share)					(1)				(1)
Common stock ($1.10/share)					(100)				(100)
Balance at September 30, 2020	$	22	$	866	$	4,208	$	(22)	$	5,074

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. Sempra’s business activities are organized under five 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. References in this report to “we,” “our,” “us” and “Sempra” are to Sempra and its consolidated entities, collectively, unless otherwise stated or indicated by the context. We refer to SDG&E and SoCalGas collectively as the California Utilities. Sempra Infrastructure Partners (formerly Sempra Global) is the holding company for our subsidiaries that are not subject to California or Texas utility regulation. We have eliminated intercompany accounts and transactions within the consolidated financial statements of each reporting entity.

Throughout these Notes, 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.

We have prepared our Condensed Consolidated Financial Statements in conformity with U.S. GAAP and in accordance with the interim-period-reporting requirements of Form 10-Q and applicable rules of the SEC. The financial statements reflect all adjustments that are necessary for a fair presentation of the results for the interim periods. These adjustments are only of a normal, recurring nature. Results of operations for interim periods are not necessarily indicative of results for the entire year or for any other period. We evaluated events and transactions that occurred after September 30, 2021 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, 2020 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2020 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.

You should read the information in this report in conjunction with the Annual Report.

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Discontinued Operations

In January 2019, our board of directors approved a plan to sell our South American businesses based on our strategic focus on North America. We determined that these businesses, which previously constituted the Sempra South American Utilities segment, and certain activities associated with these businesses, met the held-for-sale criteria. These businesses are presented as discontinued operations, which we discuss further in Note 5. We completed the sales of our South American businesses in the second quarter of 2020. Our discussions in the Notes below relate only to our continuing operations unless otherwise noted.

Regulated Operations

The California Utilities and Sempra Mexico’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 Mexico 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 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

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

RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
(Dollars in millions)
	September 30,		December 31,
	2021		2020
Cash and cash equivalents	$	873	$	960
Restricted cash, current	31		22
Restricted cash, noncurrent	3		3
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	907	$	985

CREDIT LOSSES

We are exposed to credit losses from financial assets measured at amortized cost, including trade and other accounts receivable and amounts due from unconsolidated affiliates. 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 receivable, historical and industry trends, counterparty creditworthiness, economic conditions and specific events, such as bankruptcies. 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 connection with the COVID-19 pandemic, the California Utilities implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for all customers (except for SoCalGas’ noncore customers), waiving late payment fees, and offering flexible payment plans. Such measures ended on June 30, 2021, except for the suspension of service disconnections that ended on September 30, 2021. At the CPUC’s direction, the California Utilities have started to automatically enroll residential and small business customers with past-due balances in long-term repayment plans. The CPUC is continuing to consider the impacts of any state or federal relief programs on customer arrearages and if further debt relief is warranted.

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As we discuss in Note 4, the CPUC authorized each of the California Utilities to track and request recovery of incremental costs, including uncollectible expenses, associated with complying with customer protection measures ordered by the CPUC related to the COVID-19 pandemic.

In connection with a separate CPUC decision addressing residential service disconnections, the California Utilities each established a two-way balancing account to record the uncollectible expenses associated with residential customers’ inability to pay their electric or gas bills, including as a result of the relief from outstanding utility bill amounts provided under the AMP. We discuss the AMP in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report.

The California Utilities have recorded increases in their allowances for expected credit losses primarily related to expected forgiveness of outstanding utility bill amounts, including increases due to the effect of the COVID-19 pandemic, for participating, income-qualified residential customers eligible under the AMP. Our businesses will continue to monitor macroeconomic factors and customer payment patterns when evaluating their allowances for credit losses, which may increase significantly due to the effects of the COVID-19 pandemic or other factors.

We provide below allowances and changes in allowances for credit losses for trade and other accounts receivable. The California Utilities record changes in the allowances for credit losses related to Accounts Receivable – Trade in regulatory accounts.

TRADE AND OTHER ACCOUNTS RECEIVABLE – ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	2021		2020
Sempra:
Allowances for credit losses at January 1	$	138	$	29
Incremental allowance upon adoption of ASU 2016-13	—		1
Provisions for expected credit losses	96		84
Write-offs	(28)		(11)
Allowances for credit losses at September 30(1)	$	206	$	103
SDG&E:
Allowances for credit losses at January 1	$	69	$	14
Provisions for expected credit losses	30		44
Write-offs	(16)		(6)
Allowances for credit losses at September 30(2)	$	83	$	52
SoCalGas:
Allowances for credit losses at January 1	$	68	$	15
Provisions for expected credit losses	64		40
Write-offs	(12)		(5)
Allowances for credit losses at September 30(3)	$	120	$	50

(1)    At September 30, 2021, includes $146 million in Accounts Receivable – Trade, Net, $50 million in Accounts Receivable – Other, Net and $10 million in Other Long-Term Assets.

(2)    At September 30, 2021, includes $58 million in Accounts Receivable – Trade, Net, $21 million in Accounts Receivable – Other, Net and $4 million in Other Long-Term Assets.

(3)    At September 30, 2021, includes $85 million in Accounts Receivable – Trade, Net, $29 million in Accounts Receivable – Other, Net and $6 million in Other Long-Term Assets.

For amounts due from unconsolidated affiliates, on a quarterly basis, we evaluate credit losses and record allowances for expected credit losses, 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.

As we discuss below in “Transactions with Affiliates,” Sempra has loans due from unconsolidated affiliates with varying tenors, interest rates and currencies. We provide below the allowances and changes in allowances for credit losses for loans and other amounts due from unconsolidated affiliates.

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AMOUNTS DUE FROM UNCONSOLIDATED AFFILIATES – ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	2021		2020
Sempra:
Allowances for credit losses at January 1	$	3	$	—
Allowance established upon adoption of ASU 2016-13	—		6
Reductions to expected credit losses	(2)		(3)
Allowances for credit losses at September 30(1)	$	1	$	3

(1)    At September 30, 2021, $1 million is included in Due from Unconsolidated Affiliates – Noncurrent.

As we discuss in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report, Sempra previously provided guarantees for the benefit of Cameron LNG JV related to its construction-period debt obligations for a maximum aggregate amount of $4.0 billion. In March 2021, Cameron LNG JV reached financial completion of the three-train liquefaction project, which terminated the guarantees. There are no longer any expected credit losses related to these terminated guarantees.

As we discuss below in Note 6, Sempra provided a guarantee for the benefit of Cameron LNG JV related to amounts withdrawn by Sempra LNG from the SDSRA. At September 30, 2021, expected credit losses of $7 million related to this guarantee are included in Deferred Credits and Other on Sempra’s Condensed Consolidated Balance Sheet.

INVENTORIES

The components of inventories are as follows:

INVENTORY BALANCES
(Dollars in millions)
	Natural gas				LNG				Materials and supplies				Total
	September 30, 2021		December 31, 2020		September 30, 2021		December 31, 2020		September 30, 2021		December 31, 2020		September 30, 2021		December 31, 2020
Sempra	$	169	$	118	$	17	$	7	$	185	$	183	$	371	$	308
SDG&E	—		—		—		—		112		104		112		104
SoCalGas	110		94		—		—		58		59		168		153

WILDFIRE FUND

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

In July 2021, the CPUC approved SDG&E’s 2021 Wildfire Mitigation Plan Update. In July 2021, the CPUC’s Wildfire Safety Division became the Office of Energy Infrastructure Safety (OEIS) under the California Natural Resources Agency. As successor to the Wildfire Safety Division, OEIS maintains the duties and responsibilities of the former Wildfire Safety Division with respect to Wildfire Mitigation Plans.

SDG&E submitted its request to OEIS for a 2021 wildfire safety certification in September 2021. OEIS has until December 7, 2021 to issue the certification or provide written notice explaining why additional time is needed. SDG&E’s existing safety certification remains valid until this pending request is resolved.

In a complaint filed in U.S. District Court for the Northern District of California in July 2019, plaintiffs seek to invalidate AB 1054 based on allegations that the legislation violates federal law. The district court dismissed the complaint and the plaintiffs have petitioned the U.S. Court of Appeals for the Ninth Circuit for review.

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.

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The table below summarizes capitalized interest and AFUDC.

CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Sempra	$	52	$	51	$	166	$	149
SDG&E	24		26		82		79
SoCalGas	18		14		49		39

OTHER INTANGIBLE ASSETS

Other Intangible Assets included on Sempra’s Condensed Consolidated Balance Sheets are as follows:

OTHER INTANGIBLE ASSETS
(Dollars in millions)
	Amortization period (years)	September 30, 2021		December 31, 2020
Renewable energy transmission and consumption permits	15 to 19	$	169	$	169
O&M agreement	23	66		66
PPA	14	190		—
Other	10 to indefinite	15		15
		440		250
Less accumulated amortization:
Renewable energy transmission and consumption permits		(38)		(32)
O&M agreement		(11)		(9)
PPA		(7)		—
Other		(8)		(7)
		(64)		(48)
		$	376	$	202

Other Intangible Assets at September 30, 2021 primarily include:

▪renewable energy transmission and consumption permits previously granted by the CRE at the Ventika wind power generation facilities, Don Diego Solar and Border Solar;

▪a favorable O&M agreement acquired in connection with the acquisition of Ductos y Energéticos del Norte, S. de R.L. de C.V.; and

▪an intangible asset of $190 million, representing the relative fair value of the PPA that was acquired in connection with the acquisition of ESJ in March 2021.

Intangible assets subject to amortization are amortized over their estimated useful lives. Amortization expense for intangible assets was $6 million, including $4 million recorded against revenues, and $3 million in the three months ended September 30, 2021 and 2020, respectively, and $16 million, including $7 million recorded against revenues, and $8 million in the nine months ended September 30, 2021 and 2020, respectively. We estimate the remaining amortization expense in 2021 to be $7 million, including $3 million recorded against revenues, and amortization expense of $26 million per year for the next four years, including $13 million recorded against revenues.

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.

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

SDG&E

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

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

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

SDG&E determined that none of its PPAs and tolling agreements resulted in SDG&E being the primary beneficiary of a VIE at September 30, 2021 and December 31, 2020. 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 $1,223 million and $1,237 million at September 30, 2021 and December 31, 2020, 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

Our 100% interest in Oncor Holdings is a VIE that owns an 80.25% interest in Oncor. 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 $12,475 million at September 30, 2021 and $12,440 million at December 31, 2020.

Sempra LNG

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 $454 million at September 30, 2021 and $433 million at

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December 31, 2020. 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, which was amended in June 2021, 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 LNG consolidated $522 million and $207 million of assets at September 30, 2021 and December 31, 2020, respectively, consisting primarily of PP&E, net, attributable to ECA LNG Phase 1 that could be used only to settle obligations of this VIE and that are not available to settle obligations of Sempra, and $367 million and $49 million of liabilities at September 30, 2021 and December 31, 2020, respectively, consisting primarily of long-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 of the Notes to Consolidated Financial Statements in the Annual Report, Sempra, IEnova and TOTAL 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

Settlement Accounting for Lump Sum Payments

Sempra recorded settlement charges of $7 million in the nine months ended September 30, 2021 and $13 million and $22 million in the three months and nine months ended September 30, 2020, respectively, in net periodic benefit cost for lump sum payments from its nonqualified pension plan that were in excess of the plan’s service cost plus interest cost.

Net Periodic Benefit Cost

The following three tables provide the components of net periodic benefit cost.

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NET PERIODIC BENEFIT COST – SEMPRA
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended September 30,
	2021		2020		2021		2020
Service cost	$	36	$	31	$	6	$	5
Interest cost	28		32		7		8
Expected return on assets	(44)		(41)		(14)		(14)
Amortization of:
Prior service cost (credit)	3		3		(1)		(1)
Actuarial loss (gain)	12		9		(3)		(2)
Settlement charges	—		13		—		—
Net periodic benefit cost (credit)	35		47		(5)		(4)
Regulatory adjustments	73		37		5		4
Total expense recognized	$	108	$	84	$	—	$	—
	Nine months ended September 30,
	2021		2020		2021		2020
Service cost	$	109	$	97	$	17	$	14
Interest cost	84		97		21		24
Expected return on assets	(130)		(126)		(44)		(41)
Amortization of:
Prior service cost (credit)	8		9		(2)		(2)
Actuarial loss (gain)	34		26		(7)		(7)
Settlement charges	7		22		—		—
Net periodic benefit cost (credit)	112		125		(15)		(12)
Regulatory adjustments	66		31		15		12
Total expense recognized	$	178	$	156	$	—	$	—

NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended September 30,
	2021		2020		2021		2020
Service cost	$	9	$	7	$	2	$	1
Interest cost	6		7		1		2
Expected return on assets	(11)		(12)		(2)		(3)
Amortization of:
Prior service cost	—		1		—		—
Actuarial loss (gain)	1		1		(1)		(1)
Net periodic benefit cost (credit)	5		4		—		(1)
Regulatory adjustments	21		22		—		1
Total expense recognized	$	26	$	26	$	—	$	—
	Nine months ended September 30,
	2021		2020		2021		2020
Service cost	$	26	$	23	$	4	$	3
Interest cost	18		22		4		5
Expected return on assets	(36)		(37)		(7)		(8)
Amortization of:
Prior service cost	—		2		—		—
Actuarial loss (gain)	2		3		(2)		(2)
Net periodic benefit cost (credit)	10		13		(1)		(2)
Regulatory adjustments	30		28		1		2
Total expense recognized	$	40	$	41	$	—	$	—

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NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended September 30,
	2021		2020		2021		2020
Service cost	$	23	$	20	$	5	$	3
Interest cost	19		22		5		7
Expected return on assets	(27)		(27)		(12)		(11)
Amortization of:
Prior service cost (credit)	2		2		(1)		(1)
Actuarial loss (gain)	8		6		(2)		(1)
Net periodic benefit cost (credit)	25		23		(5)		(3)
Regulatory adjustments	52		15		5		3
Total expense recognized	$	77	$	38	$	—	$	—
	Nine months ended September 30,
	2021		2020		2021		2020
Service cost	$	73	$	64	$	13	$	10
Interest cost	59		66		16		19
Expected return on assets	(85)		(81)		(36)		(32)
Amortization of:
Prior service cost (credit)	6		6		(2)		(2)
Actuarial loss (gain)	27		19		(5)		(5)
Net periodic benefit cost (credit)	80		74		(14)		(10)
Regulatory adjustments	36		3		14		10
Total expense recognized	$	116	$	77	$	—	$	—

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 $539 million and $512 million at September 30, 2021 and December 31, 2020, respectively.

SEMPRA EARNINGS PER COMMON SHARE

Basic EPS is calculated by dividing earnings attributable to common shares (from both continuing and discontinued operations) 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 September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Numerator for continuing operations:
(Loss) income from continuing operations, net of income tax	$	(632)	$	428	$	751	$	1,823
Earnings attributable to noncontrolling interests	(5)		(22)		(48)		(191)
Preferred dividends	(11)		(48)		(52)		(121)
Preferred dividends of subsidiary	—		—		(1)		(1)
(Losses) earnings from continuing operations attributable to common shares	$	(648)	$	358	$	650	$	1,510
Numerator for discontinued operations:
(Loss) income from discontinued operations, net of income tax	$	—	$	(7)	$	—	$	1,850
Earnings attributable to noncontrolling interests	—		—		—		(10)
(Losses) earnings from discontinued operations attributable to common shares	$	—	$	(7)	$	—	$	1,840
Numerator for (losses) earnings:
(Losses) earnings attributable to common shares	$	(648)	$	351	$	650	$	3,350
Denominator:
Weighted-average common shares outstanding for basic EPS(1)	319,144		289,490		309,350		291,771
Dilutive effect of stock options and RSUs(2)(3)	—		1,092		797		1,164
Dilutive effect of mandatory convertible preferred stock	—		—		707		—
Weighted-average common shares outstanding for diluted EPS	319,144		290,582		310,854		292,935
Basic EPS:
(Losses) earnings from continuing operations	$	(2.03)	$	1.23	$	2.10	$	5.17
(Losses) earnings from discontinued operations	$	—	$	(0.02)	$	—	$	6.31
(Losses) earnings	$	(2.03)	$	1.21	$	2.10	$	11.48
Diluted EPS:
(Losses) earnings from continuing operations	$	(2.03)	$	1.23	$	2.09	$	5.15
(Losses) earnings from discontinued operations	$	—	$	(0.02)	$	—	$	6.28
(Losses) earnings	$	(2.03)	$	1.21	$	2.09	$	11.43

(1)    Includes 451 and 535 fully vested RSUs held in our Deferred Compensation Plan for the three months ended September 30, 2021 and 2020, respectively, and 453 and 536 of such RSUs for the nine months ended September 30, 2021 and 2020, 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)    In the three months ended September 30, 2021, the total weighted-average number of potentially dilutive stock options and RSUs was 699. However, these securities were not included in the computation of EPS because to do so would have decreased losses per share.

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

The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect. The computation of diluted EPS for the three months and nine months ended September 30, 2021 excludes 147,840 and 240,654 potentially dilutive shares, respectively, because to include them would be antidilutive for the period. The computation of diluted EPS for the three months and nine months ended September 30, 2020 excludes 142,100 and 204,426 potentially dilutive shares, respectively, of such potentially dilutive shares. However, these shares could potentially dilute basic EPS in the future.

The potentially dilutive impact from mandatory convertible preferred stock is 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. As we discuss below in “Shareholders’ Equity and Noncontrolling Interests,” we converted our

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series A preferred stock into common stock on January 15, 2021 and our series B preferred stock into common stock on July 15, 2021. The computation of diluted EPS for the three months and nine months ended September 30, 2021 excludes 639,733 and 3,037,812 potentially dilutive shares, respectively. The computation of diluted EPS for both the three months and nine months ended September 30, 2020 excludes 19,292,641 potentially dilutive shares.

Pursuant to Sempra’s share-based compensation plans, the Compensation and Talent Committee of Sempra’s board of directors granted 222,620 nonqualified stock options, 323,889 performance-based RSUs and 143,980 service-based RSUs in the nine months ended September 30, 2021, primarily in January.

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

COMPREHENSIVE INCOME

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

CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1)
(Dollars in millions)
	Foreign currency translation adjustments		Financial instruments		Pension and other postretirement benefits		Total accumulated other comprehensive income (loss)
	Three months ended September 30, 2021 and 2020
Sempra:
Balance at June 30, 2021	$	(88)	$	(265)	$	(91)	$	(444)
OCI before reclassifications	—		15		(8)		7
Amounts reclassified from AOCI	—		16		3		19
Net OCI(2)	—		31		(5)		26
Balance at September 30, 2021	$	(88)	$	(234)	$	(96)	$	(418)
Balance at June 30, 2020	$	(83)	$	(361)	$	(98)	$	(542)
OCI before reclassifications	6		14		(7)		13
Amounts reclassified from AOCI	—		4		12		16
Net OCI(2)	6		18		5		29
Balance at September 30, 2020	$	(77)	$	(343)	$	(93)	$	(513)
SDG&E:
Balance at June 30, 2021					$	(10)	$	(10)
Amounts reclassified from AOCI					1		1
Net OCI					1		1
Balance at September 30, 2021					$	(9)	$	(9)
Balance as of June 30, 2020 and September 30, 2020					$	(12)	$	(12)
SoCalGas:
Balance at June 30, 2021			$	(13)	$	(17)	$	(30)
Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance at September 30, 2021			$	(13)	$	(16)	$	(29)
Balance as of June 30, 2020 and September 30, 2020			$	(13)	$	(9)	$	(22)

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

(2)    Total AOCI includes $(4) million and $3 million of foreign currency translation adjustments and $(2) million and $2 million of financial instruments associated with the IEnova cash tender offer in 2021 and purchases of NCI in 2020, respectively, which we discuss below in “Other Noncontrolling Interests – Sempra Mexico,” and which do 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)
	Nine months ended September 30, 2021 and 2020
Sempra(2):
Balance as of December 31, 2020	$	(64)	$	(331)	$	(105)	$	(500)
OCI before reclassifications	(24)		52		(3)		25
Amounts reclassified from AOCI	—		45		12		57
Net OCI(3)	(24)		97		9		82
Balance as of September 30, 2021	$	(88)	$	(234)	$	(96)	$	(418)
Balance as of December 31, 2019	$	(607)	$	(215)	$	(117)	$	(939)
OCI before reclassifications(4)	(115)		(153)		(5)		(273)
Amounts reclassified from AOCI(4)	645		25		29		699
Net OCI(3)	530		(128)		24		426
Balance as of September 30, 2020	$	(77)	$	(343)	$	(93)	$	(513)
SDG&E:
Balance as of December 31, 2020					$	(10)	$	(10)
Amounts reclassified from AOCI					1		1
Net OCI					1		1
Balance at September 30, 2021					$	(9)	$	(9)
Balance as of December 31, 2019					$	(16)	$	(16)
Amounts reclassified from AOCI(4)					4		4
Net OCI					4		4
Balance as of September 30, 2020					$	(12)	$	(12)
SoCalGas:
Balance as of December 31, 2020			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			—		2		2
Net OCI			—		2		2
Balance as of September 30, 2021			$	(13)	$	(16)	$	(29)
Balance as of December 31, 2019			$	(13)	$	(10)	$	(23)
Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance as of September 30, 2020			$	(13)	$	(9)	$	(22)

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

(2)    Includes discontinued operations in 2020.

(3)    Total AOCI includes $20 million and $3 million of foreign currency translation adjustments and $12 million and $2 million of financial instruments associated with the IEnova exchange and cash tender offers in 2021 and purchases of NCI in 2020, respectively, which we discuss below in “Other Noncontrolling Interests – Sempra Mexico,” and which do not impact the Condensed Consolidated Statement of Comprehensive Income (Loss).

(4)    Pension and Other Postretirement Benefits and Total AOCI include $3 million in transfers of liabilities from SDG&E to Sempra in 2020 related to the nonqualified pension plans.

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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 September 30,
	2021		2020
Sempra:
Financial instruments:
Interest rate instruments	$	(1)	$	3	Interest Expense
Interest rate instruments	19		5		Equity Earnings(1)
Interest rate and foreign exchange instruments	5		(4)		Other (Expense) Income, Net
Total before income tax	23		4
	(7)		—		Income Tax Benefit (Expense)
Net of income tax	$	16	$	4
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	3	$	3	Other (Expense) Income, Net
Amortization of prior service cost	1		1		Other (Expense) Income, Net
Settlement charges	—		13		Other (Expense) Income, Net
Total before income tax	4		17
	(1)		(5)		Income Tax Benefit (Expense)
Net of income tax	$	3	$	12
Total reclassifications for the period, net of tax	$	19	$	16
SDG&E:
Pension and other postretirement benefits(2):
Amortization of prior service cost	$	1	$	—	Other Income (Expense), Net
Total reclassifications for the period, net of tax	$	1	$	—
SoCalGas:
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	1	$	—	Other (Expense) Income, Net
Total reclassifications for the period, net of tax	$	1	$	—

(1)    Equity earnings at Sempra Mexico 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
	Nine months ended September 30,
	2021		2020
Sempra:
Foreign currency translation adjustments	$	—	$	645	(Loss) Income from Discontinued Operations, Net of Income Tax
Financial instruments:
Interest rate instruments	$	—	$	6	Interest Expense
Interest rate instruments	57		8		Equity Earnings(1)
Foreign exchange instruments	1		(2)		Revenues: Energy-Related Businesses
	—		(1)		Other (Expense) Income, Net
Foreign exchange instruments	1		(2)		Equity Earnings(1)
Interest rate and foreign exchange instruments	—		1		Interest Expense
	4		33		Other (Expense) Income, Net
Total before income tax	63		43
	(16)		(12)		Income Tax Benefit (Expense)
Net of income tax	47		31
	(2)		(6)		Earnings Attributable to Noncontrolling Interests
	$	45	$	25
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	6	$	6	Other (Expense) Income, Net
Amortization of actuarial loss	—		6		(Loss) Income from Discontinued Operations, Net of Income Tax
Amortization of prior service cost	3		3		Other (Expense) Income, Net
Settlement charges	7		22		Other (Expense) Income, Net
Total before income tax	16		37
	—		(2)		(Loss) Income from Discontinued Operations, Net of Income Tax
	(4)		(9)		Income Tax Benefit (Expense)
Net of income tax	$	12	$	26
Total reclassifications for the period, net of tax	$	57	$	696
SDG&E:
Pension and other postretirement benefits(2):
Amortization of prior service cost	$	1	$	1	Other Income (Expense), Net
Total reclassifications for the period, net of tax	$	1	$	1
SoCalGas:
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	1	$	—	Other (Expense) Income, Net
Amortization of prior service cost	1		1		Other (Expense) Income, Net
Total reclassifications for the period, net of tax	$	2	$	1

(1)    Equity earnings at Sempra Mexico are recognized after tax.

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

SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS

Sempra Series A Preferred Stock

On January 15, 2021, we converted 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

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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 have returned to the status of authorized and unissued shares of preferred stock.

Sempra Series B Preferred Stock

The terms of our series B preferred stock require a notice to holders when the aggregate adjustment to the conversion rates at which shares of series B preferred stock are convertible into shares of Sempra common stock is more than 1%. On July 7, 2021, we notified the holders of the series B preferred stock of such an adjustment. These adjustments, which resulted from the incremental impact of our second quarter dividend declared on our common stock and which became effective as of July 6, 2021, the ex-dividend date for such dividend, included adjustments to the minimum and maximum conversion rates and the related initial and threshold appreciation prices.

As of July 15, 2021, we had converted, pursuant to either early conversions at the election of the holder or the mandatory conversion of all outstanding shares, all 5,750,000 shares of series B preferred stock into an aggregate of 4,256,720 shares of our common stock and a nominal amount of cash in lieu of fractional share interests, based on a conversion rate of 0.7403 shares of our common stock for each issued and outstanding share of series B preferred stock. As a consequence, no shares of series B preferred stock were outstanding after July 15, 2021 and the 5,750,000 shares that were formerly series B preferred stock have returned to the status of authorized and unissued shares of preferred stock.

Sempra Series C Preferred Stock

On June 19, 2020, we issued 900,000 shares of our 4.875% fixed-rate reset cumulative redeemable perpetual preferred stock, series C (series C preferred stock) in a registered public offering at a price to the public of $1,000 per share and received net proceeds of $889 million after deducting the underwriting discount and equity issuance costs of $11 million. We used the net proceeds for working capital and other general corporate purposes, including the repayment of indebtedness.

Sempra Common Stock Repurchases

On September 11, 2007, our board of directors authorized the repurchase of shares of our common stock, provided that the amounts spent for such purpose do not exceed the greater of $2 billion or amounts spent to purchase no more than 40,000,000 shares. On July 1, 2020, we entered into an ASR program under which we prepaid $500 million to repurchase shares of our common stock in a share forward transaction. The total number of shares purchased was determined by dividing the $500 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 July 2, 2020 through August 4, 2020, minus a fixed discount. The program was completed on August 4, 2020 with an aggregate of 4,089,375 shares of Sempra common stock repurchased at an average price of $122.27 per share. Following the completion of the ASR program, the aggregate dollar amount authorized by the September 11, 2007 share repurchase authorization was exhausted.

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. No shares have been repurchased under this authorization.

Other Noncontrolling Interests

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

OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
	Percent ownership held by noncontrolling interests				Equity held by noncontrolling interests
	September 30, 2021		December 31, 2020		September 30, 2021		December 31, 2020
Sempra Mexico:
IEnova	0.1	%	29.8	%	$	2	$	1,487
ICM Ventures Holdings B.V.	—		17.5		—		7
Sempra LNG:
ECA LNG Phase 1	16.6		29.0		28		46
Parent and other:
PXiSE	20.0		20.0		—		1
Total Sempra					$	30	$	1,541

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Sempra Mexico

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. In addition to being traded on the New York Stock Exchange, Sempra’s common stock is now also listed on the Mexican Stock Exchange under the ticker symbol SRE.MX. We acquired the IEnova shares at an exchange ratio of 0.0323 shares of our common stock for each one IEnova ordinary share. In connection with the exchange offer, we recorded an increase in Sempra’s shareholders’ equity of $1,361 million, net of $12 million in transactions costs, and increased our ownership interest in IEnova from 70.2% to 96.4%.

In September 2021, we acquired 51,014,545 publicly owned shares of IEnova for 4.0 billion Mexican pesos (approximately $202 million in U.S. dollars) in cash upon completion of our tender offer launched in the U.S. and Mexico in August 2021, which increased our ownership interest in IEnova from 96.4% to 99.9%. We acquired these IEnova shares at a price of 78.97 Mexican pesos per share (approximately $3.95 per share in U.S. dollars). Following the cash tender offer, we recorded a decrease in Sempra’s shareholders’ equity of $14 million, including $1 million in transaction costs. 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 remaining publicly owned IEnova shares for 78.97 Mexican pesos per share, the same price per share that was offered in our cash tender offer. The trust will be in place through the earlier of April 14, 2022 or the date on which we acquire all the remaining publicly owned IEnova shares.

As a result of the increase in our ownership interest in IEnova, we recorded an increase in Sempra’s shareholders’ equity of $84 million offset by a deferred income tax asset related to the outside basis difference in IEnova’s shares. Upon completing the sale of a 20% equity interest in Sempra Infrastructure Partners in October 2021, which we discuss below, we recorded $72 million in net income tax expense related to the utilization of this deferred income tax asset, net of the income tax effect reclassified from AOCI to earnings.

In the nine months ended September 30, 2020, IEnova repurchased 57,547,381 shares of its outstanding common stock held by NCI for $167 million, resulting in an increase in Sempra’s ownership interest in IEnova from 66.6% at December 31, 2019 to 69.2% at September 30, 2020.

In the first quarter of 2020, IEnova purchased additional shares in ICM Ventures Holdings B.V. for $9 million, increasing its ownership from 53.7% to 82.5%. ICM Ventures Holdings B.V. owns certain permits and land where IEnova is building a terminal for the receipt, storage and delivery of liquid fuels. In July 2021, IEnova acquired the remaining 17.5% interest held by NCI in ICM Ventures Holdings B.V. for $7 million.

Sempra LNG

In March 2020, Sempra LNG purchased for $7 million the 24.6% minority interest in Liberty Gas Storage LLC, which owns 100% of LA Storage, LLC, increasing Sempra LNG’s ownership in Liberty Gas Storage LLC to 100%. Prior to the purchase, the minority partner converted $22 million in notes payable due from Sempra LNG to equity. As a result of the purchase, we recorded an increase in Sempra’s shareholders’ equity of $2 million for the difference between the carrying value and fair value related to the change in ownership.

Sempra Infrastructure Partners

Sale of NCI. On October 1, 2021, Sempra, its wholly owned subsidiary, Sempra Infrastructure Partners (formerly Sempra Global), and KKR consummated the transactions contemplated under a purchase and contribution agreement dated April 4, 2021 (as amended on September 27, 2021 to reflect immaterial revisions prior to closing, the Purchase Agreement). Pursuant to the Purchase Agreement, KKR acquired for a purchase price of $3.37 billion, which remains subject to post-closing adjustments, newly designated Class A Units representing 20% of the equity interests of Sempra Infrastructure Partners. Prior to closing the transaction, we completed an internal legal reorganization to consolidate the assets of Sempra LNG and our ownership of IEnova under Sempra Global, which was renamed Sempra Infrastructure Partners. On October 1, 2021, Sempra Infrastructure Partners paid $149 million to KKR for reimbursement of certain expenses that KKR incurred in connection with closing the transaction. As of September 30, 2021, the composition of our reportable segments did not change.

At the closing of the transactions contemplated under the Purchase Agreement on October 1, 2021, we owned 99.9% of the outstanding ordinary shares of IEnova. Under the terms of the Purchase Agreement, the base purchase price was adjusted downward at closing by $1 million based on the number of IEnova ordinary shares we did not own at the closing. If we later acquire additional shares of IEnova after the closing, such additional shares will be acquired by Sempra Infrastructure Partners and KKR will provide 20% of the funding.

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We estimate that Sempra Infrastructure Partners had approximately $8.37 billion of direct and indirect net debt at the closing, and there will be a customary upward or downward adjustment to the purchase price to the extent the actual net debt at closing was greater or less than such estimated amount. Direct and indirect net debt at Sempra Infrastructure Partners includes consolidated long-term and short-term debt less cash at Sempra LNG and IEnova plus their proportionate ownership share of equity method investees’ long-term and short-term debt less cash.

Pursuant to the Purchase Agreement, we have agreed to indemnify Sempra Infrastructure Partners for, among other things, certain losses arising from liabilities of Sempra Infrastructure Partners and its subsidiaries to the extent not primarily relating to the undertaking of the business of Sempra Infrastructure Partners, and we have agreed to indemnify KKR for losses attributable to pre-closing taxes.

We have also entered into an accommodation and support agreement under which KKR has the ability to borrow from Sempra up to $300 million plus reimbursement of certain fees related to such borrowing, which we fully funded on November 1, 2021. This loan is due to be repaid in full no later than October 1, 2029 and bears compound interest at 5% per annum.

Limited Partnership Agreement. At the closing of the sale of NCI in Sempra Infrastructure Partners, Sempra and KKR entered into a limited partnership agreement (the LP Agreement), which governs our and their respective rights and obligations in respect of our ownership of Sempra Infrastructure Partners. We maintain control of Sempra Infrastructure Partners as the 80% owner with KKR having certain minority protections commensurate with the size of its investment.

Sempra Infrastructure Partners has two authorized classes of units, designated as “Class A Units” (which are common voting units) and “Sole Risk Interests.” If KKR approves our request that a project not be pursued jointly, or if KKR decides not to participate in any proposed project for which we nevertheless desire to make a positive final investment decision, we will be permitted to proceed with such project either independently through a different investment vehicle or as a “Sole Risk Project” within Sempra Infrastructure Partners and receive Sole Risk Interests in respect thereof. Sole Risk Projects are separated from other Sempra Infrastructure Partners projects and are conducted at our sole cost, expense and liability and we receive, through the acquisition of Sole Risk Interests, any economic and other benefits from such projects. KKR is not entitled to any benefits or rights in respect of any Sole Risk Project. The Guaymas-El Oro segment of the Sonora pipeline at IEnova currently constitutes a Sole Risk Project. Until a specified date, KKR has certain discretionary rights to cause the Guaymas-El Oro segment of the Sonora pipeline to cease to be a Sole Risk Project and be pursued jointly within Sempra Infrastructure Partners.

Under the LP Agreement, Sempra Infrastructure Partners is managed by a board of managers comprised of members designated by us and by KKR. Matters are generally decided by majority vote. The managers designated by us and the managers designated by KKR each, as a group, have voting power equivalent to the ownership percentage of their respective designating member. However, Sempra Infrastructure Partners and its controlled subsidiaries are prohibited from taking certain actions without the prior written approval of KKR (subject to KKR maintaining certain ownership thresholds in Sempra Infrastructure Partners).

The LP Agreement contains certain default remedies if we or KKR fails to fund any amounts required to be funded under the LP Agreement.

The LP Agreement also requires that Sempra Infrastructure Partners distribute to us and to KKR at least 85% of distributable cash flow of Sempra Infrastructure Partners and its subsidiaries on a quarterly basis, subject to certain exceptions and reserves. Generally, distributions from Sempra Infrastructure Partners are made to us and KKR on a pro rata basis in accordance with our and their respective ownership interests in Sempra Infrastructure Partners. However, KKR is entitled to certain priority distributions in the event of material deviations between certain specified projected cash flows and actual cash flows. Additionally, KKR is entitled to certain priority distributions in the event a specified project that reaches a positive final investment decision does not have projected internal rates of return over a specified threshold or in the event we have not made a positive final investment decision by a certain date on specified LNG projects that are currently in development.

In addition, under the LP Agreement, both parties are granted customary registration rights in the event of an initial public offering of Sempra Infrastructure Partners, which is subject to certain consent rights of KKR.

Management Agreement. At the closing of the transactions contemplated under the Purchase Agreement, Sempra Infrastructure Partners entered into a management agreement with Sempra to engage Sempra for certain staffing and general and administrative services. The management agreement governs the services that Sempra will provide to Sempra Infrastructure Partners and the charges associated with those services.

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Discontinued Operations

As we discuss in Note 5, we completed the sales of our equity interests in our Peruvian and Chilean businesses in the second quarter of 2020. The minority interests in Luz del Sur and Tecsur were deconsolidated upon the sale of our Peruvian businesses in April 2020, and the minority interests in Chilquinta Energía and its subsidiaries were deconsolidated upon the sale of our Chilean businesses in June 2020.

TRANSACTIONS WITH AFFILIATES

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

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AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	September 30, 2021		December 31, 2020
Sempra:
Total due from various unconsolidated affiliates – current	$	30	$	20
Sempra Mexico(1):
ESJ – Note due December 31, 2022, net of negligible allowance for credit losses at December 31, 2020(2)	$	—	$	85
IMG JV – Note due March 15, 2022, net of allowance for credit losses of $1 and $3 at September 30, 2021 and December 31, 2020, respectively(3)	684		695
Total due from unconsolidated affiliates – noncurrent	$	684	$	780
Sempra Mexico – TAG Pipelines Norte, S. de. R.L. de C.V. – Note due December 20, 2021(1)(4)	$	(42)	$	(41)
Various affiliates	—		(4)
Total due to unconsolidated affiliates – current	$	(42)	$	(45)
Sempra Mexico(1)(5):
TAG Pipelines Norte, S. de. R.L. de C.V.:
5.5% Note due January 9, 2024	$	(71)	$	(68)
5.5% Note due January 14, 2025	(21)		—
5.5% Note due July 16, 2025	(20)		—
TAG JV – 5.74% Note due December 17, 2029	(174)		(166)
Total due to unconsolidated affiliates – noncurrent	$	(286)	$	(234)
SDG&E:
Total due from various unconsolidated affiliates – current	$	1	$	—
Sempra	$	(45)	$	(38)
SoCalGas	(9)		(21)
Various affiliates	(7)		(5)
Total due to unconsolidated affiliates – current	$	(61)	$	(64)
Income taxes due from Sempra(6)	$	29	$	—
SoCalGas:
SDG&E	$	9	$	21
Various affiliates	2		1
Total due from unconsolidated affiliates – current	$	11	$	22
Sempra	$	(45)	$	(31)
Total due to unconsolidated affiliates – current	$	(45)	$	(31)
Income taxes due from (to) Sempra(6)	$	1	$	(37)

(1)    Amounts include principal balances plus accumulated interest outstanding.

(2)    U.S. dollar-denominated loan at a variable interest rate based on 1-month LIBOR plus 196 bps (2.11% at December 31, 2020). At December 31, 2020, $1 million of accrued interest receivable is included in Due from Unconsolidated Affiliates – Current. In March 2021, IEnova acquired the 50% equity interest in ESJ that it did not already own and ESJ became a wholly owned, consolidated subsidiary, resulting in the elimination of this note receivable.

(3)    Mexican peso-denominated revolving line of credit for up to 14.2 billion Mexican pesos or approximately $689 million U.S. dollar-equivalent at September 30, 2021, at a variable interest rate based on the 91-day Interbank Equilibrium Interest Rate plus 220 bps (7.02% at September 30, 2021), to finance construction of a natural gas marine pipeline. At both September 30, 2021 and December 31, 2020, $2 million of accrued interest receivable is included in Due from Unconsolidated Affiliates – Current. At September 30, 2021, we classified this revolving line of credit as noncurrent because we expect to extend the maturity date on a long-term basis prior to its stated maturity date.

(4)    U.S. dollar-denominated loan at a variable interest rate based on 6-month LIBOR plus 290 bps (3.06% at September 30, 2021).

(5)     U.S. dollar-denominated loans at fixed interest rates.

(6)    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.

The following table summarizes income statement information from unconsolidated affiliates.

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INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Sempra:
Revenues	$	7	$	9	$	22	$	31
Cost of sales	—		9		11		35
Interest income	11		12		38		44
Interest expense	4		4		11		11
SDG&E:
Revenues	$	3	$	1	$	7	$	4
Cost of sales	20		17		75		56
SoCalGas:
Revenues	$	24	$	23	$	72	$	61
Cost of sales(1)	(2)		2		1		2

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

Guarantees

Sempra provided guarantees related to Cameron LNG JV’s construction-period debt, which were terminated in March 2021, as well as 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 September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Sempra:
Allowance for equity funds used during construction	$	31	$	34	$	103	$	96
Investment gains, net(1)	—		16		28		9
(Losses) gains on interest rate and foreign exchange instruments, net	(3)		19		(26)		(129)
Foreign currency transaction (losses) gains, net(2)	(17)		15		(10)		(95)
Non-service component of net periodic benefit cost	(66)		(48)		(52)		(45)
Fine related to Energy Efficiency Program inquiry	—		(6)		—		(6)
Interest on regulatory balancing accounts, net	2		—		5		13
Sundry, net	(2)		(1)		4		(6)
Total	$	(55)	$	29	$	52	$	(163)
SDG&E:
Allowance for equity funds used during construction	$	18	$	21	$	63	$	61
Non-service component of net periodic benefit cost	(15)		(18)		(10)		(15)
Fine related to Energy Efficiency Program inquiry	—		(6)		—		(6)
Interest on regulatory balancing accounts, net	2		—		5		8
Sundry, net	(1)		1		3		(1)
Total	$	4	$	(2)	$	61	$	47
SoCalGas:
Allowance for equity funds used during construction	$	13	$	11	$	36	$	29
Non-service component of net periodic benefit cost	(49)		(15)		(30)		(3)
Interest on regulatory balancing accounts, net	—		—		—		5
Sundry, net	(3)		(3)		(8)		(10)
Total	$	(39)	$	(7)	$	(2)	$	21

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

(2)    Includes losses of $18 million and $13 million in the three months and nine months ended September 30, 2021, respectively, and gains of $15 million and losses of $120 million in the three months and nine months ended September 30, 2020, respectively, from translation to U.S. dollars of a Mexican peso-denominated loan to IMG JV, 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 (BENEFIT) EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended September 30,						Nine months ended September 30,
	2021			2020			2021			2020
Sempra:
Income tax (benefit) expense from continuing operations	$	(342)		$	99		$	(45)		$	60
(Loss) income from continuing operations before income taxes and equity earnings	$	(1,365)		$	201		$	(316)		$	1,061
Equity earnings, before income tax(1)	137			117			457			158
Pretax (loss) income	$	(1,228)		$	318		$	141		$	1,219
Effective income tax rate	28		%	31		%	(32)		%	5		%
SDG&E:
Income tax expense	$	90		$	33		$	168		$	161
Income before income taxes	$	295		$	211		$	771		$	794
Effective income tax rate	31		%	16		%	22		%	20		%
SoCalGas:
Income tax (benefit) expense	$	(437)		$	(6)		$	(335)		$	95
(Loss) income before income taxes	$	(1,563)		$	(30)		$	(959)		$	521
Effective income tax rate	28		%	20		%	35		%	18		%

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

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

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

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

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

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

▪utility self-developed software expenditures

▪depreciation on a certain portion of utility plant assets

▪state income taxes

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

We record income tax (expense) benefit from the transactional effects of foreign currency and inflation. Through the first quarter of 2021, such effects were offset by net gains (losses) from foreign currency derivatives that were hedging Sempra Mexico parent’s exposure to movements in the Mexican peso from its controlling interest in IEnova.

Discontinued Operations

In January 2019, our board of directors approved a plan to sell our South American businesses. We completed the sales in the second quarter of 2020, as we discuss in Note 5. Because of our decision to sell our South American businesses, we no longer asserted indefinite reinvestment of basis differences related to these businesses. Accordingly, in the nine months ended September 30, 2020, we recorded a $7 million income tax benefit from changes in outside basis differences in our discontinued operations in South America.

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NOTE 2. NEW ACCOUNTING STANDARDS

We describe below recent accounting pronouncements that have had or may have a significant effect on our financial condition, results of operations, 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 conversion and cash conversion features. The standard also amends ASC 260, “Earnings Per Share,” as follows:

▪requires an entity to apply the if-converted method when calculating diluted EPS for convertible instruments and no longer use the treasury stock method, which was previously allowed for certain convertible instruments;

▪requires an entity to include the effect of potential share settlement in the diluted EPS calculation when an instrument may be settled in cash or shares, and no longer allows an entity to rebut the presumption of share settlement if it has a history or policy of cash settlement;

▪requires an entity to include equity-classified convertible preferred stock that contains down-round features whereby, if the down-round feature is triggered, its effect is treated as a dividend and as a reduction of income available to common shareholders in basic EPS;

▪clarifies that the average market price should be used to calculate the diluted EPS denominator when the exercise price or the number of shares that may be issued is variable, except for certain contingently issuable shares; and

▪clarifies that the weighted-average share count from each quarter should be used when calculating the year-to-date weighted-average share count.

For public entities, ASU 2020-06 is effective for fiscal years beginning after December 15, 2021, including interim periods therein, with early adoption permitted for fiscal years beginning after December 15, 2020. 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 plan to adopt the standard on January 1, 2022 and are currently evaluating the effect of the standard on our ongoing financial reporting.

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.

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DISAGGREGATED REVENUES
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Mexico		Sempra LNG		Consolidating adjustments and Parent and Other		Sempra
	Three months ended September 30, 2021
By major service line:
Utilities	$	1,369	$	966	$	17	$	—	$	(27)	$	2,325
Energy-related businesses	—		—		324		144		(145)		323
Revenues from contracts with customers	$	1,369	$	966	$	341	$	144	$	(172)	$	2,648
By market:
Gas	$	145	$	966	$	231	$	143	$	(165)	$	1,320
Electric	1,224		—		110		1		(7)		1,328
Revenues from contracts with customers	$	1,369	$	966	$	341	$	144	$	(172)	$	2,648
Revenues from contracts with customers	$	1,369	$	966	$	341	$	144	$	(172)	$	2,648
Utilities regulatory revenues	95		140		—		—		—		235
Other revenues	—		—		256		(25)		(101)		130
Total revenues	$	1,464	$	1,106	$	597	$	119	$	(273)	$	3,013
	Nine months ended September 30, 2021
By major service line:
Utilities	$	3,755	$	3,685	$	61	$	—	$	(79)	$	7,422
Energy-related businesses	—		—		859		260		(282)		837
Revenues from contracts with customers	$	3,755	$	3,685	$	920	$	260	$	(361)	$	8,259
By market:
Gas	$	580	$	3,685	$	635	$	257	$	(334)	$	4,823
Electric	3,175		—		285		3		(27)		3,436
Revenues from contracts with customers	$	3,755	$	3,685	$	920	$	260	$	(361)	$	8,259
Revenues from contracts with customers	$	3,755	$	3,685	$	920	$	260	$	(361)	$	8,259
Utilities regulatory revenues	364		53		—		—		—		417
Other revenues	—		—		448		107		(218)		337
Total revenues	$	4,119	$	3,738	$	1,368	$	367	$	(579)	$	9,013

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DISAGGREGATED REVENUES (CONTINUED)
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Mexico		Sempra LNG		Consolidating adjustments and Parent and other		Sempra
	Three months ended September 30, 2020
By major service line:
Utilities	$	1,301	$	813	$	12	$	—	$	(25)	$	2,101
Energy-related businesses	—		—		244		35		(32)		247
Revenues from contracts with customers	$	1,301	$	813	$	256	$	35	$	(57)	$	2,348
By market:
Gas	$	126	$	813	$	159	$	33	$	(54)	$	1,077
Electric	1,175		—		97		2		(3)		1,271
Revenues from contracts with customers	$	1,301	$	813	$	256	$	35	$	(57)	$	2,348
Revenues from contracts with customers	$	1,301	$	813	$	256	$	35	$	(57)	$	2,348
Utilities regulatory revenues	171		29		—		—		—		200
Other revenues	—		—		95		28		(27)		96
Total revenues	$	1,472	$	842	$	351	$	63	$	(84)	$	2,644
	Nine months ended September 30, 2020
By major service line:
Utilities	$	3,610	$	3,261	$	42	$	—	$	(66)	$	6,847
Energy-related businesses	—		—		616		56		(40)		632
Revenues from contracts with customers	$	3,610	$	3,261	$	658	$	56	$	(106)	$	7,479
By market:
Gas	$	518	$	3,261	$	439	$	51	$	(98)	$	4,171
Electric	3,092		—		219		5		(8)		3,308
Revenues from contracts with customers	$	3,610	$	3,261	$	658	$	56	$	(106)	$	7,479
Revenues from contracts with customers	$	3,610	$	3,261	$	658	$	56	$	(106)	$	7,479
Utilities regulatory revenues	366		(14)		—		—		—		352
Other revenues	—		—		277		199		(108)		368
Total revenues	$	3,976	$	3,247	$	935	$	255	$	(214)	$	8,199

REVENUES FROM CONTRACTS WITH CUSTOMERS

Utilities Revenues

In connection with the COVID-19 pandemic, the California Utilities implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for all customers (except for SoCalGas’ noncore customers), waiving late payment fees, and offering flexible payment plans. Such measures ended on June 30, 2021, except for the suspension of service disconnections that ended on September 30, 2021. At the CPUC’s direction, the California Utilities have started to automatically enroll residential and small business customers with past-due balances in long-term repayment plans. The CPUC is continuing to consider the impacts of any state or federal relief programs on customer arrearages and if further debt relief is warranted.

53

Remaining Performance Obligations

For contracts greater than one year, at September 30, 2021, we expect to recognize revenue related to the fixed fee component of the consideration as shown below. SoCalGas did not have any such performance obligations at September 30, 2021.

REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra		SDG&E
2021 (excluding first nine months of 2021)	$	88	$	1
2022	368		4
2023	367		4
2024	367		4
2025	364		4
Thereafter	4,129		67
Total revenues to be recognized	$	5,683	$	84

(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 nine months ended September 30, 2021 or 2020.

CONTRACT LIABILITIES
(Dollars in millions)
	2021		2020
Sempra:
Contract liabilities at January 1	$	(207)	$	(163)
Revenue from performance obligations satisfied during reporting period	36		3
Payments received in advance	(1)		—
Contract liabilities at September 30(1)	$	(172)	$	(160)
SDG&E:
Contract liabilities at January 1	$	(87)	$	(91)
Revenue from performance obligations satisfied during reporting period	3		3
Contract liabilities at September 30(1)	$	(84)	$	(88)

(1)     At September 30, 2021, includes $8 million and $4 million in Other Current Liabilities and $164 million and $80 million 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.

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RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS
(Dollars in millions)
	September 30, 2021		December 31, 2020
Sempra:
Accounts receivable – trade, net	$	1,216	$	1,447
Accounts receivable – other, net	17		12
Due from unconsolidated affiliates – current(1)	2		3
Other long-term assets	115		—
Total	$	1,350	$	1,462
SDG&E:
Accounts receivable – trade, net	$	642	$	573
Accounts receivable – other, net	11		8
Due from unconsolidated affiliates – current(1)	3		2
Other long-term assets	47		—
Total	$	703	$	583
SoCalGas:
Accounts receivable – trade, net	$	462	$	786
Accounts receivable – other, net	6		4
Other long-term assets	68		—
Total	$	536	$	790

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

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 currently 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.

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REGULATORY ASSETS AND LIABILITIES

We show the details of regulatory assets and liabilities in the following table.

REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	September 30, 2021		December 31, 2020
SDG&E:
Fixed-price contracts and other derivatives	$	(88)	$	(53)
Deferred income taxes recoverable in rates	72		22
Pension and other postretirement benefit plan obligations	19		50
Removal obligations	(2,228)		(2,121)
Environmental costs	55		56
Sunrise Powerlink fire mitigation	121		121
Regulatory balancing accounts(1)(2)
Commodity – electric	85		72
Gas transportation	23		35
Safety and reliability	60		67
Public purpose programs	(138)		(158)
2019 GRC retroactive impacts	14		56
Other balancing accounts	535		233
Other regulatory assets, net(2)	110		72
Total SDG&E	(1,360)		(1,548)
SoCalGas:
Deferred income taxes recoverable (refundable) in rates	9		(82)
Pension and other postretirement benefit plan obligations	342		417
Employee benefit costs	37		37
Removal obligations	(649)		(685)
Environmental costs	35		36
Regulatory balancing accounts(1)(2)
Commodity – gas, including transportation	(138)		(56)
Safety and reliability	299		335
Public purpose programs	(274)		(253)
2019 GRC retroactive impacts	51		202
Other balancing accounts	85		(58)
Other regulatory assets, net(2)	160		75
Total SoCalGas	(43)		(32)
Sempra Mexico:
Deferred income taxes recoverable in rates	80		80
Total Sempra	$	(1,323)	$	(1,500)

(1)    At September 30, 2021 and December 31, 2020, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $331 million and $139 million, respectively, and for SoCalGas was $472 million and $218 million, respectively.

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

CALIFORNIA UTILITIES

COVID-19 Pandemic Protections

In connection with the COVID-19 pandemic, the California Utilities implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for all customers (except for SoCalGas’ noncore customers), waiving late payment fees, and offering flexible payment plans. Such measures ended on June 30, 2021, except for the suspension of service disconnections that ended on September 30, 2021. At the CPUC’s direction, the California Utilities have started to automatically enroll residential and small business customers with past-due balances in long-term repayment plans. The CPUC is continuing to consider the impacts of any state or federal relief programs on customer arrearages and if further debt relief is warranted.

Each of the California Utilities has been authorized to track and request recovery of incremental costs associated with complying with customer protection measures implemented by the CPUC related to the COVID-19 pandemic, including costs associated

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with suspending service disconnections and uncollectible expenses that arise from customers’ failure to pay. The California Utilities expect to pursue recovery of small and medium-large commercial and industrial customers’ tracked costs in rates in a future CPUC proceeding, which recovery is not assured. Uncollectible expenses related to residential customers are recorded in a two-way balancing account as we discuss below.

Disconnection OIR

In June 2020, the CPUC issued a decision to adopt certain customer protections to reduce residential customer disconnections and improve reconnection processes, including, among other things, imposing limitations on service disconnections, elimination of deposit requirements and reconnection fees, establishment of the AMP that provides successfully participating, income-qualified residential customers with relief from outstanding utility bill amounts, and increased outreach and marketing efforts. As permitted by the decision, each of the California Utilities has established a two-way balancing account to record the uncollectible expenses associated with residential customers’ inability to pay their electric or gas bills, including as a result of the relief from outstanding utility bill amounts provided under the AMP.

CPUC GRC

The CPUC uses GRCs to set rates designed to allow the California Utilities to recover their reasonable operating costs and to provide the opportunity to realize their authorized rates of return on their investments.

In January 2020, the CPUC issued a final decision implementing a four-year GRC cycle for California IOUs and the California Utilities were directed to file a petition for modification to revise their 2019 GRC to add two additional attrition years, resulting in a transitional five-year GRC period (2019-2023). The California Utilities filed the petition in April 2020.

In May 2021, the CPUC issued a final decision approving the California Utilities’ request to continue their authorized post-test year mechanisms for 2022 and 2023. For SDG&E, the decision authorizes revenue requirement increases of $87 million (3.92%) for 2022 and $86 million (3.70%) for 2023. For SoCalGas, the decision authorizes revenue requirement increases of $142 million (4.53%) for 2022 and $130 million (3.97%) for 2023.

The 2019 GRC FD clarified that differences between incurred and forecasted income tax expense due to forecasting differences are not subject to tracking in the income tax expense memorandum account beginning in 2019. SDG&E and SoCalGas previously recorded regulatory liabilities, inclusive of interest, associated with the 2016 through 2018 tracked forecasting differences of $86 million and $89 million, respectively. In April 2020, the CPUC confirmed treatment of the two-way income tax expense memorandum account for these 2016 through 2018 balances, at which time the California Utilities released these regulatory liability balances to revenues and regulatory interest.

We provide additional information concerning the 2019 GRC FD in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report.

CPUC Cost of Capital

A CPUC cost of capital proceeding determines a utility’s authorized capital structure and authorized return on rate base. In December 2019, the CPUC approved the cost of capital and rate structures 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. The CCM considers 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. 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.

Alternatively, under the CCM, each of the California Utilities 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. In August 2021, SDG&E filed an application with the CPUC to update its cost of capital effective January 1, 2022 due to the ongoing effects of the COVID-19 pandemic. In this application, SDG&E proposed to adjust its authorized capital structure by increasing its common equity ratio from 52% to 54%. SDG&E also proposed to increase its authorized ROE from 10.20% to 10.55% and decrease its authorized cost of debt from 4.59% to 3.84%. As a result, SDG&E’s proposed return on rate base would decrease from 7.55% to 7.46% if such application is approved by the CPUC as filed. SDG&E filed a joint motion with PG&E and Edison to consolidate all three utilities’ cost of capital applications given the overlapping issues of law and fact, which joint motion was granted in October 2021.

For the measurement period ended September 30, 2021, the CCM would trigger for SDG&E 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

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4.498%. However, SDG&E’s application to update its cost of capital effective January 1, 2022, if accepted by the CPUC, would supersede the CCM from applying. If such application is not accepted, the CCM would be effective 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. SDG&E has requested that a final CPUC decision on its interim cost of capital application be issued in the first half of 2022.

For the measurement period ended September 30, 2021, the CCM was not triggered for SoCalGas. SoCalGas expects to file its next cost of capital application in April 2022 for a January 1, 2023 effective date.

SDG&E

FERC Rate Matters and Cost of Capital

SDG&E files separately with the FERC for its authorized ROE on FERC-regulated electric transmission operations and assets.

SDG&E’s TO4 ROE of 10.05% was the basis of SDG&E’s FERC-related revenue recognition until March 2020, when the FERC approved the settlement terms that SDG&E and all settling parties reached in October 2019 on SDG&E’s TO5 filing. The settlement agreement provided for a ROE of 10.60%, consisting of a base ROE of 10.10% plus an additional 50 bps for participation in the California ISO (the California ISO adder). If the FERC issues an order ruling that California IOUs are no longer eligible for the California ISO adder, SDG&E would refund the California ISO adder as of the refund effective date (June 1, 2019) if such a refund is determined to be required by the terms of the TO5 settlement. The TO5 term is effective June 1, 2019 and shall remain in effect each calendar year until terminated by a notice at least six months before the end of a calendar year. In the first quarter of 2020, SDG&E recorded retroactive revenues of $12 million related to 2019, and additional FERC revenues of $17 million to conclude a rate base matter, net of certain refunds to be paid to CPUC-jurisdictional customers.

Energy Efficiency Program Inquiry

In January 2020, the CPUC issued a ruling seeking comments on a report prepared by its consultant regarding SDG&E’s Upstream Lighting Program for the program year 2017. The CPUC subsequently expanded the scope of the comments to cover the program year 2018. The Upstream Lighting Program was one of SDG&E’s Energy Efficiency Programs designed to produce energy efficiency savings for which SDG&E could earn a performance-based incentive.

Pursuant to the CPUC ruling, intervenors representing ratepayers questioned SDG&E’s management of the program and alleged that certain program expenditures did not benefit the purpose of the program. As a result of the inquiry, SDG&E voluntarily expanded its review to include the program year 2019. Based on this review, SDG&E concluded some concessions were appropriate, which included refunding certain costs to customers and reducing certain performance-based incentives. Accordingly, in the three months and nine months ended September 30, 2020, SDG&E reduced revenues by $36 million and $51 million, respectively, and recorded a fine of $6 million in Other (Expense) Income, Net, on the SDG&E and Sempra Condensed Consolidated Statements of Operations. The after-tax impact for the three months and nine months ended September 30, 2020 was $29 million and $44 million, respectively. In October 2020, SDG&E executed a settlement agreement with intervenors consistent with these concessions. In September 2021, the CPUC approved the settlement agreement.

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. The OSC stemmed from a short period of transitional energy efficiency (EE) codes and standards advocacy activities undertaken by SoCalGas in 2018, following a CPUC decision disallowing SoCalGas’ future engagement in EE statewide codes and standards advocacy. We are awaiting a CPUC decision.

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, whether its shareholders should bear the costs of those advocacy activities, and to address whether any other remedies are appropriate. The scope of this OSC was later expanded to include EE program years 2014 and 2015, and SoCalGas’ engagement with local governments on proposed reach codes. In April 2021, the assigned Administrative Law Judge issued a Presiding Officer’s Decision (POD) on the second OSC. The POD 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. The POD, which is currently under appeal by intervenors, orders customer refunds that SoCalGas expects will be negligible (subject to a CPUC audit). Additionally, the POD precludes SoCalGas

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from seeking cost recovery associated with EE codes and standards advocacy programs until lifted by the CPUC, and orders certain nonfinancial remedies.

Intervenors in these OSCs have suggested the CPUC order various financial and non-financial penalties. If the CPUC were to assess fines or penalties on SoCalGas associated with these OSCs, they could be material.

NOTE 5. ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS

ACQUISITION

Sempra Mexico

ESJ

In March 2021, IEnova completed the acquisition of Saavi Energía’s 50% equity interest in ESJ for a purchase price of approximately $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 IEnova that eliminates upon consolidation). IEnova previously accounted for its 50% interest in ESJ as an equity method investment. This acquisition increased IEnova’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. IEnova 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. ESJ is constructing a second wind power generation facility with a nameplate capacity of 108 MW that we expect will be completed in the first quarter of 2022.

DISCONTINUED OPERATIONS

In April 2020, we completed the sale of our equity interests in our Peruvian businesses, including our 83.6% interest in Luz del Sur and its interest in Tecsur, to an affiliate of China Yangtze Power International (Hongkong) Co., Limited for cash proceeds of $3,549 million, net of transaction costs and as adjusted for post-closing adjustments, and recorded a pretax gain of $2,271 million ($1,499 million after tax).

In June 2020, we completed the sale of our equity interests in our Chilean businesses, including our 100% interest in Chilquinta Energía and Tecnored and our 50% interest in Eletrans, to State Grid International Development Limited for cash proceeds of $2,216 million, net of transaction costs and as adjusted for post-closing adjustments, and recorded a pretax gain of $628 million ($248 million after tax).

In the three months and nine months ended September 30, 2020, the pretax gains from the sales of our South American businesses are included in (Loss) Gain on Sale of Discontinued Operations in the table below and the after-tax gains are included in (Loss) Income from Discontinued Operations, Net of Income Tax, on Sempra’s Condensed Consolidated Statements of Operations.

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Summarized results from discontinued operations were as follows:

DISCONTINUED OPERATIONS
(Dollars in millions)
	Three months ended September 30, 2020(1)		Nine months ended September 30, 2020(2)
Revenues	$	—	$	570
Cost of sales	—		(364)
(Loss) gain on sale of discontinued operations	(16)		2,899
Operating expenses	—		(66)
Interest and other	—		(3)
Income before income taxes	(16)		3,036
Income tax benefit (expense)	9		(1,186)
(Loss) income from discontinued operations, net of income tax	(7)		1,850
Earnings attributable to noncontrolling interests	—		(10)
(Losses) earnings from discontinued operations attributable to Sempra	$	(7)	$	1,840

(1)    Represents post-closing adjustments related to the sale of our equity interests in our Chilean businesses.    

(2)    Results include activity until the sale of our Peruvian businesses on April 24, 2020 and Chilean businesses on June 24, 2020.

As a result of the sales of our South American businesses, in the second quarter of 2020, we reclassified $645 million of cumulative foreign currency translation losses from AOCI to (Loss) Gain on Sale of Discontinued Operations, which is included in (Loss) Income from Discontinued Operations, Net of Income Tax, on Sempra’s Condensed Consolidated Statements of Operations.

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 nine months ended September 30, 2021 and 2020, Sempra contributed $151 million and $209 million, respectively, to Oncor Holdings, and Oncor Holdings distributed $239 million and $220 million, respectively, to Sempra. Additionally, in the nine months ended September 30, 2021, Oncor Holdings distributed a $361 million return of investment to Sempra.

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

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SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Operating revenues	$	1,286	$	1,232	$	3,572	$	3,394
Operating expenses	(866)		(819)		(2,531)		(2,387)
Income from operations	420		413		1,041		1,007
Interest expense	(104)		(102)		(308)		(305)
Income tax expense	(54)		(50)		(124)		(115)
Net income	255		255		587		557
Noncontrolling interest held by TTI	(51)		(50)		(118)		(111)
Earnings attributable to Sempra(1)	204		205		469		446

(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 MEXICO

ESJ

As we discuss in Note 5, in March 2021, IEnova completed the acquisition of the remaining 50% equity interest in ESJ and ESJ became a wholly owned, consolidated subsidiary. Prior to the acquisition date, IEnova owned 50% of ESJ and accounted for its interest as an equity method investment. In the nine months ended September 30, 2021 and 2020, ESJ distributed a $4 million and $8 million, respectively, return of investment to IEnova.

SEMPRA LNG

Cameron LNG JV

In the nine months ended September 30, 2021, Cameron LNG JV distributed to Sempra LNG $496 million, of which $165 million relates to the distribution from Cameron LNG JV’s SDSRA that we discuss below.

In the nine months ended September 30, 2020, Sempra LNG contributed $54 million to Cameron LNG JV, and Cameron LNG JV distributed to Sempra LNG $209 million and a return of investment of $803 million.

In March 2021, Cameron LNG JV reached financial completion of the three-train liquefaction project, and Sempra’s related guarantees for a maximum aggregate amount of $4.0 billion were terminated. We discuss these guarantees in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.

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 LNG 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 LNG from the SDSRA, or $165 million. We recorded a guarantee liability of $22 million in June 2021, with an associated carrying value of $22 million at September 30, 2021, for the fair value of the promissory note, which is being reduced over the duration of the guarantee through Sempra LNG’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 LNG 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

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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 LNG’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 LNG 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 LNG 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 LNG 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 LNG.

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 LNG 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 September 30, 2021, the fair value of the Support Agreement was $5 million, of which $7 million is included in Other Current Assets offset by $2 million included in Deferred Credits and Other on Sempra’s Condensed Consolidated Balance Sheet.

PARENT AND OTHER

RBS Sempra Commodities

As we discuss in Note 11, in the nine months ended September 30, 2020, we recorded a charge of $100 million in Equity Earnings on Sempra’s Condensed Consolidated Statement of Operations representing our share of estimated losses in excess of the carrying value of our equity method investment in RBS Sempra Commodities. In the nine months ended September 30, 2021, we reduced this charge by $50 million based on the favorable outcome of a settlement with HMRC and revised assumptions on the High Court of Justice case.

NOTE 7. DEBT AND CREDIT FACILITIES

LINES OF CREDIT

Primary U.S. Committed Lines of Credit

In May 2021, Sempra Global assigned its $3.2 billion, five-year committed line of credit facility to Sempra and Sempra assumed all rights and responsibilities under the credit agreement. Also, in May 2021, Sempra established a commercial paper program to replace Sempra Global’s commercial paper program that was terminated in June 2021.

At September 30, 2021, Sempra had an aggregate capacity of $6.7 billion from primary U.S. committed lines of credit, which provide liquidity and support commercial paper. The principal terms of these committed lines of credit, which expire in May 2024, are described below and in Note 7 of the Notes to Consolidated Financial Statements in the Annual Report.

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PRIMARY U.S. COMMITTED LINES OF CREDIT
(Dollars in millions)
	September 30, 2021
	Total facility		Commercial paper outstanding(1)(2)		Available unused credit
Sempra(3)	$	4,435	$	(2,112)	$	2,323
SDG&E(4)	1,500		—		1,500
SoCalGas(4)	750		—		750
Total	$	6,685	$	(2,112)	$	4,573

(1)    Because the commercial paper programs are supported by these lines, we reflect the amount of commercial paper outstanding as a reduction to the available unused credit.

(2)    Commercial paper outstanding is before reductions of a negligible amount of unamortized discount.

(3)    The facility also provides for issuance of $200 million of letters of credit on behalf of Sempra with the amount of borrowings otherwise available under the facility reduced by the amount of outstanding letters of credit. Subject to obtaining commitments from existing or new lenders and satisfaction of other specified conditions, Sempra has the right to increase the letter of credit commitment up to $500 million. No letters of credit were outstanding at September 30, 2021.

(4)    The facility also provides for issuance of $100 million of letters of credit on behalf of the borrowing utility with the amount of borrowings otherwise available under the facility reduced by the amount of outstanding letters of credit. Subject to obtaining commitments from existing or new lenders and satisfaction of other specified conditions, the borrowing utility has the right to increase the letter of credit commitment up to $250 million. No letters of credit were outstanding at September 30, 2021.

Sempra, SDG&E and SoCalGas each must maintain a ratio of indebtedness to total capitalization (as defined in each of the applicable credit facilities) of no more than 65% at the end of each quarter. At September 30, 2021, each entity was in compliance with this ratio under its respective credit facility.

Foreign Committed Lines of Credit

Our foreign operations in Mexico have committed lines of credit with an aggregate capacity of $1.9 billion at September 30, 2021. The principal terms of these committed lines of credit are described in Note 7 of the Notes to Consolidated Financial Statements in the Annual Report.

FOREIGN COMMITTED LINES OF CREDIT
(U.S. dollar equivalent in millions)
	September 30, 2021
Expiration date of facility	Total facility		Amounts outstanding		Available unused credit
February 2024	$	1,500	$	—	$	1,500
September 2023(1)	350		(294)		56
Total	$	1,850	$	(294)	$	1,556

(1)    In September 2021, IEnova amended this revolving credit facility to increase the amount available under the facility from $280 million to $350 million and extend the expiration of the facility from September 2021 to September 2023. Borrowings continue to bear interest at a per annum rate equal to 3-month LIBOR plus 54 bps.

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Foreign Uncommitted Lines of Credit

In addition to our committed lines of credit, our foreign operations in Mexico have uncommitted lines of credit with an aggregate capacity of $470 million at September 30, 2021, which are generally used for working capital requirements.

FOREIGN UNCOMMITTED LINES OF CREDIT
(U.S. dollar equivalent in millions)
		September 30, 2021
Expiration date of facility	Borrowing denomination	Total facility		Amounts outstanding		Available unused credit
September 2022(1)	U.S. dollars	$	250	$	(250)	$	—
August 2023(2)	U.S. dollars or Mexican pesos	100		(37)		63
October 2023(3)	U.S. dollars	100		—		100
October 2023(4)	U.S. dollars or Mexican pesos	20		—		20
Total		$	470	$	(287)	$	183

(1)    IEnova’s one-year credit agreement under which borrowings bear interest at a per annum rate equal to 3-month LIBOR plus 10 bps.

(2)    ECA LNG Phase 1’s two-year credit agreement under which outstanding amounts were borrowed in Mexican pesos and bear interest at a variable rate based on the 28-day Interbank Equilibrium Interest Rate plus 105 bps and are before reductions from negligible unamortized discount. Borrowings made in U.S. dollars bear interest at a variable rate based on the 1-month or 3-month LIBOR plus 105 bps.

(3)    IEnova’s three-year credit agreement under which borrowings bear interest at a per annum rate equal to 6-month LIBOR plus 52 bps.

(4)    IEnova’s three-year credit agreement under which borrowings made in Mexican pesos bear interest at a variable rate based on the 28-day Interbank Equilibrium Interest Rate plus an applicable margin. Borrowings made in U.S. dollars bear interest at a variable rate based on 1-month LIBOR plus an applicable margin. The applicable margin is determined on the date of borrowing.

Letters of Credit

Outside of our domestic and foreign committed credit facilities, we have bilateral unsecured standby letter of credit capacity with select lenders that is uncommitted and supported by reimbursement agreements. At September 30, 2021, we had approximately $697 million in standby letters of credit outstanding under these agreements.

TERM LOAN

In June 2021, SDG&E entered into a $375 million, 364-day term loan with a maturity date of June 27, 2022. At September 30, 2021, $375 million, net of negligible issuance costs, was outstanding under the term loan. The borrowing bears interest at benchmark rates plus 62.5 bps. The term loan provides SDG&E with additional liquidity outside of its line of credit.

WEIGHTED-AVERAGE INTEREST RATES

The weighted-average interest rates on the total short-term debt at September 30, 2021 and December 31, 2020 were as follows:

WEIGHTED-AVERAGE INTEREST RATES
	September 30, 2021		December 31, 2020
Sempra	0.39	%	0.83	%
SDG&E	0.76		—
SoCalGas	—		0.14

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LONG-TERM DEBT

SDG&E

In August 2021, SDG&E issued $750 million of 2.95% green first mortgage bonds maturing in 2051 and received proceeds of $737 million (net of debt discount, underwriting discounts and debt issuance costs of $13 million). SDG&E intends to use the net proceeds to finance or refinance eligible projects that fall into one or more of the following categories: climate change adaptation, clean energy solutions and clean transportation.

Sempra Mexico

As we discuss in Note 5, through its acquisition of ESJ, Sempra Mexico assumed a $177 million (net of $6 million in unamortized debt issuance costs) variable rate loan payable to a syndicate of five lenders that matures in June 2033. To moderate exposure to interest rate and associated cash flow variability, ESJ entered into floating-to-fixed rate swaps for 90% of the principal balance, resulting in a fixed rate of 6.13%. The remaining 10% of the principal balance bears interest at 6-month LIBOR plus a margin of 2.63% with an increase of 25 bps every four years (2.80% at September 30, 2021). On October 8, 2021, Sempra Mexico used proceeds from borrowings against its committed and uncommitted lines of credit to fully repay $175 million of outstanding principal plus accrued and unpaid interest on the ESJ loan prior to its scheduled maturity in 2033, and recognized approximately $16 million ($10 million after tax and NCI) in charges associated with hedge termination costs and a write-off of unamortized debt issuance costs.

On October 13, 2021, Sempra Mexico used proceeds from borrowings against its committed and uncommitted lines of credit to fully repay $375 million of outstanding principal plus accrued and unpaid interest on the Ventika fixed- and variable-rate loans prior to scheduled maturity dates through 2032, and recognized approximately $34 million ($20 million after tax and NCI) in charges associated with hedge termination costs and a write-off of unamortized debt issuance costs.

Sempra LNG

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. At September 30, 2021 and December 31, 2020, $291 million and $17 million, respectively, was outstanding, with a weighted-average interest rate of 2.84% and 2.82%, respectively. We discuss the details of this agreement in Note 7 of the Notes to Consolidated Financial Statements in the Annual Report.

Parent and Other

On November 1, 2021, Sempra issued notices to redeem, at respective make-whole redemption prices, an aggregate principal amount of $2.35 billion of senior unsecured notes prior to scheduled maturities in 2022 through 2025. Upon redemption, which is scheduled to occur in December 2021, we expect to recognize approximately $128 million ($93 million after tax) in charges associated with the make-whole premiums from the early redemptions and write-off of unamortized discount and debt issuance costs. As a result of our expected early redemption, this debt was classified as Current Portion of Long-Term Debt and Finance Leases on Sempra’s Condensed Consolidated Balance Sheet at September 30, 2021.

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 have derivatives that are (1) cash flow hedges, (2) fair value hedges, or (3) undesignated. Depending on the applicability of hedge accounting and, for the California Utilities 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

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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 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:

▪The California Utilities use natural gas and 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 Mexico and Sempra LNG 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 the California Utilities, may use other energy derivatives to hedge exposures such as the price of vehicle fuel and greenhouse gas allowances.

The following table summarizes net energy derivative volumes.

NET ENERGY DERIVATIVE VOLUMES
(Quantities in millions)
Commodity	Unit of measure	September 30, 2021	December 31, 2020
Sempra:
Natural gas	MMBtu	(14)	5
Electricity	MWh	1	1
Congestion revenue rights	MWh	48	43
SDG&E:
Natural gas	MMBtu	10	16
Electricity	MWh	1	1
Congestion revenue rights	MWh	48	43
SoCalGas:
Natural gas	MMBtu	—	1

In addition to the amounts noted above, we use commodity derivatives to manage risks associated with the physical locations of contractual obligations and assets, such as natural gas purchases and sales.

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INTEREST RATE DERIVATIVES

We are exposed to interest rates primarily as a result of our current and expected use of financing. The California Utilities, 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 JVs.

INTEREST RATE DERIVATIVES
(Dollars in millions)
	September 30, 2021			December 31, 2020
	Notional debt		Maturities	Notional debt		Maturities
Sempra:
Cash flow hedges	$	747	2021-2034	$	1,486	2021-2034

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 variable interest rates for U.S. fixed interest rates. From time to time, Sempra Mexico 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.

We also utilized foreign currency derivatives in 2020 to hedge exposure to fluctuations in the Peruvian sol and Chilean peso related to the sales of our operations in Peru and Chile, respectively.

The following table presents the net notional amounts of our foreign currency derivatives, excluding JVs.

FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	September 30, 2021			December 31, 2020
	Notional amount		Maturities	Notional amount		Maturities
Sempra:
Cross-currency swaps	$	306	2021-2023	$	306	2021-2023
Other foreign currency derivatives	130		2021-2023	1,764		2021-2022

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)
	September 30, 2021
	Other current assets(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	$	—	$	6	$	(42)	$	(134)
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	252		19		(300)		(21)
Associated offsetting commodity contracts	(225)		(15)		225		15
Associated offsetting cash collateral	—		—		11		—
Commodity contracts subject to rate recovery	50		76		(52)		(3)
Associated offsetting commodity contracts	(4)		—		4		—
Net amounts presented on the balance sheet	73		86		(154)		(143)
Additional cash collateral for commodity contracts not subject to rate recovery	47		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	30		—		—		—
Total(2)	$	150	$	86	$	(154)	$	(143)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	47	$	76	$	(18)	$	(2)
Associated offsetting commodity contracts	(3)		—		3		—
Net amounts presented on the balance sheet	44		76		(15)		(2)
Additional cash collateral for commodity contracts subject to rate recovery	28		—		—		—
Total(2)	$	72	$	76	$	(15)	$	(2)
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	3	$	—	$	(34)	$	(1)
Associated offsetting commodity contracts	(1)		—		1		—
Net amounts presented on the balance sheet	2		—		(33)		(1)
Additional cash collateral for commodity contracts subject to rate recovery	2		—		—		—
Total	$	4	$	—	$	(33)	$	(1)

(1)    Included in Current Assets: Fixed-Price Contracts and Other Derivatives for SDG&E.

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

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DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	December 31, 2020
	Other current assets(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	$	—	$	1	$	(26)	$	(160)
Derivatives not designated as hedging instruments:
Foreign exchange instruments	24		—		—		—
Commodity contracts not subject to rate recovery	82		17		(95)		(16)
Associated offsetting commodity contracts	(82)		(13)		82		13
Commodity contracts subject to rate recovery	35		95		(35)		(25)
Associated offsetting commodity contracts	(2)		—		2		—
Net amounts presented on the balance sheet	57		100		(72)		(188)
Additional cash collateral for commodity contracts not subject to rate recovery	21		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	30		—		—		—
Total(2)	$	108	$	100	$	(72)	$	(188)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	32	$	95	$	(28)	$	(25)
Associated offsetting commodity contracts	(1)		—		1		—
Net amounts presented on the balance sheet	31		95		(27)		(25)
Additional cash collateral for commodity contracts subject to rate recovery	24		—		—		—
Total(2)	$	55	$	95	$	(27)	$	(25)
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	3	$	—	$	(7)	$	—
Associated offsetting commodity contracts	(1)		—		1		—
Net amounts presented on the balance sheet	2		—		(6)		—
Additional cash collateral for commodity contracts subject to rate recovery	6		—		—		—
Total	$	8	$	—	$	(6)	$	—

(1)    Included in Current Assets: Fixed-Price Contracts and Other Derivatives for SDG&E.

(2)    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 September 30,					Three months ended September 30,
	2021		2020		Location	2021		2020
Sempra:
Interest rate instruments	$	7	$	8	Interest Expense	$	1	$	(3)
Interest rate instruments	3		25		Equity Earnings(1)	(19)		(5)
Foreign exchange instruments	5		(2)		Revenues: Energy- Related Businesses	—		—
Foreign exchange instruments	3		(1)		Equity Earnings(1)	—		—
Interest rate and foreign exchange instruments	(3)		6		Other (Expense) Income, Net	(5)		4
Total	$	15	$	36		$	(23)	$	(4)
	Nine months ended September 30,					Nine months ended September 30,
	2021		2020		Location	2021		2020
Sempra:
Interest rate instruments	$	27	$	(42)	Interest Expense	$	—	$	(6)
Interest rate instruments	54		(175)		Equity Earnings(1)	(57)		(8)
Foreign exchange instruments	7		14		Revenues: Energy- Related Businesses	(1)		2
					Other (Expense) Income, Net	—		1
Foreign exchange instruments	5		9		Equity Earnings(1)	(1)		2
Interest rate and foreign exchange instruments	(2)		(31)		Interest Expense	—		(1)
					Other (Expense) Income, Net	(4)		(33)
Total	$	91	$	(225)		$	(63)	$	(43)

(1)    Equity earnings at Sempra Mexico are recognized after tax.

For Sempra, we expect that net losses of $104 million, which are 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. SoCalGas expects that $1 million of losses, net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. Actual amounts ultimately reclassified into earnings depend on the interest rates in effect when derivative contracts mature.

For all forecasted transactions, the maximum remaining term over which we are hedging exposure to the variability of cash flows at September 30, 2021 is approximately 13 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 18 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 September 30,				Nine months ended September 30,
	Location	2021		2020		2021		2020
Sempra:
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	$	(154)	$	(39)	$	(344)	$	25
Commodity contracts subject to rate recovery	Cost of Natural Gas	(26)		—		(24)		(6)
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	8		41		51		41
Foreign exchange instruments	Other (Expense) Income, Net	2		15		(22)		(97)
Total		$	(170)	$	17	$	(339)	$	(37)
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	8	$	41	$	51	$	41
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas	$	(26)	$	—	$	(24)	$	(6)

CONTINGENT FEATURES

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

For Sempra, the total fair value of this group of derivative instruments in a liability position at September 30, 2021 and December 31, 2020 was $63 million and $16 million, respectively. For SoCalGas, the total fair value of this group of derivative instruments in a liability position at September 30, 2021 and December 31, 2020 was $34 million and $6 million, respectively. At September 30, 2021, if the credit ratings of Sempra or SoCalGas were reduced below investment grade, $63 million and $34 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.

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RECURRING FAIR VALUE MEASURES

The three tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis at September 30, 2021 and December 31, 2020. 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, 2020.

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 cash balances, 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 marketable securities 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). These investments in marketable securities were negligible at both September 30, 2021 and December 31, 2020.

▪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 LNG.”

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RECURRING FAIR VALUE MEASURES – SEMPRA
(Dollars in millions)
	Fair value at September 30, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	350	$	6	$	—	$	356
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	40		12		—		52
Municipal bonds	—		320		—		320
Other securities	—		270		—		270
Total debt securities	40		602		—		642
Total nuclear decommissioning trusts(1)	390		608		—		998
Interest rate and foreign exchange instruments	—		6		—		6
Commodity contracts not subject to rate recovery	—		31		—		31
Effect of netting and allocation of collateral(2)	47		—		—		47
Commodity contracts subject to rate recovery	32		2		88		122
Effect of netting and allocation of collateral(2)	24		—		6		30
Support Agreement, net of related guarantee fees	—		—		7		7
Total	$	493	$	647	$	101	$	1,241
Liabilities:
Interest rate and foreign exchange instruments	$	—	$	176	$	—	$	176
Commodity contracts not subject to rate recovery	—		81		—		81
Effect of netting and allocation of collateral(2)	—		(11)		—		(11)
Commodity contracts subject to rate recovery	—		35		16		51
Support Agreement, net of related guarantee fees	—		—		2		2
Total	$	—	$	281	$	18	$	299
	Fair value at December 31, 2020
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	358	$	6	$	—	$	364
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	41		24		—		65
Municipal bonds	—		326		—		326
Other securities	—		270		—		270
Total debt securities	41		620		—		661
Total nuclear decommissioning trusts(1)	399		626		—		1,025
Interest rate and foreign exchange instruments	—		25		—		25
Commodity contracts not subject to rate recovery	—		4		—		4
Effect of netting and allocation of collateral(2)	21		—		—		21
Commodity contracts subject to rate recovery	6		1		121		128
Effect of netting and allocation of collateral(2)	19		5		6		30
Support Agreement, net of related guarantee fees	—		—		7		7
Total	$	445	$	661	$	134	$	1,240
Liabilities:
Interest rate and foreign exchange instruments	$	—	$	186	$	—	$	186
Commodity contracts not subject to rate recovery	—		16		—		16
Commodity contracts subject to rate recovery	—		6		52		58
Support Agreement, net of related guarantee fees	—		—		4		4
Total	$	—	$	208	$	56	$	264

(1)    Excludes cash, cash equivalents and 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 September 30, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	350	$	6	$	—	$	356
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	40		12		—		52
Municipal bonds	—		320		—		320
Other securities	—		270		—		270
Total debt securities	40		602		—		642
Total nuclear decommissioning trusts(1)	390		608		—		998
Commodity contracts subject to rate recovery	32		—		88		120
Effect of netting and allocation of collateral(2)	22		—		6		28
Total	$	444	$	608	$	94	$	1,146
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	1	$	16	$	17
Total	$	—	$	1	$	16	$	17
	Fair value at December 31, 2020
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	358	$	6	$	—	$	364
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	41		24		—		65
Municipal bonds	—		326		—		326
Other securities	—		270		—		270
Total debt securities	41		620		—		661
Total nuclear decommissioning trusts(1)	399		626		—		1,025
Commodity contracts subject to rate recovery	5		—		121		126
Effect of netting and allocation of collateral(2)	18		—		6		24
Total	$	422	$	626	$	127	$	1,175
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	—	$	52	$	52
Total	$	—	$	—	$	52	$	52

(1)    Excludes cash, cash equivalents and 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 September 30, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	—	$	2	$	—	$	2
Effect of netting and allocation of collateral(1)	2		—		—		2
Total	$	2	$	2	$	—	$	4
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	34	$	—	$	34
Total	$	—	$	34	$	—	$	34
	Fair value at December 31, 2020
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	1	$	1	$	—	$	2
Effect of netting and allocation of collateral(1)	1		5		—		6
Total	$	2	$	6	$	—	$	8
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	6	$	—	$	6
Total	$	—	$	6	$	—	$	6

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

Level 3 Information

SDG&E

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

LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)
	Three months ended September 30,
	2021		2020
Balance at July 1	$	80	$	17
Realized and unrealized losses	(35)		(4)
Allocated transmission instruments	1		1
Settlements	26		19
Balance at September 30	$	72	$	33
Change in unrealized gains (losses) relating to instruments still held at September 30	$	9	$	7
	Nine months ended September 30,
	2021		2020
Balance at January 1	$	69	$	28
Realized and unrealized losses	(29)		(18)
Allocated transmission instruments	(1)		2
Settlements	33		21
Balance at September 30	$	72	$	33
Change in unrealized gains (losses) relating to instruments still held at September 30	$	5	$	(1)

(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
2021	$	(1.81)	to	$	14.11	$	(0.12)
2020	(3.77)		to	6.03		(1.58)

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 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 September 30 were as follows:

LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS
Settlement year	Price per MWh					Weighted-average price per MWh
2021	$	24.05	to	$	130.40	$	57.36
2020		19.45	to		71.25		38.14

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 LNG

The table below sets forth a reconciliation 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 RECONCILIATION
(Dollars in millions)
	Three months ended September 30,
	2021		2020
Balance at July 1	$	4	$	—
Realized and unrealized gains(1)	3		7
Settlements	(2)		(1)
Balance at September 30(2)	$	5	$	6
Change in unrealized gains (losses) relating to instruments still held at September 30	$	3	$	6
	Nine months ended September 30,
	2021		2020
Balance at January 1	$	3	$	—
Realized and unrealized gains(1)	8		7
Settlements	(6)		(1)
Balance at September 30(2)	$	5	$	6
Change in unrealized gains (losses) relating to instruments still held at September 30	$	7	$	6

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

(2)    Includes $7 million in Other Current Assets offset by $2 million in Deferred Credits and Other at September 30, 2021 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, short-term amounts due to/from unconsolidated affiliates, 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)
	September 30, 2021
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
Sempra:
Long-term amounts due from unconsolidated affiliates(1)	$	687	$	—	$	697	$	—	$	697
Long-term amounts due to unconsolidated affiliates	328		—		347		—		347
Total long-term debt(2)	21,966		—		24,288		—		24,288
SDG&E:
Total long-term debt(3)	$	6,418	$	—	$	7,263	$	—	$	7,263
SoCalGas:
Total long-term debt(4)	$	4,759	$	—	$	5,373	$	—	$	5,373
	December 31, 2020
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
Sempra:
Long-term amounts due from unconsolidated affiliates(1)	$	786	$	—	$	817	$	—	$	817
Long-term amounts due to unconsolidated affiliates	275		—		266		—		266
Total long-term debt(2)	22,259		—		25,478		—		25,478
SDG&E:
Total long-term debt(3)	$	6,253	$	—	$	7,384	$	—	$	7,384
SoCalGas:
Total long-term debt(4)	$	4,759	$	—	$	5,655	$	—	$	5,655

(1)    Before allowances for credit losses of $1 million and $3 million at September 30, 2021 and December 31, 2020, respectively. Includes $2 million and $3 million in Due From Unconsolidated Affiliates – Current at September 30, 2021 and December 31, 2020, respectively.

(2)    Before reductions of unamortized discount and debt issuance costs of $266 million and $268 million at September 30, 2021 and December 31, 2020, respectively, and excluding finance lease obligations of $1,336 million and $1,330 million at September 30, 2021 and December 31, 2020, respectively.

(3)    Before reductions of unamortized discount and debt issuance costs of $62 million and $52 million at September 30, 2021 and December 31, 2020, respectively, and excluding finance lease obligations of $1,279 million and $1,276 million at September 30, 2021 and December 31, 2020, respectively.

(4)    Before reductions of unamortized discount and debt issuance costs of $37 million and $40 million at September 30, 2021 and December 31, 2020, respectively, and excluding finance lease obligations of $57 million and $54 million at September 30, 2021 and December 31, 2020, 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 September 2020, the foundation filed another writ petition under the California Coastal Act in LA Superior Court seeking to set aside the California Coastal Commission’s July 2020 approval of the inspection and maintenance plan for the SONGS’ canisters and to obtain injunctive relief to stop decommissioning work. A trial date for this petition has been set for April 2022. To date, decommissioning work has not been interrupted as a result of these writ petitions.

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. The amounts 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 2020, SDG&E received authorization from the CPUC to access NDT funds of up to $89 million for forecasted 2021 costs.

The following table shows the fair values and gross unrealized gains and losses for the securities held in the NDT. 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
At September 30, 2021:
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	52	$	—	$	—	$	52
Municipal bonds(2)	307		14		(1)		320
Other securities(3)	261		10		(1)		270
Total debt securities	620		24		(2)		642
Equity securities	103		255		(2)		356
Cash and cash equivalents	7		—		—		7
Payables, net	(2)		—		—		(2)
Total	$	728	$	279	$	(4)	$	1,003
At December 31, 2020:
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	$	64	$	1	$	—	$	65
Municipal bonds	308		18		—		326
Other securities	253		17		—		270
Total debt securities	625		36		—		661
Equity securities	112		254		(2)		364
Cash and cash equivalents	3		—		—		3
Payables, net	(9)		—		—		(9)
Total	$	731	$	290	$	(2)	$	1,019

(1)    Maturity dates are 2021-2051.

(2)    Maturity dates are 2022-2056.

(3)    Maturity dates are 2021-2072.

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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 NDT
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Proceeds from sales	$	187	$	294	$	729	$	1,091
Gross realized gains	9		9		48		108
Gross realized losses	(1)		(2)		(4)		(13)

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 AND SPENT NUCLEAR FUEL

The present value of SDG&E’s ARO related to decommissioning costs for the SONGS units was $551 million at September 30, 2021. That amount includes the cost to decommission Units 2 and 3, and the remaining cost to complete the decommissioning of Unit 1, which is substantially complete. The ARO for all three units is based on a cost study prepared in 2017 that is pending CPUC approval. The ARO for Units 2 and 3 reflects the acceleration of the start of decommissioning of these units as a result of the early closure of the plant. SDG&E’s share of total decommissioning costs in 2021 dollars is approximately $886 million.

NUCLEAR INSURANCE

SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. Currently, this insurance provides $450 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides an additional $110 million of coverage. If a nuclear liability loss occurs at SONGS and exceeds the $450 million insurance limit, this additional coverage would be available to provide a total of $560 million in coverage limits per incident.

The SONGS co-owners have nuclear property damage insurance of $130 million, which exceeds the minimum federal requirements 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 $4.3 million of retrospective premiums based on overall member claims.

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

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, cash flows, results of operations, financial condition and/or prospects. Unless otherwise indicated, we are unable to estimate reasonably possible losses or a range of losses in excess of any amounts accrued.

At September 30, 2021, loss contingency accruals for legal matters, including associated legal fees and regulatory matters related to the Leak, that are probable and estimable were $2,076 million for Sempra, including $1,998 million for SoCalGas. Amounts for Sempra and SoCalGas include $1,973 million for matters related to the Leak, which we discuss below.

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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 Estimates, Accounting Impact and Insurance.”

Civil Litigation – Litigation Subject to Agreements to Resolve. As of November 1, 2021, 416 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, wrongful death and violations of Proposition 65 against SoCalGas and Sempra (excluding the Proposition 65 claims, the Individual Plaintiff Litigation). 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.

On September 26, 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 by June 1, 2022, although SoCalGas and Sempra have the right to waive such condition. 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 agreement is further subject to LA Superior Court approval of the process to allocate payments among the plaintiffs and a stay of the Individual Plaintiff Litigation. The plaintiffs who do not agree to participate in the settlement will be able to continue to pursue their claims.

In January 2017, two consolidated class action complaints were filed against SoCalGas and Sempra, one on behalf of a putative class of persons and businesses who own or lease real property within a five-mile radius of the well (the Property Class Action), and a second on behalf of a putative class of all persons and entities conducting business within five miles of the facility (the Business 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. The Business Class Action asserts a claim for violation of the California Unfair Competition Law. Both complaints seek compensatory, statutory and punitive damages, injunctive relief and attorneys’ fees.

On September 26, 2021, SoCalGas and Sempra entered into an agreement to settle the Property Class Action for a total amount of $40 million. If, following a fairness hearing at which any objections to the settlement will be heard, the LA Superior Court gives final approval of the settlement, the agreement provides for a release of SoCalGas, Sempra and their respective affiliates from all claims related to the Leak by all property class members who do not opt out of the class. Members of the property class who opt out of the settlement will have the right to pursue their claims on an individual basis.

On September 27, 2021, SoCalGas and Sempra entered into an agreement to settle the individual claims of the named plaintiffs in the Business Class Action for a total amount of $100,000 in exchange for a dismissal and release of SoCalGas, Sempra and their respective affiliates from all claims related to the Leak.

The Third Amended Consolidated Master Case Complaint for Individual Actions includes claims for violation of Proposition 65 seeking penalties for alleged violation of requirements to warn about certain chemical exposures as a result of the Leak. On November 4, 2021, SoCalGas entered into an agreement to settle these claims for a payment of approximately $2 million; in

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addition, SoCalGas agreed to implement certain measures to reduce emissions at the Aliso Canyon natural gas storage facility and to provide warnings to residents if benzene measured at the facility’s fence line exceeds certain levels. The settlement of these claims requires the approval of the LA Superior Court.

An adverse ruling in any of the lawsuits in the Individual Plaintiff Litigation filed by plaintiffs who do not agree to settle, any lawsuits filed by property class members who opt out of the Property Class Action settlement or by members of the putative Business Class Action, or the Proposition 65 claims described above if that settlement is not approved by the court, could have a material adverse effect on SoCalGas’ and Sempra’s cash flows, financial condition and results of operations. In addition, there can be no assurance that the conditions to resolve the Individual Plaintiff Litigation will be satisfied or that the LA Superior Court will approve the settlement for the Property Class Action.

In addition, a federal securities class action alleging violation of the federal securities laws was filed against Sempra and certain of its officers in July 2017 in the U.S. District Court for the Southern District of California. In March 2018, the court dismissed the action with prejudice, and in February 2021, the U.S. Court of Appeals for the Ninth Circuit affirmed the dismissal. The time for appeal has passed and, as a result, this represents the final judgment in this proceeding.

Civil Litigation – Unresolved Litigation. Five property developers filed complaints in July and October of 2018 against SoCalGas and Sempra alleging causes of action for strict liability, negligence per se, negligence, continuing nuisance, permanent nuisance and violation of the California Unfair Competition Law, as well as claims for negligence against certain directors of SoCalGas. The complaints seek compensatory, statutory and punitive damages, injunctive relief and attorneys’ fees. The LA Superior Court has scheduled a trial for one or more of the developers in February 2022.

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 filed a notice of appeal. The remaining action was also dismissed but plaintiffs were given leave to amend their complaint.

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 Safety Enforcement Division (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. 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 sufficiently cooperate 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

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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 2020, the CPUC issued a decision on the interim range of gas inventory levels at the Aliso Canyon natural gas storage facility, setting the interim range between 0 Bcf and 34 Bcf. In November 2021, the CPUC issued a decision approving a new 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 September 30, 2021, the Aliso Canyon natural gas storage facility had a net book value of $863 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 and cash flows.

Cost Estimate, Accounting Impact and Insurance. SoCalGas has incurred significant costs 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 September 30, 2021, SoCalGas estimates these costs related to the Leak are $3,199 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. A portion of the cost estimate has been paid, and $1,976 million is accrued as Reserve for Aliso Canyon Costs at September 30, 2021 on SoCalGas’ and Sempra’s Condensed Consolidated Balance Sheets.

In the first quarter of 2020, SoCalGas recorded $277 million in costs, inclusive of estimated legal costs, related to settlement discussions in connection with civil litigation described above. Of this amount, $177 million was recorded in Insurance Receivable for Aliso Canyon Costs on the SoCalGas and Sempra Condensed Consolidated Balance Sheets and $100 million ($72 million after tax) was recorded in Aliso Canyon Litigation and Regulatory Matters on the SoCalGas and Sempra Condensed Consolidated Statements of Operations. In the third quarter of 2020, SoCalGas recorded an additional charge of $27 million ($22 million after tax) related to the OII described above in “Regulatory Proceedings.”

As a result of entering into the September 26 and 27, 2021 agreements described above, SoCalGas recorded an additional charge of $1.57 billion ($1.13 billion after tax) in the third quarter of 2021 in Aliso Canyon Litigation and Regulatory Matters on the SoCalGas and Sempra Condensed Consolidated Statements of Operations. Sempra has elected to make equity contributions to SoCalGas that are sufficient to maintain SoCalGas’ approved capital structure in connection with the accruals related to these agreements. In connection with this election, in September 2021, Sempra made an initial equity contribution of $800 million to SoCalGas.

Except for the amounts paid or estimated to settle certain legal and regulatory matters as described above, the cost estimate does not include 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. These costs or losses not included in the cost estimate could be significant and could have a material adverse effect on SoCalGas’ and Sempra’s cash flows, financial condition and results of operations.

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 September 30, 2021, we recorded the expected recovery of the cost estimate related to the Leak of $414 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 $865 million of insurance proceeds we received through September 30, 2021. 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

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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, which could be significant, could have a material adverse effect on SoCalGas’ and Sempra’s cash flows, financial condition and results of operations.

Sempra Mexico

Energía Costa Azul

We describe below certain land and customer disputes and permit challenges affecting our ECA Regas Facility and our proposed ECA LNG liquefaction projects. 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, cash flows, financial condition, results of operations and/or prospects.

Land Disputes. IEnova 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 IEnova 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.

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. We expect the plaintiff may appeal.

▪The second disputed area is one 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, the ECA Regas Facility bought the property a second time in 2008 from the plaintiff. 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. IEnova appealed the ruling in July 2021, which is pending resolution. 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 decision was affirmed on 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.

Certain of these land disputes involve land on which portions of the ECA LNG liquefaction facilities, including ECA LNG Phase 1 currently under construction, 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.

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:

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▪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; therefore, the natural gas liquefaction activities have not been affected.

▪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 case is awaiting proceedings.

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 IEnova and a force majeure event. Citing these circumstances, the customers subsequently stopped making payments of amounts due under their respective LNG storage and regasification agreements. IEnova has rejected the customers’ assertions and has drawn on the customers’ letters of credit provided as payment security. The parties engaged in discussions under the applicable contractual dispute resolution procedures without coming to a mutually acceptable resolution. In July 2020, Shell Mexico submitted a request for arbitration of the dispute and although Gazprom has joined the proceeding, Gazprom has since replenished the amounts drawn on its letter of credit and has resumed making regular monthly payments under its LNG storage and regasification agreement. As a consequence, IEnova is not currently drawing on Gazprom’s letter of credit but expects to continue to draw on Shell Mexico’s letter of credit. IEnova intends to avail itself of its available claims, defenses, rights and remedies in the arbitration proceeding, including seeking dismissal of the customers’ claims. In addition to the arbitration proceeding, Shell Mexico also filed a constitutional challenge to the CRE’s approval of the update to the general terms and conditions and an additional constitutional claim against the issuance of the liquefaction permit. Shell Mexico’s request to stay the CRE’s approval of the general terms and conditions was denied in October 2020 and upheld on appeal. A decision on the merits is pending. The claim regarding the liquefaction permit issuance was denied in March 2021 and upheld on appeal. A hearing on the merits of the arbitration case was held in October 2021.

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, cash flows, financial condition, results of operations and/or prospects.

Sonora Pipeline

Guaymas-El Oro Segment. IEnova’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, IEnova 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, IEnova 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, IEnova 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 IEnova from making repairs to put the pipeline back in service. In July 2019, a federal district court ruled in favor of IEnova 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 IEnova 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.

IEnova 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 IEnova and the CFE reached an agreement to restart natural gas

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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, IEnova and the CFE agreed to extend the service start date multiple times, most recently to March 14, 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 March 14, 2022, and the parties do not agree on a new service start date, IEnova retains the right to terminate the contract and seek to recover its reasonable and documented costs and lost profits.

At September 30, 2021, Sempra Mexico had $436 million in PP&E, net, related to the Guaymas-El Oro segment of the Sonora pipeline, which could be subject to impairment if IEnova is unable to make such repairs (which have not commenced) or re-route the pipeline (which has not been agreed to by the parties) and resume operations in the Guaymas-El Oro segment of the Sonora pipeline or if IEnova 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, IEnova 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. IEnova intends to file a special judicial action whereby it will ask a civil court to acknowledge the existence of the easement and to determine the consideration the landowner should receive in exchange for the easement. The failure to stay this judgment pending the resolution of IEnova’s planned special judicial action or prevail in preserving the easement in the special judicial action could require us to modify the route of the pipeline and could require a temporary shutdown of this portion of the pipeline, which 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

We describe below certain actions by the Mexican government that could have a material impact on the energy sector in Mexico. IEnova 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. If passed in its current form, the proposed constitutional reform described below introduces significant changes to the legal and economic principles underlying the country’s energy reform of 2013, generating imminent risks for private investments in this sector. An unfavorable decision on one or more of these amparo or other challenges, the potential for extended disputes, or if passed in its current form, the proposed constitutional reform may impact our ability to operate our facilities at existing levels or at all, may result in increased costs for IEnova and its customers, may adversely affect our ability to develop new projects, 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, financial condition, results of operations, 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 IEnova’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 have obtained injunctive relief but are required to guarantee the difference in tariffs, which could be material, until the claims are definitively resolved by the courts. The three facilities obtained favorable resolutions from a lower court and the CRE has appealed one of these decisions.

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. If IEnova is not able to obtain legal protection for these impacted facilities, IEnova 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 significantly lower than the fixed prices in the PPAs that were entered into through self-supply permits. At September 30, 2021, Sempra Mexico had $14 million in other intangible assets, net, related to these self-supply permits previously granted by the CRE and impacted by the

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Offtaker Resolution that could be subject to impairment if IEnova is unable to obtain adequate legal protection. IEnova 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, and it is expected that Mexico’s Supreme Court will ultimately settle the matter. If the proposed amendments are affirmed by the Supreme Court, 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 of IEnova’s facilities participating in the hydrocarbons sector filed lawsuits against the initiative to reform the Hydrocarbons Law and received injunctive relief pending a final resolution by the courts. In May 2021, a Mexican district court ordered the suspension of several of the provisions of the amendments with general application across the sector. 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 filed by several companies in the market, including three of the five lawsuits filed by IEnova. These judgments have been appealed and the granted suspensions will remain valid until the lawsuits are definitively resolved.

Amendments to Mexico’s General Foreign Trade Rules. In June 2021, amendments to Mexico’s General Foreign Trade Rules went into effect, which establish that only state-owned companies may import and export hydrocarbons, refined products, petrochemicals, and biofuels through channels other than those authorized (LDA authorization). These amendments prevent non-state-owned companies from (i) obtaining LDA authorizations, which affect new projects that have not obtained such approval, and (ii) renewing existing LDA authorizations, which affect operational projects and those under construction. The ECA Regas Facility and the Veracruz terminal have LDA authorizations that are valid through 2023 and, as a preventive measure, have filed amparo claims to challenge the newly introduced barrier to renew their existing LDA authorizations. In order to start operations at terminals currently under construction or in development in the vicinity of Topolobampo, Manzanillo and Ensenada, including the proposed ECA LNG liquefaction projects, IEnova filed amparo claims to challenge such amendments that prevent them from obtaining LDA authorizations in the future.

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 to the CFE, including permits at all of IEnova’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.

The initiative must first be submitted to a vote and approved in the respective plenary sessions of the Chamber of Deputies and the Chamber of Senators in Mexico. Additionally, the initiative must be approved by a two-thirds vote of Mexico’s Federal Congress and by the majority of the legislatures of the Mexican States and published in the Federal Official Gazette to be in force. Sempra Mexico is following this legislative procedure while assessing alternatives for its project companies. If passed in its current form, the initiative could have a material adverse effect on our business, financial condition, results of operations, cash flows and/or prospects, our ability to recover the carrying values of our investments in Mexico, and our ability to operate existing facilities and develop new energy projects in the country.

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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. RBS, now NatWest Markets plc, our partner in the JV, paid an assessment of £86 million (approximately $138 million in U.S. dollars) in October 2014 to HMRC for denied VAT refund claims filed in connection with the purchase of carbon credit allowances by RBS SEE, a subsidiary of RBS Sempra Commodities. RBS SEE was subsequently sold to J.P. Morgan Chase & Co. and later to Mercuria Energy Group, Ltd. HMRC asserted that RBS was not entitled to reduce its VAT liability by VAT paid on certain carbon credit purchases during 2009 because RBS knew or should have known that certain vendors in the trading chain did not remit their own VAT to HMRC. In July 2021, RBS entered into a settlement with HMRC that resolved this matter.

In 2015, liquidators filed a claim in the High Court of Justice against RBS 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. 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 for 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 $61 million in U.S. dollars at September 30, 2021), plus costs and interest. In October 2020, the High Court of Justice assessed costs and interest to be approximately £21 million (approximately $28 million in U.S. dollars at September 30, 2021) 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. The Liquidating Companies in the High Court of Justice case have applied to the Supreme Court for permission to appeal the Court of Appeals’ decision. J.P. Morgan Chase & Co. has 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.

We recorded $100 million in equity losses from our investment in RBS Sempra Commodities in Equity Earnings on Sempra’s Condensed Consolidated Statement of Operations in the first quarter of 2020, which represented an estimate of our obligations to settle pending VAT matters and related legal costs. In the second quarter of 2021, we reduced this estimate by $50 million based on the settlement with HMRC on the First-Tier Tribunal case and revised assumptions on the High Court of Justice case. The final outcome of the High Court of Justice case remains uncertain.

Asbestos Claims Against EFH Subsidiaries

Certain EFH subsidiaries that we acquired as part of the merger of EFH with an indirect subsidiary of Sempra are defendants in personal injury lawsuits brought in state courts throughout the U.S. As of November 1, 2021, three such lawsuits are pending, all of which have been served. These cases allege 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 seek compensatory and punitive damages. 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 cash flows, financial condition and results of operations.

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.

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A lease exists when a contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration. We determine if an arrangement is or contains a lease at inception of the contract.

Some of our lease agreements contain nonlease components, which represent activities that transfer a separate good or service to the lessee. As the lessee for both operating and finance leases, we have elected to combine lease and nonlease components as a single lease component for real estate, fleet vehicles, power generating facilities, and pipelines, whereby fixed or in-substance fixed payments allocable to the nonlease component are accounted for as part of the related lease liability and ROU asset. As the lessor, we have elected to combine lease and nonlease components as a single lease component for real estate, power generating facilities and terminals if the timing and pattern of transfer of the lease and nonlease components are the same and the lease component would be classified as an operating lease if accounted for separately.

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 and peaker plant facilities.

Leases that Have Not Yet Commenced

SDG&E has entered into a battery storage tolling agreement that it expects will commence in the fourth quarter of 2021. SDG&E expects to account for the tolling agreement as an operating lease upon commencement and expects the future minimum lease payments to be $1 million in 2021, $10 million in each of 2022 through 2025 and $103 million thereafter until expiration in 2036.

Lessor Accounting

Sempra Mexico is a lessor for certain of its natural gas and ethane pipelines, compressor stations, LPG storage facilities, a rail facility and two liquid fuels terminals.

Generally, we recognize operating lease income on a straight-line basis over the lease term and evaluate the underlying asset for impairment. Certain of our leases contain rate adjustments or are based on foreign currency exchange rates that may result in lease payments received that vary in amount from one period to the next.

In July 2021, a rail facility agreement commenced, which Sempra Mexico is accounting for as a sales-type lease. The rail facility is being used by the lessee to transport liquid fuels out of the Veracruz terminal. The lessee has the right to direct the use of the rail facility and will obtain substantially all of the economic benefits of the rail facility. At lease commencement, Sempra Mexico derecognized the $44 million carrying value of the rail facility from PP&E and recognized a net investment in sales-type lease asset of $60 million and a selling profit of $16 million. The agreement expires in 2041 and will automatically renew for successive five-year terms unless written notice is provided by Sempra Mexico or the lessee. Fixed lease payments are payable in the first five years of the agreement, which the lessee is required to pay even in the event of lease termination.

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

LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Sales-type leases:
Income recognized at lease commencement	$	16	$	—	$	16	$	1
Interest income	2		—		2		1
Total revenues from sales-type leases(1)	$	18	$	—	$	18	$	2
Operating leases:
Fixed lease payments	$	80	$	48	$	192	$	145
Variable lease payments	2		1		3		1
Total revenues from operating leases(1)	$	82	$	49	$	195	$	146
Depreciation expense	$	13	$	10	$	35	$	29

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

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CONTRACTUAL COMMITMENTS

We discuss below significant changes in the first nine months of 2021 to contractual commitments discussed in Notes 1 and 16 of the Notes to Consolidated Financial Statements in the Annual Report.

LNG Purchase Agreement

Sempra LNG has a sale and purchase agreement 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 2021 to 2029. Although this agreement specifies a number of cargoes to be delivered, under its terms, the customer may divert certain cargoes, which would reduce amounts paid under the agreement by Sempra LNG. At September 30, 2021, we expect the commitment amount to decrease by $277 million in 2021 and then increase by $496 million in 2022, $279 million in 2023, $197 million in 2024, $153 million in 2025 and by $499 million thereafter (through contract termination in 2029) compared to December 31, 2020, reflecting changes in estimated forward prices since December 31, 2020 and actual transactions for the first nine months of 2021. 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.

OTHER COMMITMENTS

Franchise Agreements

In December 2020, the City of San Diego and SDG&E agreed to extend SDG&E’s natural gas and electric franchises for the city to June 1, 2021. After completing a competitive bid process, on June 8, 2021, the City of San Diego approved ordinances granting to SDG&E the natural gas and electric franchises for the city. These franchise agreements provide SDG&E the opportunity to serve the City of San Diego for the next 20 years, consisting of 10-year agreements that will automatically renew for an additional 10 years unless the City Council voids the automatic renewal with a supermajority vote. The agreements went into effect in July 2021. Over the 20-year term of the agreements, SDG&E will make principal payments of $110 million and interest payments of $13 million as consideration for the natural gas and electric franchise agreements. The consideration paid will not be recovered from customers and will be amortized over 20 years. SDG&E paid $11 million to the City of San Diego in the first nine months of 2021. At September 30, 2021, SDG&E has commitments to make future payments of $14 million per year in 2022 through 2024, $15 million in 2025 and $55 million thereafter.

Two lawsuits have been filed in the California Superior Court challenging the City’s process for its award of the natural gas and electric franchises and seeking to declare the franchise agreements null and void.

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 $46 million for Sempra, $17 million for SDG&E and $15 million for SoCalGas at September 30, 2021.

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NOTE 12. SEGMENT INFORMATION

We have five 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 Mexico develops, owns and operates, or holds interests in, natural gas, electric, LNG, LPG, ethane and liquid fuels infrastructure, and has marketing operations for the purchase of LNG and the purchase and sale of natural gas in Mexico.

▪Sempra LNG develops, builds, operates and invests in natural gas liquefaction export facilities, including natural gas pipelines and infrastructure, and buys, sells and transports natural gas through its marketing operations, all within North America.

As we discuss in Note 5, the financial information related to our businesses that constituted the Sempra South American Utilities segment is presented as discontinued operations for all periods presented. The information in the tables below excludes amounts from discontinued operations unless otherwise noted. We completed the sales of our discontinued operations in the second quarter of 2020.

We evaluate each segment’s performance based on its contribution to Sempra’s reported earnings and cash flows. The California Utilities operate in essentially separate service territories, under separate regulatory frameworks and rate structures set by the CPUC and, for SDG&E, the FERC. We describe the accounting policies of all of our segments in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

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 and include certain nominal amounts from our South American businesses that did not qualify for treatment as discontinued operations.

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SEGMENT INFORMATION
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
REVENUES
SDG&E	$	1,464	$	1,472	$	4,119	$	3,976
SoCalGas	1,106		842		3,738		3,247
Sempra Mexico	597		351		1,368		935
Sempra LNG	119		63		367		255
All other	2		—		4		1
Adjustments and eliminations	—		2		(1)		—
Intersegment revenues(1)	(275)		(86)		(582)		(215)
Total	$	3,013	$	2,644	$	9,013	$	8,199
INTEREST EXPENSE
SDG&E	$	104	$	103	$	307	$	307
SoCalGas	39		39		118		119
Sempra Mexico	43		31		122		95
Sempra LNG	4		8		10		39
All other	77		93		240		304
Intercompany eliminations	(8)		(10)		(21)		(46)
Total	$	259	$	264	$	776	$	818
INTEREST INCOME
SDG&E	$	—	$	1	$	1	$	2
SoCalGas	—		—		—		2
Sempra Mexico	12		14		36		47
Sempra LNG	6		25		23		65
All other	1		—		2		3
Intercompany eliminations	(3)		(13)		(12)		(43)
Total	$	16	$	27	$	50	$	76
DEPRECIATION AND AMORTIZATION
SDG&E	$	226	$	200	$	659	$	598
SoCalGas	180		165		533		486
Sempra Mexico	60		47		168		141
Sempra LNG	3		2		8		7
All other	2		4		8		10
Total	$	471	$	418	$	1,376	$	1,242
INCOME TAX EXPENSE (BENEFIT)
SDG&E	$	90	$	33	$	168	$	161
SoCalGas	(437)		(6)		(335)		95
Sempra Mexico	24		92		145		(161)
Sempra LNG	(11)		18		19		59
All other	(8)		(38)		(42)		(94)
Total	$	(342)	$	99	$	(45)	$	60
EQUITY EARNINGS (LOSSES)
Equity earnings (losses), before income tax:
Sempra Texas Utilities	$	—	$	1	$	3	$	1
Sempra LNG	137		116		404		257
All other	—		—		50		(100)
	137		117		457		158
Equity earnings, net of income tax:
Sempra Texas Utilities	207		208		480		457
Sempra Mexico	47		1		85		207
	254		209		565		664
Total	$	391	$	326	$	1,022	$	822

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SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E	$	205	$	178	$	603	$	633
SoCalGas	(1,126)		(24)		(625)		425
Sempra Texas Utilities	206		209		479		458
Sempra Mexico	164		50		225		302
Sempra LNG	1		71		194		207
Discontinued operations	—		(7)		—		1,840
All other	(98)		(126)		(226)		(515)
Total	$	(648)	$	351	$	650	$	3,350
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E					$	1,560	$	1,323
SoCalGas					1,417		1,345
Sempra Mexico					260		443
Sempra LNG					362		196
All other					7		6
Total					$	3,606	$	3,313
					September 30, 2021		December 31, 2020
ASSETS
SDG&E					$	23,783	$	22,311
SoCalGas					19,919		18,460
Sempra Texas Utilities					12,580		12,542
Sempra Mexico					11,339		10,752
Sempra LNG					3,335		2,205
All other					1,094		1,209
Intersegment receivables					(1,578)		(856)
Total					$	70,472	$	66,623
EQUITY METHOD AND OTHER INVESTMENTS
Sempra Texas Utilities					$	12,580	$	12,542
Sempra Mexico					924		852
Sempra LNG					454		433
All other					—		1
Total					$	13,958	$	13,828

(1)    Revenues for reportable segments include intersegment revenues of $3 million, $24 million, $52 million and $196 million for the three months ended September 30, 2021; $7 million, $72 million, $114 million and $389 million for the nine months ended September 30, 2021; $1 million, $23 million, $18 million and $44 million for the three months ended September 30, 2020 and $4 million, $61 million, $69 million and $81 million for the nine months ended September 30, 2020 for SDG&E, SoCalGas, Sempra Mexico and Sempra LNG, respectively.

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

You should read the following discussion 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.

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OVERVIEW

Sempra Energy is a California-based holding company with energy infrastructure investments in North America. On July 2, 2021, Sempra Energy began doing business as Sempra. Our businesses invest in, develop and operate energy infrastructure, and provide electric and gas services to customers through regulated public utilities. As 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, our business activities are organized under five separately managed reportable segments.

Our former South American businesses and certain activities associated with those businesses are presented as discontinued operations. Nominal activities that are not classified as discontinued operations have been subsumed into Parent and other. We completed the sales of these businesses in the second quarter of 2020. Our discussions below exclude discontinued operations, unless otherwise noted.

This report includes information for the following separate registrants:

▪Sempra;

▪SDG&E; and

▪SoCalGas.

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 refer to SDG&E and SoCalGas collectively as the California Utilities, which do not include the utilities in our Sempra Texas Utilities or Sempra Mexico segments or the utilities in our former South American businesses included in discontinued operations. 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.

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 our results of operations.

OVERALL RESULTS OF OPERATIONS OF SEMPRA

In the three months ended September 30, 2021, we reported losses of $(648) million and diluted EPS of $(2.03) compared to earnings of $351 million and diluted EPS of $1.21 for the same period in 2020. In the nine months ended September 30, 2021, we reported earnings of $650 million and diluted EPS of $2.09 compared to earnings of $3,350 million and diluted EPS of $11.43 for the same period in 2020. The change in diluted EPS in the three months ended September 30, 2021 compared to the same period in 2020 included a reduction in losses per share by $0.20 due to an increase in weighted-average common shares outstanding. The change in diluted EPS in the nine months ended September 30, 2021 compared to the same period in 2020 included a reduction in earnings per share by $0.13 due to an increase in weighted-average common shares outstanding. Our (losses) earnings and diluted EPS were impacted by variances discussed in “Segment Results” below.

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SEGMENT RESULTS

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

SEMPRA (LOSSES) EARNINGS BY SEGMENT
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
SDG&E	$	205	$	178	$	603	$	633
SoCalGas	(1,126)		(24)		(625)		425
Sempra Texas Utilities	206		209		479		458
Sempra Mexico	164		50		225		302
Sempra LNG	1		71		194		207
Parent and other(1)	(98)		(126)		(226)		(515)
Discontinued operations	—		(7)		—		1,840
(Losses) earnings attributable to common shares	$	(648)	$	351	$	650	$	3,350

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

SDG&E

The increase in earnings of $27 million (15%) in the three months ended September 30, 2021 compared to the same period in 2020 was primarily due to:

▪$29 million charge in 2020 for amounts expected to be refunded to customers and a fine related to the Energy Efficiency Program inquiry; and

▪$27 million higher CPUC base operating margin, net of operating expenses; offset by

▪$18 million higher income tax expense primarily from flow-through items, net of associated regulatory revenues; and

▪$3 million lower AFUDC equity.

The decrease in earnings of $30 million (5%) in the nine months ended September 30, 2021 compared to the same period in 2020 was primarily due to:

▪$62 million decrease due to the release of a regulatory liability in 2020 related to 2016-2018 forecasting differences that are not subject to tracking in the income tax expense memorandum account;

▪$20 million lower electric transmission margin, including the following favorable impacts in 2020 from the March 2020 FERC-approved TO5 settlement proceeding:

◦$18 million to conclude a rate base matter, and

◦$9 million impact from the retroactive application of the final TO5 settlement for 2019; and

▪$8 million higher income tax expense primarily from flow-through items, net of associated regulatory revenues; offset by

▪$44 million charge in 2020 for amounts expected to be refunded to customers and a fine related to the Energy Efficiency Program inquiry; and

▪$14 million higher CPUC base operating margin, net of operating expenses and favorable resolution of regulatory matters in 2020.

SoCalGas

The increase in losses of $1,102 million in the three months ended September 30, 2021 compared to the same period in 2020 was primarily due to:

▪$1,110 million increase in charges from impacts associated with the Aliso Canyon natural gas storage facility litigation and regulatory matters comprised of $1,132 million in 2021 compared to $22 million in 2020; offset by

▪$8 million higher CPUC base operating margin, net of operating expenses, AFUDC equity and other items.

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Losses of $625 million in the nine months ended September 30, 2021 compared to earnings of $425 million for the same period in 2020 was primarily due to:

▪$1,038 million increase in charges from impacts associated with the Aliso Canyon natural gas storage facility litigation and regulatory matters comprised of $1,132 million in 2021 compared to $94 million in 2020; and

▪$64 million decrease due to the release of a regulatory liability in 2020 related to 2016-2018 forecasting differences that are not subject to tracking in the income tax expense memorandum account; offset by

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

▪$12 million higher income tax benefits from forecasted flow-through items.

Sempra Texas Utilities

The decrease in earnings of $3 million (1%) in the three months ended September 30, 2021 compared to the same period in 2020 was primarily due to lower equity earnings from Oncor Holdings driven by:

▪increased operating costs and expenses attributable to invested capital; and

▪lower revenues due to an annual energy efficiency program performance bonus recognized in 2020, but pending PUCT approval in 2021; offset by

▪increased revenues from rate updates to reflect increases in invested capital and customer growth.

The increase in earnings of $21 million (5%) in the nine months ended September 30, 2021 compared to the same period in 2020 was primarily due to higher equity earnings from Oncor Holdings driven by:

▪increased revenues from rate updates to reflect increases in invested capital and customer growth; offset by

▪increased operating costs and expenses attributable to invested capital; and

▪lower revenues due to an annual energy efficiency program performance bonus recognized in 2020, but pending PUCT approval in 2021.

Sempra Mexico

Because Ecogas, our natural gas distribution utility in Mexico, uses the local currency as its functional currency, its revenues and expenses are translated into U.S. dollars at average exchange rates for the period for consolidation in Sempra’s results of operations. Prior year amounts used in the variances discussed below are as adjusted for the difference in foreign currency translation rates between years. We discuss these and other foreign currency effects below in “Impact of Foreign Currency and Inflation Rates on Results of Operations.”

The increase in earnings of $114 million in the three months ended September 30, 2021 compared to the same period in 2020 was primarily due to:

▪$62 million favorable impact from foreign currency and inflation effects net of foreign currency derivative effects comprised of a $29 million favorable impact in 2021 compared to a $33 million unfavorable impact in 2020;

▪$6 million earnings attributable to NCI at IEnova in 2021 compared to $22 million earnings in 2020, including the effects of the increase in our ownership of IEnova;

▪$14 million primarily due to the start of commercial operations of the Veracruz terminal in first quarter of 2021; and

▪$11 million selling profit on a sales-type lease relating to the commencement of a rail facility lease at the Veracruz terminal in the third quarter of 2021, which we discuss in Note 11 of the Notes to Condensed Consolidated Financial Statements; offset by

▪$6 million higher net interest expense.

The decrease in earnings of $77 million (25%) in the nine months ended September 30, 2021 compared to the same period in 2020 was primarily due to:

▪$227 million unfavorable impact from foreign currency and inflation effects net of foreign currency derivative effects comprised of a $42 million unfavorable impact in 2021 compared to a $185 million favorable impact in 2020;

▪$29 million income tax expense in 2021 primarily from outside basis differences in JV investments and the remeasurement of certain deferred income taxes; and

▪$15 million higher net interest expense; offset by

▪$50 million earnings attributable to NCI at IEnova in 2021 compared to $193 million earnings in 2020, including the effects of the increase in our ownership of IEnova;

▪$16 million primarily due to the start of commercial operations of the Veracruz terminal in the first quarter of 2021; and

▪$11 million selling profit on a sales-type lease relating to the commencement of a rail facility lease at the Veracruz terminal in the third quarter of 2021.

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Sempra LNG

The decrease in earnings of $70 million in the three months ended September 30, 2021 compared to the same period in 2020 was primarily due to:

▪$65 million lower earnings from marketing operations, primarily driven by changes in natural gas prices; and

▪$11 million lower net interest income from lower intercompany balances with Parent and other; offset by

▪$15 million higher equity earnings from Cameron LNG JV primarily due to the three-train liquefaction project achieving full commercial operations in August 2020.

The decrease in earnings of $13 million (6%) in the nine months ended September 30, 2021 compared to the same period in 2020 was primarily due to:

▪$122 million lower earnings from marketing operations due to losses in 2021 compared to gains in 2020, primarily driven by changes in natural gas prices;

▪$8 million lower net interest income from lower intercompany balances with Parent and other; and

▪$8 million of certain non‐capitalizable expenses at ECA LNG Phase 1 in 2021, which reached a final investment decision in November 2020; offset by

▪$115 million higher equity earnings from Cameron LNG JV primarily due to the three-train liquefaction project achieving full commercial operations in August 2020; and

▪$22 million income tax benefit in 2021 from the remeasurement of certain deferred income taxes.

Parent and Other

The decrease in losses of $28 million (22%) in the three months ended September 30, 2021 compared to the same period in 2020 was primarily due to:

▪$37 million lower preferred dividends primarily as a result of $36 million lower dividends due to the mandatory conversion of all series A preferred stock and series B preferred stock in January 2021 and July 2021, respectively; and

▪$15 million lower net interest expense; offset by

▪$18 million income tax expense in 2021 compared to a $2 million income tax benefit in 2020 primarily due to a valuation allowance against certain tax credit carryforwards; and

▪$10 million lower net investment gains on dedicated assets in support of our employee nonqualified benefit plan and deferred compensation obligations.

The decrease in losses of $289 million in the nine months ended September 30, 2021 compared to the same period in 2020 was primarily due to:

▪$50 million equity earnings in 2021 compared to $100 million equity losses in 2020 related to our investment in RBS Sempra Commodities to settle pending VAT matters and related legal costs, which we discuss in Note 11 of the Notes to Condensed Consolidated Financial Statements;

▪$69 million lower preferred dividends as a result of $88 million lower dividends due to the mandatory conversion of all series A preferred stock and series B preferred stock in January 2021 and July 2021, respectively, offset by $19 million higher dividends due to the issuance of series C preferred stock in June 2020;

▪$48 million lower net interest expense;

▪$22 million lower operating costs retained at Parent and other; and

▪$9 million higher net investment gains on dedicated assets in support of our employee nonqualified benefit plan and deferred compensation obligations; offset by

▪$25 million higher income tax expense primarily due to:

◦$8 million higher income tax expense due to a valuation allowance against certain tax credit carryforwards,

◦$6 million higher consolidated California state income tax expense associated with income from our investments in Sempra LNG entities, and

◦$5 million lower income tax benefit related to share-based compensation.

Discontinued Operations

Discontinued operations that were previously in our Sempra South American Utilities segment include our former 100% interest in Chilquinta Energía in Chile, our former 83.6% interest in Luz del Sur in Peru and our former interests in two energy-services companies, Tecnored and Tecsur, which provide electric construction and infrastructure services to Chilquinta Energía and Luz del Sur, respectively, as well as third parties. Discontinued operations also include activities, mainly income taxes related to the

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South American businesses, that were previously included in the holding company of the South American businesses at Parent and other.

As we discuss in Note 5 of the Notes to Condensed Consolidated Financial Statements, we completed the sales of our South American businesses in the second quarter of 2020. On April 24, 2020, we sold our equity interests in our Peruvian businesses, including our 83.6% interest in Luz del Sur and its interest in Tecsur, for cash proceeds of $3,549 million, net of transaction costs and as adjusted for post-closing adjustments, and on June 24, 2020, we sold our equity interests in our Chilean businesses, including our 100% interest in Chilquinta Energía and Tecnored and our 50% interest in Eletrans, for cash proceeds of $2,216 million, net of transaction costs and as adjusted for post-closing adjustments.

Losses from discontinued operations of $7 million in the three months ended September 30, 2020 was due to a reduction to the gain on sale of our Chilean businesses as a result of post-closing adjustments.

Earnings from discontinued operations of $1,840 million in the nine months ended September 30, 2020 included:

▪$1,499 million gain on the sale of our Peruvian businesses;

▪$248 million gain on the sale of our Chilean businesses;

▪$98 million operational earnings prior to the sale of our Peruvian and Chilean businesses; and

▪$7 million income tax benefit related to changes in outside basis differences from earnings and foreign currency effects.

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.

Utilities Revenues and Cost of Sales

Our utilities revenues include natural gas revenues at our California Utilities and Sempra Mexico’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 currently 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.

▪The California Utilities 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 customer billing cycles causing a difference between customer billings and recorded or authorized costs. 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.

The California Utilities’ 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 September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Natural gas revenues:
SoCalGas	$	1,106	$	842	$	3,738	$	3,247
SDG&E	157		134		585		498
Sempra Mexico	17		12		61		42
Eliminations and adjustments	(25)		(23)		(74)		(62)
Total	1,255		965		4,310		3,725
Electric revenues:
SDG&E	1,307		1,338		3,534		3,478
Eliminations and adjustments	(2)		(2)		(5)		(4)
Total	1,305		1,336		3,529		3,474
Total utilities revenues	$	2,560	$	2,301	$	7,839	$	7,199
Cost of natural gas(1):
SoCalGas	$	240	$	92	$	736	$	476
SDG&E	37		27		159		118
Sempra Mexico	13		2		25		8
Eliminations and adjustments	(8)		(7)		(28)		(20)
Total	$	282	$	114	$	892	$	582
Cost of electric fuel and purchased power(1):
SDG&E	$	324	$	430	$	869	$	921
Eliminations and adjustments	(12)		(1)		(41)		(3)
Total	$	312	$	429	$	828	$	918

(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 the California Utilities 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.

CALIFORNIA UTILITIES AVERAGE COST OF NATURAL GAS
(Dollars per thousand cubic feet)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
SoCalGas	$	5.01	$	1.95	$	3.46	$	2.21
SDG&E	5.40		3.79		4.62		3.56

In the three months ended September 30, 2021, our natural gas revenues increased by $290 million (30%) to $1.3 billion compared to the same period in 2020 primarily due to:

▪$264 million increase at SoCalGas, which included:

◦$148 million increase in cost of natural gas sold, which we discuss below,

◦$33 million higher non-service component of net periodic benefit cost in 2021, which fully offsets in Other (Expense) Income, net,

◦$31 million higher recovery of costs associated with refundable programs, which revenues are offset in O&M,

◦$26 million higher CPUC-authorized revenues, and

◦$20 million higher revenues from incremental and balanced capital projects; and

▪$23 million increase at SDG&E, which included:

◦$10 million increase in cost of natural gas sold, which we discuss below,

◦$6 million higher revenues primarily associated with PSEP, and

◦$3 million higher CPUC-authorized revenues.

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In the three months ended September 30, 2021, our cost of natural gas increased by $168 million to $282 million compared to the same period in 2020 primarily due to:

▪$148 million increase at SoCalGas primarily due to higher average natural gas prices; and

▪$10 million increase at SDG&E primarily due to higher average natural gas prices.

In the nine months ended September 30, 2021, our natural gas revenues increased by $585 million (16%) to $4.3 billion compared to the same period in 2020 primarily due to:

▪$491 million increase at SoCalGas, which included:

◦$260 million increase in cost of natural gas sold, which we discuss below,

◦$116 million higher recovery of costs associated with refundable programs, which revenues are offset in O&M,

◦$94 million higher CPUC-authorized revenues,

◦$62 million higher revenues from incremental and balanced capital projects, and

◦$26 million higher non-service component of net periodic benefit cost in 2021, which fully offsets in Other (Expense), Income, net, offset by

◦$84 million decrease due to the release of a regulatory liability in 2020 related to 2016-2018 forecasting differences that are not subject to tracking in the income tax expense memorandum account; and

▪$87 million increase at SDG&E, which included:

◦$41 million increase in cost of natural gas sold, which we discuss below,

◦$17 million higher recovery of costs associated with refundable programs, which revenues are offset in O&M,

◦$17 million higher CPUC-authorized revenues, and

◦$14 million higher revenues primarily associated with PSEP, offset by

◦$6 million decrease due to the release of a regulatory liability in 2020 related to 2016-2018 forecasting differences that are not subject to tracking in the income tax expense memorandum account.

In the nine months ended September 30, 2021, our cost of natural gas increased by $310 million (53%) to $892 million compared to the same period in 2020 primarily due to:

▪$260 million increase at SoCalGas primarily due to higher average natural gas prices; and

▪$41 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 September 30, 2021, our electric revenues, substantially all of which are at SDG&E, decreased by $31 million (2%), remaining at $1.3 billion compared to the same period in 2020 primarily due to:

▪$106 million lower cost of electric fuel and purchased power, which we discuss below; and

▪$12 million lower recovery of costs associated with refundable programs, which revenues are offset in O&M; offset by

▪$36 million charge in 2020 for amounts expected to be refunded to customers related to the Energy Efficiency Program inquiry;

▪$15 million higher revenues associated with SDG&E’s wildfire mitigation plan;

▪$13 million higher CPUC-authorized revenues;

▪$9 million higher revenues associated with lower income tax benefits from flow-through items;

▪$5 million higher revenue from transmission operations; and

▪$5 million higher revenues associated with a new customer information system.

Our utility cost of electric fuel and purchased power decreased by $117 million (27%) to $312 million in the three months ended September 30, 2021 compared to the same period in 2020 due to:

▪$106 million at SDG&E primarily due to higher purchased power costs caused by increased demand in 2020 and a decrease in residential demand in 2021 from an increase in rooftop solar adoption; and

▪$11 million higher intercompany eliminations associated with sales between SDG&E and Sempra Mexico due to the acquisition of ESJ in March 2021.

In the nine months ended September 30, 2021, our electric revenues, substantially all of which are at SDG&E, increased by $55 million (2%), remaining at $3.5 billion compared to the same period in 2020 primarily due to:

▪$78 million higher recovery of costs associated with refundable programs, which revenues are offset in O&M;

▪$51 million charge in 2020 for amounts expected to be refunded to customers related to the Energy Efficiency Program inquiry;

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▪$33 million higher CPUC-authorized revenues;

▪$33 million higher revenues associated with SDG&E’s wildfire mitigation plan;

▪$15 million higher revenues associated with lower income tax benefits from flow-through items; and

▪$8 million higher revenues associated with a new customer information system; offset by

▪$77 million decrease due to the release of a regulatory liability in 2020 related to 2016-2018 forecasting differences that are not subject to tracking in the income tax expense memorandum account;

▪$52 million lower cost of electric fuel and purchased power, which we discuss below;

▪$22 million lower revenues due to favorable resolution of regulatory matters in 2020; and

▪$13 million lower revenues from transmission operations, including the following favorable impacts in 2020 related to the March 2020 FERC-approved TO5 settlement proceeding:

◦$26 million to settle a rate base matter, and

◦$12 million impact from the retroactive application of the final TO5 settlement for 2019.

Our utility cost of electric fuel and purchased power decreased by $90 million (10%) to $828 million in the nine months ended September 30, 2021 compared to the same period in 2020 due to:

▪$52 million at SDG&E primarily due to higher purchased power costs caused by increased demand in 2020 and a decrease in residential demand in 2021 from an increase in rooftop solar adoption; and

▪$38 million higher intercompany eliminations associated with sales between SDG&E and Sempra Mexico 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 September 30,				Nine months ended September 30,
	2021		2020		2021		2020
REVENUES
Sempra Mexico	$	580	$	339	$	1,307	$	893
Sempra LNG	119		63		367		255
Parent and other(1)	(246)		(59)		(500)		(148)
Total revenues	$	453	$	343	$	1,174	$	1,000
COST OF SALES(2)
Sempra Mexico	$	247	$	89	$	488	$	202
Sempra LNG	207		62		419		145
Parent and other(1)	(234)		(61)		(459)		(147)
Total cost of sales	$	220	$	90	$	448	$	200

(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 September 30, 2021, revenues from our energy-related businesses increased by $110 million (32%) to $453 million compared to the same period in 2020 primarily due to:

▪$241 million increase at Sempra Mexico primarily due to:

◦$154 million increase from the marketing business primarily due to higher natural gas prices and volumes,

◦$45 million higher revenues from the Veracruz and Mexico City terminals placed in service in March and July of 2021, respectively, including a $16 million selling profit on a sales-type lease relating to the commencement of a rail facility lease at the Veracruz terminal in the third quarter of 2021,

◦$20 million higher revenues from TdM primarily due to unrealized gains on commodity derivatives in 2021 compared to unrealized losses in 2020 and higher volumes and power prices, and

◦$8 million increase from the renewables business primarily due to the acquisition of ESJ in March 2021 and renewable assets placed in service in December 2020 and March 2021; and

▪$56 million increase at Sempra LNG primarily due to:

◦$122 million increase from LNG marketing operations primarily from higher natural gas and LNG cargo sales to Sempra Mexico mainly as a result of higher natural gas prices and volumes, offset by

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◦$68 million decrease from natural gas marketing operations primarily due to higher losses in 2021 compared to 2020, mainly driven by changes in natural gas prices, offset by

▪$187 million decrease primarily from higher intercompany eliminations associated with sales between Sempra LNG and Sempra Mexico.

In the three months ended September 30, 2021, the cost of sales for our energy-related businesses increased by $130 million to $220 million compared to the same period in 2020 primarily due to:

▪$158 million increase at Sempra Mexico primarily due to higher natural gas prices and volumes at the marketing business and at TdM; and

▪$145 million increase at Sempra LNG mainly from natural gas marketing activities due to higher natural gas purchases; offset by

▪$173 million decrease primarily from higher intercompany eliminations associated with sales between Sempra LNG and Sempra Mexico.

In the nine months ended September 30, 2021, revenues from our energy-related businesses increased by $174 million (17%) to $1.2 billion compared to the same period in 2020 primarily due to:

▪$414 million increase at Sempra Mexico primarily due to:

◦$277 million increase from the marketing business primarily due to higher natural gas prices and volumes,

◦$54 million higher revenues from the Veracruz and Mexico City terminals placed in service in March and July of 2021, respectively, including a $16 million selling profit on a sales-type lease relating to the commencement of a rail facility lease at the Veracruz terminal in the third quarter of 2021,

◦$31 million increase from the renewables business primarily due to the acquisition of ESJ in March 2021 and renewable assets placed in service in December 2020 and March 2021, and

◦$29 million higher revenues from TdM mainly due to higher volumes and power prices, offset by unrealized losses on commodity derivatives in 2021 compared to unrealized gains in 2020; and

▪$112 million increase at Sempra LNG primarily due to:

◦$232 million increase from LNG marketing operations primarily from higher natural gas and LNG cargo sales to Sempra Mexico mainly as a result of higher natural gas prices and volumes, offset by

◦$121 million decrease from natural gas marketing operations primarily due to losses in 2021 compared to gains in 2020, mainly driven by changes in natural gas prices; offset by

▪$352 million decrease primarily from higher intercompany eliminations associated with sales between Sempra LNG and Sempra Mexico.

In the nine months ended September 30, 2021, the cost of sales for our energy-related businesses increased by $248 million to $448 million compared to the same period in 2020 primarily due to:

▪$286 million increase at Sempra Mexico primarily due to higher natural gas prices and volumes at the marketing business and at TdM; and

▪$274 million increase at Sempra LNG mainly from natural gas marketing activities primarily due to higher natural gas purchases; offset by

▪$312 million decrease primarily from higher intercompany eliminations associated with sales between Sempra LNG and Sempra Mexico.

Operation and Maintenance

In the three months ended September 30, 2021, O&M increased by $55 million (5%) to $1.1 billion compared to the same period in 2020 primarily due to:

▪$52 million increase at SoCalGas primarily due to:

◦$31 million higher expenses associated with refundable programs, which costs incurred are recovered in revenue, and

◦$21 million higher non-refundable operating costs;

▪$16 million increase at Sempra Mexico primarily from the renewables business, including the acquisition of ESJ in March 2021; and

▪$15 million increase at Sempra LNG primarily due to the timing of employee benefit expenses and certain non-capitalizable expenses at ECA LNG Phase 1 in 2021, which reached a final investment decision in November 2020; offset by

▪$25 million decrease at SDG&E primarily due to:

◦$14 million lower non-refundable operating costs, and

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◦$11 million lower expenses associated with refundable programs, which costs incurred are recovered in revenue.

In the nine months ended September 30, 2021, O&M increased by $331 million (12%) to $3.1 billion compared to the same period in 2020 primarily due to:

▪$175 million increase at SoCalGas primarily due to:

◦$116 million higher expenses associated with refundable programs, which costs incurred are recovered in revenue, and

◦$59 million higher non-refundable operating costs;

▪$102 million increase at SDG&E primarily due to:

◦$95 million higher expenses associated with refundable programs, which costs incurred are recovered in revenue, and

◦$7 million higher non-refundable operating costs;

▪$44 million increase at Sempra Mexico primarily from the renewables business, including the acquisition of ESJ in March 2021, and expenses associated with the growth in the business; and

▪$24 million increase at Sempra LNG primarily due to certain non-capitalizable expenses at ECA LNG Phase 1 in 2021, which reached a final investment decision in November 2020, and expected credit losses associated with the guarantee related to Cameron LNG JV’s SDSRA; offset by

▪$18 million decrease at Parent and other primarily from lower retained operating costs offset by higher deferred compensation expense.

Aliso Canyon Litigation and Regulatory Matters

In the three months and nine months ended September 30, 2021, SoCalGas recorded a charge of $1,571 million related to agreements associated with civil litigation against SoCalGas and Sempra pertaining to the Leak, which we describe in Note 11 of the Notes to Condensed Consolidated Financial Statements. In the three months and nine months ended September 30, 2020, SoCalGas recorded charges of $27 million and $127 million, respectively, related to civil litigation and regulatory matters pertaining to the Leak.

Other (Expense) Income, Net

As part of our central risk management function, we may enter into foreign currency derivatives to hedge Sempra Mexico parent’s exposure to movements in the Mexican peso from its controlling interest in IEnova. The gains/losses associated with these derivatives are included in Other (Expense) Income, Net, as described below, and partially mitigate the transactional effects of foreign currency and inflation included in Income Tax Expense for Sempra Mexico’s consolidated entities and in Equity Earnings for Sempra Mexico’s equity method investments. We also utilized foreign currency derivatives in 2020 to hedge exposure to fluctuations in the Peruvian sol and Chilean peso related to the sales of our operations in Peru and Chile, respectively. 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 September 30, 2021 was $55 million compared to other income, net, of $29 million in the same period in 2020. The change was primarily due to:

▪$20 million net losses in 2021 from impacts associated with interest rate and foreign exchange instruments and foreign currency transactions compared to net gains of $34 million for the same period in 2020 primarily due to:

◦$18 million foreign currency losses in 2021 compared to $15 million foreign currency gains in 2020 on a Mexican peso-denominated loan to IMG JV, which is offset in Equity Earnings, and

◦$3 million losses in 2021 on foreign currency derivatives and cross-currency swaps compared to $19 million gains for the same period in 2020 as a result of fluctuation of the Mexican peso;

▪$18 million higher non-service component of net periodic benefit cost in 2021; and

▪$16 million lower investment gains in 2021 on dedicated assets in support of our executive retirement and deferred compensation plans; offset by

▪$6 million fine at SDG&E in 2020 related to the Energy Efficiency Program inquiry.

Other income, net, in the nine months ended September 30, 2021 was $52 million compared to other expense, net, of $163 million in the same period in 2020. The change was primarily due to:

▪$188 million lower net losses from impacts associated with interest rate and foreign exchange instruments and foreign currency transactions primarily due to:

◦$107 million lower foreign currency losses on a Mexican peso-denominated loan to IMG JV, which is offset in Equity Earnings, and

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◦$101 million lower losses on foreign currency derivatives and cross-currency swaps as a result of fluctuation of the Mexican peso; offset by

◦$22 million lower net gains in 2021 on other foreign currency transactional effects;

▪$19 million higher investment gains on dedicated assets in support of our executive retirement and deferred compensation plans;

▪$7 million higher AFUDC equity at SoCalGas; and

▪$6 million fine at SDG&E in 2020 related to the Energy Efficiency Program inquiry; offset by

▪$8 million decrease in regulatory interest at the California Utilities due to the release of a regulatory liability in 2020 related to 2016-2018 forecasting differences that are not subject to tracking in the income tax expense memorandum account; and

▪$7 million higher non-service component of net periodic benefit cost in 2021.

Income Taxes

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

INCOME TAX (BENEFIT) EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended September 30,						Nine months ended September 30,
	2021			2020			2021			2020
Sempra:
Income tax (benefit) expense from continuing operations	$	(342)		$	99		$	(45)		$	60
(Loss) income from continuing operations before income taxes and equity earnings	$	(1,365)		$	201		$	(316)		$	1,061
Equity earnings, before income tax(1)	137			117			457			158
Pretax (loss) income	$	(1,228)		$	318		$	141		$	1,219
Effective income tax rate	28		%	31		%	(32)		%	5		%
SDG&E:
Income tax expense	$	90		$	33		$	168		$	161
Income before income taxes	$	295		$	211		$	771		$	794
Effective income tax rate	31		%	16		%	22		%	20		%
SoCalGas:
Income tax (benefit) expense	$	(437)		$	(6)		$	(335)		$	95
(Loss) income before income taxes	$	(1,563)		$	(30)		$	(959)		$	521
Effective income tax rate	28		%	20		%	35		%	18		%

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

Sempra

Sempra’s income tax benefit in the three months ended September 30, 2021 compared to an income tax expense in the same period in 2020 was primarily due to:

▪$439 million income tax benefit in 2021 compared to $5 million income tax benefit in 2020 associated with the Aliso Canyon natural gas storage facility litigation and regulatory matters; and

▪$33 million income tax benefit in 2021 compared to $44 million income tax expense in 2020 from foreign currency and inflation effects and associated derivatives; offset by

▪lower income tax benefits from flow-through items.

Sempra’s income tax benefit in the nine months ended September 30, 2021 compared to an income tax expense in the same period in 2020 was primarily due to:

▪$439 million income tax benefit in 2021 compared to $33 million income tax benefit in 2020 associated with the Aliso Canyon natural gas storage facility litigation and regulatory matters;

▪$22 million income tax benefit in 2021 from the remeasurement of certain deferred income taxes; and

▪higher income tax benefits from flow-through items; offset by

▪$8 million income tax expense in 2021 compared to $263 million income tax benefit in 2020 from foreign currency and inflation effects and associated derivatives; and

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▪$11 million lower income tax benefit related to share-based compensation.

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

SDG&E’s income tax expense increased in the three months ended September 30, 2021 compared to the same period in 2020 primarily due to higher pretax income and lower income tax benefits from flow-through items.

SDG&E’s income tax expense increased in the nine months ended September 30, 2021 compared to the same period in 2020 primarily due to lower income tax benefits from flow-through items.

SoCalGas

SoCalGas’ income tax benefit increased in the three months ended September 30, 2021 compared to the same period in 2020 primarily due to $439 million income tax benefit in 2021 compared to $5 million income tax benefit in 2020 associated with the Aliso Canyon natural gas storage facility litigation and regulatory matters.

SoCalGas’ income tax benefit in the nine months ended September 30, 2021 compared to an income tax expense in the same period in 2020 was primarily due to $439 million income tax benefit in 2021 compared to $33 million income tax benefit in 2020 associated with the Aliso Canyon natural gas storage facility litigation and regulatory matters.

Equity Earnings

In the three months ended September 30, 2021, equity earnings increased by $65 million (20%) to $391 million compared to the same period in 2020 primarily due to:

▪$40 million higher equity earnings at IMG JV, primarily due to foreign currency effects, including $18 million foreign currency gains in 2021 compared to $15 million foreign currency losses in 2020 on IMG JV’s Mexican peso-denominated loans from its JV owners, which is fully offset in Other (Expense) Income, Net; and

▪$21 million higher equity earnings at Cameron LNG JV primarily due to the three-train liquefaction project achieving full commercial operations in August 2020.

In the nine months ended September 30, 2021, equity earnings increased by $200 million (24%) to $1.0 billion compared to the same period in 2020 primarily due to:

▪$50 million equity earnings in 2021 compared to $100 million equity losses in 2020 related to our investment in RBS Sempra Commodities to settle pending VAT matters and related legal costs;

▪$147 million higher equity earnings at Cameron LNG JV primarily due to the three-train liquefaction project achieving full commercial operations in August 2020; and

▪$23 million higher equity earnings at Oncor Holdings primarily due to higher revenues from rate updates to reflect increases in invested capital and customer growth, offset by increased operating costs and expenses attributable to invested capital, and lower revenues due to an annual energy efficiency program performance bonus recognized in 2020, but pending PUCT approval in 2021; offset by

▪$122 million lower equity earnings at Sempra Mexico, which included:

◦$103 million lower equity earnings at IMG JV, primarily due to foreign currency effects, including $107 million lower foreign currency gains on IMG JV’s Mexican peso-denominated loans from its JV owners, which is fully offset in Other (Expense) Income, Net, and

◦$15 million lower equity earnings at TAG JV primarily due to income tax expense in 2021 compared to a benefit in 2020.

Earnings Attributable to Noncontrolling Interests

In the three months ended September 30, 2021, earnings attributable to NCI decreased by $17 million to $5 million compared to the same period in 2020 primarily due to the increase in our ownership interest in IEnova as a result of the exchange offer and subsequent cash tender offer, which we discuss in Note 1 of the Notes to Condensed Consolidated Financial Statements, offset by an increase mainly from foreign currency effects as a result of fluctuation of the Mexican peso.

In the nine months ended September 30, 2021, earnings attributable to NCI decreased by $153 million to $48 million compared to the same period in 2020 primarily due to lower earnings at Sempra Mexico and from the increase in our ownership interest in IEnova as a result of the exchange offer and subsequent cash tender offer.

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Preferred Dividends

In the three months ended September 30, 2021, preferred dividends decreased by $37 million to $11 million compared to the same period in 2020 primarily due to the mandatory conversion of all series A preferred stock and series B preferred stock in January 2021 and July 2021, respectively.

In the nine months ended September 30, 2021, preferred dividends decreased by $69 million to $52 million compared to the same period in 2020 primarily due to the mandatory conversion of all series A preferred stock and series B preferred stock in January 2021 and July 2021, respectively, offset by the issuance of series C preferred stock in June 2020.

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. Prior to the sales of our South American businesses in 2020, our operations in South America used their local currency as their functional currency. 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.

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 nine months ended September 30, 2021, the change in our earnings as a result of foreign currency translation rates was not material compared to the same period in 2020.

Transactional Impacts

Income statement activities at our foreign 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 September 30,
	2021		2020		2021		2020
Other (expense) income, net	$	(55)	$	29	$	(20)	$	34
Income tax benefit (expense)	342		(99)		33		(44)
Equity earnings	391		326		16		(23)
(Loss) income from continuing operations, net of income tax	(632)		428		29		(33)
(Loss) income from discontinued operations, net of income tax	—		(7)		—		—
Earnings attributable to noncontrolling interests	(5)		(22)		(1)		15
(Losses) earnings attributable to common shares	(648)		351		28		(18)
	Nine months ended September 30,
	2021		2020		2021		2020
Other (expense) income, net	$	52	$	(163)	$	(36)	$	(224)
Income tax benefit (expense)	45		(60)		(8)		263
Equity earnings	1,022		822		—		141
(Loss) income from continuing operations, net of income tax	751		1,823		(44)		180
(Loss) income from discontinued operations, net of income tax	—		1,850		—		15
Earnings attributable to noncontrolling interests	(48)		(201)		3		(84)
(Losses) earnings attributable to common shares	650		3,350		(41)		111

CAPITAL RESOURCES AND LIQUIDITY

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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” and “Part II – Item 7. MD&A – Capital Resources and Liquidity” in the Annual Report.

Sempra Infrastructure Partners

As we discuss in Note 1 of the Notes to Condensed Consolidated Financial Statements, on October 1, 2021, we completed the sale of a 20% equity interest in Sempra Infrastructure Partners, which generally represents the combined businesses of Sempra LNG and IEnova, to KKR for cash proceeds of $3.37 billion, subject to post-closing adjustments. On October 1, 2021, Sempra Infrastructure Partners paid $149 million to KKR for reimbursement of certain expenses that KKR incurred in connection with closing the transaction. We intend to use the proceeds from the sale to fund capital investments in support of additional growth opportunities and strengthen our balance sheet by reducing debt, which we discuss below in “Long-Term Debt Activities.”

We have also entered into an accommodation and support agreement under which KKR has the ability to borrow from Sempra up to $300 million plus reimbursement of certain fees related to such borrowing, which we fully funded on November 1, 2021. This loan is due to be repaid in full no later than October 1, 2029 and bears compound interest at 5% per annum.

The completion of the sale of NCI in Sempra Infrastructure Partners reduced our ownership interest in Sempra Infrastructure Partners and requires us to share control over certain business decisions with our minority partner, which introduces a number of risks similar to those associated with sharing business control. Moreover, the decrease in our ownership of Sempra Infrastructure Partners will also decrease our share of the cash flows, profits and other benefits these businesses currently or may in the future produce, which could materially adversely affect our results of operations, cash flows, financial condition and/or prospects. We discuss these risks and uncertainties further in “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 our credit facilities, distributions from our equity method investments, issuances of debt, project financing and funding from minority interest owners. We believe that these cash flow sources, combined with available funds, will be adequate to fund our current operations, including to:

▪finance capital expenditures

▪meet liquidity requirements

▪fund dividends

▪fund new business or asset acquisitions or start-ups

▪fund capital contribution requirements

▪repay long-term debt

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

Sempra and the California Utilities currently have reasonable access to the money markets and capital markets and are not currently constrained in their ability to borrow money at reasonable rates from commercial banks, under existing revolving credit facilities or through public offerings registered with the SEC. 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 and disruptions to the money markets and capital markets, due to the COVID-19 pandemic or otherwise, worsen. 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

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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 intention to maintain our investment-grade credit ratings and capital structure.

We have significant investments in several trusts to provide for future payments of pensions and other postretirement benefits and nuclear decommissioning. Changes in asset values, which are dependent on activity in the equity and fixed income markets, have not materially and adversely affected the trust funds’ abilities to make required payments. However, changes in asset values or other factors in future periods, such as changes to discount rates, assumed rates of return, mortality tables and regulations, may impact funding requirements for pension and other postretirement benefits plans. Funding requirements for SDG&E’s NDT could also be impacted by the timing and amount of SONGS decommissioning costs. At the California Utilities, funding requirements are generally recoverable in rates. We discuss our employee benefit plans and SDG&E’s NDT, including our investment allocation strategies for assets in these trusts, in Notes 9 and 15, respectively, of the Notes to Consolidated Financial Statements in the Annual Report.

Available Funds

Our committed lines of credit provide liquidity and support commercial paper. As we discuss in Note 7 of the Notes to Condensed Consolidated Financial Statements, Sempra, SDG&E and SoCalGas each have five-year credit agreements expiring in 2024. In addition, Sempra Mexico has committed lines of credit that expire in 2023 and 2024 and uncommitted revolving credit facilities that expire in 2022 and 2023. Sempra Infrastructure Partners intends to enter into its own revolving credit facility, although such a credit facility and its timing remain uncertain.

The table below shows the amount of available funds at September 30, 2021, including available unused credit on these primary U.S. and foreign lines of credit.

AVAILABLE FUNDS AT SEPTEMBER 30, 2021
(Dollars in millions)
	Sempra		SDG&E		SoCalGas
Unrestricted cash and cash equivalents(1)	$	873	$	239	$	226
Available unused credit(2)(3)	6,312		1,500		750

(1)    Amounts at Sempra include $138 million held in non-U.S. jurisdictions. We discuss repatriation in Note 8 of the Notes to Consolidated Financial Statements in the Annual Report.

(2)    Available unused credit is the total available on Sempra’s, SDG&E’s, SoCalGas’, Sempra Mexico’s and Sempra LNG’s credit facilities that we discuss in Note 7 of the Notes to Condensed Consolidated Financial Statements.

(3)    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. Our California Utilities use short-term debt primarily to meet working capital needs. Revolving lines of credit, commercial paper and a term loan were our primary sources of short-term debt funding in the first nine months of 2021.

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

Issuances of and payments on long-term debt in the first nine months of 2021 included the following:

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LONG-TERM DEBT ISSUANCES AND PAYMENTS
(Dollars in millions)
Issuances:	Amount at issuance		Maturity
SDG&E 2.95% green first mortgage bonds	$	750	2051
Sempra LNG variable rate notes	274		2025
Payments:	Payments		Maturity
Sempra variable rate notes	$	850	2021
SDG&E 3% first mortgage bonds	350		2021
SDG&E 1.914% amortizing first mortgage bonds	36		2021
SDG&E variable rate 364-day term loan	200		2021
Sempra Mexico amortizing variable rate notes	33		2021
Sempra Mexico amortizing variable and fixed rate loans	29		2021

In October 2021, Sempra Mexico used proceeds from borrowings against its committed and uncommitted lines of credit to fully repay $175 million of outstanding principal plus accrued and unpaid interest on the ESJ fixed- and variable-rate loan prior to its scheduled maturity in 2033, and $375 million of outstanding principal plus accrued and unpaid interest on the Ventika fixed- and variable-rate loans prior to scheduled maturity dates through 2032, and recognized approximately $50 million ($30 million after tax and NCI) in charges associated with hedge termination costs and a write-off of unamortized debt issuance costs.

On November 1, 2021, Sempra issued notices to redeem, at respective make-whole redemption prices, an aggregate principal amount of $2.35 billion of senior unsecured notes prior to scheduled maturities in 2022 through 2025. Upon redemption, which is scheduled to occur in December 2021, we expect to recognize approximately $128 million ($93 million after tax) in charges associated with the make-whole premiums from the early redemptions and write-off of unamortized discount and debt issuance costs.

We discuss our long-term debt activities 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 nine months of 2021.

CREDIT RATINGS AT SEPTEMBER 30, 2021
	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 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 September 30, 2021.

Loans with Affiliates

At September 30, 2021, Sempra had $686 million in loans due from unconsolidated affiliates and $328 million in loans due to unconsolidated affiliates.

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California Utilities

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, cash flows from operations, and debt issuances will continue to be adequate to fund their respective current operations and planned capital expenditures. Additionally, Sempra has elected to make equity contributions to SoCalGas, which began in September 2021, that are sufficient to maintain SoCalGas’ approved capital structure in connection with the accruals related to the Leak. The California Utilities manage their capital structure 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 in rates through billings to customers.

COVID-19 Pandemic Protections

The California Utilities 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, the California Utilities implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for all customers (except for SoCalGas’ noncore customers), waiving late payment fees, and offering flexible payment plans. Such measures ended on June 30, 2021, except for the suspension of service disconnections that ended on September 30, 2021. At the CPUC’s direction, the California Utilities have started to automatically enroll residential and small business customers with past-due balances in long-term repayment plans. The CPUC is continuing to consider the impacts of any state or federal relief programs on customer arrearages and if further debt relief is warranted.

The CPUC authorized each of the California Utilities to track and request recovery of incremental costs associated with complying with residential customer protection measures implemented by the CPUC related to the COVID-19 pandemic, including costs associated with suspending service disconnections and uncollectible expenses that arise from customers’ failure to pay. The California Utilities expect to pursue recovery of small and medium-large commercial and industrial customers’ tracked costs in rates in a future CPUC proceeding, which recovery is not assured. Uncollectible expenses related to residential customers are recorded in a two-way balancing account as we discuss below.

The continuation of these circumstances could result in a further reduction in payments received from the California Utilities’ customers and a further increase in uncollectible accounts, which could become material, and any inability or delay in recovering all or a substantial portion of these costs could have a material adverse effect on the cash flows, financial condition and results of operations of Sempra, SDG&E and SoCalGas. We discuss regulatory mechanisms in Note 4 of the Notes to Condensed Consolidated Financial Statements.

Disconnection OIR

In June 2020, the CPUC issued a decision addressing residential service disconnections that, among other things, allows each of the California Utilities to establish a two-way balancing account to record the uncollectible expenses associated with residential customers’ inability to pay their electric or gas bills. This decision also directs the California Utilities to establish an AMP that provides successfully participating, income-qualified residential customers with relief from outstanding utility bill amounts and became effective in February 2021. The California Utilities have recorded increases in their allowances for uncollectible accounts primarily related to expected forgiveness of outstanding bill amounts for customers eligible under the AMP. The AMP could result in a further reduction in payments received from the California Utilities’ customers and a further increase to uncollectible accounts, which could become material, and any inability to recover these costs could have a material adverse effect on the cash flows, financial condition and results of operations of Sempra, SDG&E and SoCalGas.

CCM

A CPUC cost of capital proceeding determines a utility’s authorized capital structure and authorized return on rate base. In December 2019, the CPUC approved the cost of capital and rate structures for SDG&E and SoCalGas that became effective on

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January 1, 2020 and will remain in effect through December 31, 2022, subject to the CCM. The CCM considers 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. 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.

Alternatively, under the CCM, each of the California Utilities 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. In August 2021, SDG&E filed an application with the CPUC to update its cost of capital effective January 1, 2022 due to the ongoing effects of the COVID-19 pandemic. In this application, SDG&E proposed to adjust its authorized capital structure by increasing its common equity ratio from 52% to 54%. SDG&E also proposed to increase its authorized ROE from 10.20% to 10.55% and decrease its authorized cost of debt from 4.59% to 3.84%. As a result, SDG&E’s proposed return on rate base would decrease from 7.55% to 7.46% if such application is approved by the CPUC as filed. SDG&E filed a joint motion with PG&E and Edison to consolidate all three utilities’ cost of capital applications given the overlapping issues of law and fact, which joint motion was granted in October 2021.

For the measurement period ended September 30, 2021, the CCM would trigger for SDG&E 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%. However, SDG&E’s application to update its cost of capital effective January 1, 2022, if accepted by the CPUC, would supersede the CCM from applying. If such application is not accepted, the CCM would be effective 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. SDG&E has requested that a final CPUC decision on its interim cost of capital application be issued in the first half of 2022.

For the measurement period ended September 30, 2021, the CCM was not triggered for SoCalGas. SoCalGas expects to file its next cost of capital application in April 2022 for a January 1, 2023 effective date.

SDG&E

Wildfire Fund

The carrying value of SDG&E’s Wildfire Fund asset totals $371 million at September 30, 2021. We describe the Wildfire Legislation and related accounting treatment 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, including with respect to wildfires that have occurred since enactment of the Wildfire Legislation in July 2019. In such a situation, SDG&E may recognize a reduction of its Wildfire Fund asset and record a charge against earnings when there is a reduction of the available coverage due to recoverable claims from any of the participating IOUs. At September 30, 2021, PG&E recorded a receivable from the Wildfire Fund indicating that it may seek reimbursement in the future from the Wildfire Fund for losses associated with the Dixie Fire. 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 cash flows, results of operations and financial condition.

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 regulatory account balance as of January 1 of each year. Such potential recovery would be incremental to wildfire costs authorized in its GRC and would be subject to reasonableness review. We expect the CPUC to issue a final decision in the first half of 2022.

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.

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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 September 30, 2021, SoCalGas estimates certain costs related to the Leak are $3,199 million (the cost estimate). This cost estimate may increase significantly as more information becomes available. A portion of the cost estimate has been paid, and $1,976 million is accrued as Reserve for Aliso Canyon Costs at September 30, 2021 on SoCalGas’ and Sempra’s Condensed Consolidated Balance Sheets. Sempra has elected to make equity contributions to SoCalGas that are sufficient to maintain SoCalGas’ approved capital structure in connection with the accruals related to these agreements, and Sempra does not expect to issue common equity in relation to these agreements. In connection with this election, in September 2021, Sempra made an initial equity contribution of $800 million to SoCalGas.

Except for the amounts paid or estimated to settle certain legal and regulatory matters, the cost estimate does not include 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. These costs or losses not included in the cost estimate could be significant and could have a material adverse effect on SoCalGas’ and Sempra’s cash flows, financial condition and results of operations.

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 September 30, 2021, we recorded the expected recovery of the cost estimate related to the Leak of $414 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 $865 million of insurance proceeds we received through September 30, 2021. 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, which could be significant, could have a material adverse effect on SoCalGas’ and Sempra’s cash flows, financial condition, results of operations 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 element 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 September 30, 2021, the Aliso Canyon natural gas storage facility had a net book value of $863 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.

Labor Relations

Field, technical and most clerical employees at SoCalGas are represented by the Utility Workers Union of America or the International Chemical Workers Union Council. The collective bargaining agreement for these employees covering wages, hours, working conditions, and medical and other benefit plans expired on September 30, 2021. On October 1, 2021, SoCalGas and

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representatives of the unions reached a tentative agreement for a new collective bargaining agreement to be in effect through 2024. To allow time for ratification of the new collective bargaining agreement by the employees, it was also agreed that the terms and conditions of the existing agreement would be extended through the date the new collective bargaining agreement is ratified. We expect the new collective bargaining agreement to be ratified in November 2021.

Franchise Agreement

SoCalGas’ natural gas franchise agreement with the City of Los Angeles is due to expire December 31, 2021. SoCalGas expects that it will participate in the competitive bid process for a new franchise agreement, consistent with the terms of the City Charter.

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 which would reduce the cash available to us for other purposes, could increase our indebtedness and could ultimately materially adversely affect our results of operations, liquidity, financial condition and prospects. Oncor’s ability to pay dividends may be limited by factors such as its credit ratings, regulatory capital requirements, debt-to-equity ratio approved by the PUCT and other restrictions. In addition, Oncor will not pay dividends 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.

Winter Weather Event

In February 2021, ERCOT required electric distribution companies, including Oncor, to significantly reduce demand on the grid because electricity generation was insufficient to meet demand due to extreme winter weather. As a result of the load shedding events and state-wide power outages, the PUCT, other governmental authorities or third parties, including Oncor’s customers, have taken or could take other measures to address financial challenges experienced as a result of the event, which could adversely impact Oncor’s collections and cash flows and, in turn, could adversely impact Sempra. The Texas Legislature has passed, and the Governor of Texas has signed, various legislation affecting the ERCOT market, which addresses matters including certain weatherization requirements and fines of up to $1 million per day for failures to comply with such requirements, enabling ERCOT to finance certain amounts owed by ERCOT market participants relating to the winter weather event, creation of the Texas Energy Reliability Council, identification of gas facilities that are critical to electric-generator fuel supplies, coordination between the gas and electric industries, and changes in the composition of the PUCT and the ERCOT board of directors. In addition, various regulatory and governmental entities have also commenced investigations or indicated an intent to investigate the operation of the ERCOT grid during this extreme winter weather event and potential future actions to improve grid reliability. Any significant changes relating to the ERCOT market that impact transmission and distribution utilities as a result of such proceedings or otherwise could materially adversely impact Oncor. If Oncor does not successfully respond to these changes and any other legislative, regulatory, or market or industry developments applicable to it, Oncor could suffer a deterioration in its results of operations, financial condition, cash flows and/or prospects, which could materially adversely affect Sempra’s results of operations, financial condition, cash flows and/or prospects.

Sempra Mexico

Construction Projects

Sempra Mexico began commercial operations of its new terminals for the receipt, storage and delivery of refined fuel products in the new port of Veracruz on March 19, 2021 and in Mexico City on July 2, 2021. The two terminals have a combined storage capacity of more than 2.6 million barrels. The storage capacity for both terminals is contracted with Valero Energy Corporation. Sempra Mexico also completed construction and began commercial operations of a new solar facility (Border Solar) in Juárez, Chihuahua on March 25, 2021.

Sempra Mexico is currently constructing additional terminals for the receipt, storage, and delivery of liquid fuels in the vicinity of Puebla and Topolobampo. We expect the Puebla project to commence commercial operations in 2021 and the Topolobampo project to commence commercial operations in the first half of 2022. However, expected commencement dates could be delayed by worsening or extended disruptions of project construction caused by the COVID-19 pandemic or other factors outside our control. Sempra Mexico is continuing to monitor the impacts of the COVID-19 pandemic on cash flows and results of operations. We expect to fund these capital expenditures, investments and operations at IEnova with available funds, including credit facilities, and funds internally generated by the Sempra Mexico businesses, as well as funds from project financing, sales of

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securities, interim funding from the parent or affiliates, and partnering in JVs. Sempra Mexico is also developing terminals for the receipt, storage, and delivery of liquid fuels in the vicinity of Manzanillo, Guadalajara 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 IEnova’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 IEnova’s custody. Although IEnova filed an amparo lawsuit against the closure and has submitted proof of the legal origin of the products to the prosecutor’s office, we are unable to predict when the investigation will be completed and whether the facility will be able to resume normal operations. If the terminal were to be shut down or commissioning operations significantly curtailed for an extended period of time, Sempra’s results of operations, financial condition, cash flows and/or prospects could be materially adversely affected.

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.

Legal and Regulatory Matters

Energía Costa Azul. IEnova 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). 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. Certain of these land disputes involve land on which portions of the ECA LNG liquefaction facilities, including ECA LNG Phase 1 currently under construction, 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.

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.

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 IEnova and a force majeure event. Citing these circumstances, the customers subsequently stopped making payments of amounts due under their respective LNG storage and regasification agreements. IEnova has rejected the customers’ assertions and has drawn on the customers’ letters of credit provided as payment security. The parties engaged in discussions under the applicable contractual dispute resolution procedures without coming to a mutually acceptable resolution. In July 2020, Shell Mexico submitted a request for arbitration of the dispute and although Gazprom has joined the proceeding, Gazprom has since replenished the amounts drawn on its letter of credit and has resumed making regular monthly payments under its LNG storage and regasification agreement. As a consequence, IEnova is not currently drawing on Gazprom’s letter of credit but expects to continue to draw on Shell Mexico’s letter of credit. IEnova intends to avail itself of its available claims, defenses, rights and remedies in the arbitration proceeding, including seeking dismissal of the customers’ claims. In addition to the arbitration proceeding, Shell Mexico also filed a constitutional challenge to the CRE’s approval of the update to the general terms and conditions and an additional constitutional claim against the issuance of the liquefaction permit. Shell Mexico’s request to stay the CRE’s approval of the general terms and conditions was denied in October 2020 and upheld on appeal. A decision on the merits is pending. The claim regarding the liquefaction permit issuance was denied in March 2021 and upheld on appeal. A hearing on the merits of the arbitration case was held in October 2021.

We discuss these matters in further detail in Note 11 of the Notes to Condensed Consolidated Financial Statements. 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, cash flows, financial condition, results of operations and/or prospects.

Sonora Pipeline. As we discuss in Note 11 of the Notes to Condensed Consolidated Financial Statements, the Guaymas-El Oro segment of the Sonora pipeline has been inoperable since August 2017. Under an agreement between IEnova and the CFE, the CFE will resume making payments only when the damaged section of the Guaymas-El Oro segment of the Sonora pipeline is

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repaired. If the pipeline is not repaired by March 14, 2022, and the parties do not agree on a new service start date, IEnova retains the right to terminate the contract and seek to recover its reasonable and documented costs and lost profits. At September 30, 2021, Sempra Mexico had $436 million in PP&E, net, related to the Guaymas-El Oro segment of the Sonora pipeline, which could be subject to impairment if IEnova is unable to make such repairs (which have not commenced) or re-route the pipeline (which has not been agreed to by the parties) and resume operations in the Guaymas-El Oro segment of the Sonora pipeline or if IEnova 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.

In June 2014, IEnova 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. IEnova intends to file a special judicial action whereby it will ask a civil court to acknowledge the existence of the easement and to determine the consideration the landowner should receive in exchange for the easement. The failure to stay this judgment pending the resolution of IEnova’s planned special judicial action or prevail in preserving the easement in the special judicial action could require us to modify the route of the pipeline and could require a temporary shutdown of this portion of the pipeline, which 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. As we discuss in Note 11 of the Notes to Condensed Consolidated Financial Statements, the Mexican government and certain Mexican governmental agencies have amended existing laws and rules, updated transmission rates, and issued orders, decrees and regulations that could materially impact IEnova’s participation in the country’s energy market. Those actions would, among other things, create barriers for renewable energy facilities to enter the wholesale electricity market, threaten the prospects for private-party renewable energy generation in the country, limit the ability to dispatch renewable energy and to receive or maintain operation permits and increase costs of electricity for legacy renewables and cogeneration energy contract holders. In addition, those actions (i) require that only state-owned companies may import and export hydrocarbons, refined products, petrochemicals, and biofuels through channels other than those authorized, which could adversely affect new projects that have not obtained such authorizations and projects under construction, in development or in operation, and (ii) grant SENER and the CRE additional powers to suspend and revoke permits related to the midstream and downstream sectors. Some of these newly enacted amendments, orders, rules, decrees and regulations have been challenged or temporarily suspended through litigation and judicial rulings obtained by businesses operating in the power sector, including by IEnova.

As we discuss in Note 11 of the Notes to Condensed Consolidated Financial Statements, in September 2021, the President of Mexico presented a constitutional reform initiative that introduces significant changes to the legal and economic principles underlying the country’s energy reform of 2013, generating imminent risks for private investments in this sector. Electricity generation permits and contracts for the sale of electricity to the CFE, including permits at all of IEnova’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.

If the ongoing litigation to enjoin enforcement or suspend or overturn these newly enacted laws and regulations fails, if the proposed constitutional reform is passed in its current form, or if other amendments to existing laws or regulations are adopted or enacted that curb private-party involvement in the energy sector in Mexico, this could impact our ability to operate our facilities at existing levels or at all, result in increased costs for IEnova and its customers, adversely affect our ability to develop new projects, and 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, financial condition, results of operations, cash flows and/or prospects.

Acquisition of ESJ

As we discuss in Note 5 of the Notes to Condensed Consolidated Financial Statements, in March 2021, IEnova increased its ownership interest in ESJ from 50% to 100% by acquiring Saavi Energía’s 50% equity interest in ESJ. 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. ESJ is constructing a second wind power generation facility with a nameplate capacity of 108 MW that we expect will be completed in the first quarter of 2022.

IEnova Exchange Offer and Cash Tender Offer

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

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in IEnova from 70.2% to 96.4%. In September 2021, we completed a cash tender offer and acquired 51,014,545 publicly owned shares of IEnova for 4.0 billion Mexican pesos (approximately $202 million in U.S. dollars) in cash, which increased our ownership interest in IEnova from 96.4% to 99.9%. We describe these transactions in Note 1 of the Notes to Condensed Consolidated Financial Statements.

In addition to being traded on the New York Stock Exchange, Sempra’s common stock is also listed on the Mexican Stock Exchange under the ticker symbol SRE.MX. 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 remaining publicly owned IEnova shares for 78.97 Mexican pesos per share, the same price per share that was offered in our cash tender offer. The trust will be in place through the earlier of April 14, 2022 or the date on which we acquire all remaining publicly owned IEnova shares.

Sempra LNG

Sempra LNG is pursuing development of additional LNG export facilities on the Gulf Coast and Pacific Coast of North America through its proposed Cameron LNG JV Phase 2 liquefaction expansion project in Louisiana, ECA LNG liquefaction export projects in Mexico, and Port Arthur LNG liquefaction export project in Texas. Sempra LNG will require funding for the development and expansion of its portfolio of projects, which may be financed through a combination of operating cash flows, funding from the parent and minority interest owners, bank financing, project financing, accessing the capital markets and participating in JVs.

Cameron LNG JV Liquefaction Expansion Project (Phase 2)

Cameron LNG JV has received the major permits and FTA and non-FTA approvals necessary to expand the current configuration of the Cameron LNG JV liquefaction project beyond Phase 1. The permits for the Phase 2 project currently include up to two additional liquefaction trains and up to two additional full containment LNG storage tanks. However, Cameron LNG JV plans to file 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. We expect the proposed expansion project will initially have one train with offtake capacity of over 6 Mtpa, with the ability to increase capacity with debottlenecking, and the site can accommodate additional trains beyond Phase 2.

Sempra has entered into MOUs with TOTAL SE, Mitsui & Co., Ltd. and Mitsubishi Corporation that provide a framework for cooperation for the development of and 100% of the offtake from the potential Cameron LNG JV Phase 2 project. The ultimate participation of and offtake by TOTAL SE, Mitsui & Co., Ltd. and Mitsubishi Corporation remains subject to negotiation and finalization of definitive agreements, among other factors, and TOTAL SE, Mitsui & Co., Ltd. and Mitsubishi Corporation have no commitment to participate in or enter into offtake agreements with the Phase 2 project until such definitive agreements are established.

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, timing restrictions on expansion of the project unless appropriate prior consent is obtained from the Phase 1 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. Discussions among all the Cameron LNG JV partners have been taking place regarding how an expansion may be structured, including a facility design utilizing electric drives, and we expect that discussions will continue. Although we are working towards making a final investment decision around the end of 2022, the timing of when or if Cameron LNG JV will receive approval to amend the permits is uncertain, and there is no assurance that the Cameron LNG JV members will unanimously agree in a timely manner or at all on an expansion structure, which, if not accomplished, would materially and adversely impact the development of the Phase 2 project.

The development of the potential 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; securing financing; negotiating and completing suitable commercial agreements, including a definitive EPC contract, 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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ECA LNG Liquefaction Export Projects

Sempra LNG and IEnova are developing two natural gas liquefaction export projects at IEnova’s 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. 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 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. We have planned measures to limit disruption of operations at the ECA Regas Facility with the construction of the ECA LNG Phase 1 project.

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 in development.

In April 2020, ECA LNG Phase 1 executed definitive 20-year LNG sale and purchase agreements with Mitsui & Co., Ltd. for approximately 0.8 Mtpa of LNG and with an affiliate of TOTAL SE for approximately 1.7 Mtpa of LNG. In December 2020, an affiliate of TOTAL SE acquired a 16.6% ownership interest in ECA LNG Phase 1, with Sempra LNG and IEnova each retaining a 41.7% ownership interest. Our MOU with Mitsui & Co., Ltd. provides a framework for Mitsui & Co., Ltd.’s potential offtake of LNG from, and potential acquisition of an equity interest in, ECA LNG Phase 2.

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, we released Technip Energies to commence work 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 $291 million was outstanding at September 30, 2021. 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 Phase 2, 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, an unfavorable judgment that does not allow IEnova to secure new or renew existing LDA authorizations, 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 financial condition, results of operations, cash flows and 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 LNG 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 LNG received authorizations from the DOE in August 2015 and May 2019 that collectively permit the LNG to be produced from the proposed Port Arthur LNG project to be exported to all current and future FTA and non-FTA countries.

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In April 2019, the FERC approved the siting, construction and operation of the proposed Port Arthur LNG liquefaction facility, 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, assuming the project is completed. In February 2020, Sempra LNG filed a FERC application for the siting, construction and operation of a second phase at the proposed Port Arthur LNG facility, including the potential addition of two liquefaction trains.

In February 2020, we entered into an EPC contract with Bechtel for the proposed Port Arthur LNG liquefaction project. The EPC contract contemplates the construction of two liquefaction trains with a nameplate capacity of approximately 13.5 Mtpa, two LNG storage tanks, a marine berth and associated loading facilities and related infrastructure necessary to provide liquefaction services. We have no obligation to move forward on the EPC contract, and we may release Bechtel to perform portions of the work pursuant to limited notices to proceed. We have the option to fully release Bechtel to perform all of the work to construct the Port Arthur LNG liquefaction export project only after we reach a positive final investment decision with respect to the project and after certain other conditions are met, including obtaining project financing. 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. Such amendment may adjust the EPC contract price and the EPC schedule and could potentially include other changes to the work and terms and conditions of the EPC contract prior to Port Arthur LNG having the right to issue a full notice to proceed thereunder. Any agreement on such an amendment by both parties or on favorable terms to Sempra cannot be assured.

In December 2018, Polish Oil & Gas Company (PGNiG) and Port Arthur LNG entered into a definitive 20-year agreement for the sale and purchase of 2 Mtpa of LNG per year from the Port Arthur LNG liquefaction export project. In July 2021, the agreement was terminated and PGNiG and Sempra LNG entered into an MOU to collaborate to transition the 2 Mtpa to Sempra LNG’s portfolio of projects.

In May 2019, Aramco Services Company and Sempra LNG signed a Heads of Agreement for the negotiation of a definitive 20-year LNG sale and purchase agreement for 5 Mtpa of LNG offtake from the Port Arthur LNG liquefaction export project. The Heads of Agreement also included the negotiation of a potential 25% equity investment in the project. In January 2020, Aramco Services Company and Sempra LNG signed an Interim Project Participation Agreement related to the proposed project. In June 2021, Aramco Services Company and Sempra LNG agreed to allow the Heads of Agreement and Interim Project Participation Agreement to expire.

In November 2019, Port Arthur LNG commenced the relocation and upgrade of approximately three miles of highway where the Port Arthur LNG liquefaction export project would be located.

We continue work to progress development of the proposed Port Arthur LNG liquefaction export project and are evaluating design changes that could reduce overall emissions, including electric drives, renewable power sourcing and other technological solutions. Given uncertainties in the energy markets, including real-time developments of new technologies that could impact the design, scale and structure of the project, we continue to evaluate the timing of a final investment decision; however, we will not make a final investment decision in 2021.

Development of the Port Arthur LNG liquefaction export project is subject to a number of risks and uncertainties, including obtaining customer commitments; completing the required commercial agreements, such as equity acquisitions and governance agreements, LNG sales agreements and gas supply and transportation agreements; completing construction contracts; securing and maintaining all necessary permits and approvals; obtaining financing and incentives; 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 financial condition, results of operations and 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.

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)
Nine months ended September 30,	Sempra		SDG&E		SoCalGas
2021	$	2,981	$	1,024	$	1,037
2020	1,629		983		1,388
Change	$	1,352	$	41	$	(351)
Net increase in Reserve for Aliso Canyon Costs primarily due to $1,248 higher accruals and $18 lower payments	$	1,266			$	1,266
Higher dividends received from Cameron LNG JV	287
Net decrease in Insurance Receivable for Aliso Canyon primarily due to $193 lower accruals and $3 higher insurance proceeds received	196				196
Release of a regulatory liability related to 2016-2018 income tax expense forecasting differences in 2020	175		$	86	89
Change in income taxes receivable/payable, net	166		(134)		(170)
Decrease in prepaid insurance	42		39		3
Change in accounts payable	86		(32)		24
Increase in greenhouse gas allowance purchases	(123)				(133)
Change in accounts receivable	(183)		29		(96)
Change in net undercollected regulatory balancing accounts (including long-term amounts in regulatory assets)	(189)		(80)		(109)
Change in net margin posted at Sempra LNG’s marketing operations	(364)
(Lower) higher net income (loss), adjusted for noncash items included in earnings	(1,103)		114		(1,427)
Other	45		19		6
Cash used in discontinued operations in 2020 primarily due to $1,161 income taxes paid related to the sale of our South American businesses	1,051
	$	1,352	$	41	$	(351)

CASH FLOWS FROM INVESTING ACTIVITIES
(Dollars in millions)
Nine months ended September 30,	Sempra		SDG&E		SoCalGas
2021	$	(3,456)	$	(1,553)	$	(1,417)
2020	2,415		(1,315)		(1,345)
Change	$	(5,871)	$	(238)	$	(72)
Distribution from Cameron LNG JV in 2020	$	(753)
Increase in capital expenditures	(293)		$	(237)	$	(72)
Acquisition of 50% interest in ESJ in March 2021 for $79, net of $14 cash and cash equivalents acquired	(65)
Lower contributions to Oncor Holdings	58
Distribution from Oncor Holdings in 2021	361
Other	7		(1)
Cash provided by discontinued operations in 2020 primarily due to $5,781 proceeds, net of transaction costs paid, offset by $502 cash sold from the sale of our South American businesses	(5,186)
	$	(5,871)	$	(238)	$	(72)

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CASH FLOWS FROM FINANCING ACTIVITIES
(Dollars in millions)
Nine months ended September 30,	Sempra		SDG&E		SoCalGas
2021	$	397	$	506	$	602
2020	(710)		1,055		251
Change	$	1,107	$	(549)	$	351
Change in borrowings and repayments of short-term debt, net	$	3,870	$	80	$	517
Lower payments for commercial paper and other short-term debt with maturities greater than 90 days	2,277
Repurchase of common stock under ASR program in 2020	500
Lower repurchases of common stock	26
Lower advances from unconsolidated affiliates	(24)
Higher purchases of NCI	(43)
(Higher) lower common dividends paid	(109)		200		(25)
Higher payments on long-term debt and finance leases	(205)		(354)
Net proceeds from issuance of series C preferred stock in 2020	(890)
(Lower) higher issuances of short-term debt with maturities greater than 90 days	(1,296)		375
Lower issuances of long-term debt	(2,646)		(853)		(949)
Equity contribution from Sempra					800
Other	48		3		8
Cash provided by discontinued operations in 2020 primarily from a $250 intercompany loan and $165 net increase in short term debt	(401)
	$	1,107	$	(549)	$	351

Capital Expenditures, Investments and Acquisitions

EXPENDITURES FOR PP&E, INVESTMENTS AND ACQUISITIONS
(Dollars in millions)
	Nine months ended September 30,
	2021		2020
SDG&E	$	1,560	$	1,323
SoCalGas	1,417		1,345
Sempra Texas Utilities	151		225
Sempra Mexico	325		443
Sempra LNG	362		200
Parent and other	7		6
Total	$	3,822	$	3,542

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 2021, we expect to make capital expenditures and investments of approximately $6.1 billion, an increase from the $5.8 billion projected in “Part II – Item 7. MD&A – Capital Resources and Liquidity” in the Annual Report. The increase is primarily attributable to an increase in expected contributions to our investment in Oncor Holdings and pipeline expansion projects at Sempra Mexico, offset by a delay of capital expenditures related to ECA LNG Phase 1 at Sempra LNG.

COMMITMENTS

We discuss significant changes to contractual commitments in the first nine months of 2021, none of which were outside the ordinary course of our business, in Notes 7 and 11 of the Notes to Condensed Consolidated Financial Statements.

OFF-BALANCE SHEET ARRANGEMENTS

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,

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scheduled to occur in 2039, or replenishment of the amount withdrawn by Sempra LNG from the SDSRA. We discuss this guarantee in Note 6 of the Notes to Condensed Consolidated Financial Statements.

In March 2021, Cameron LNG JV reached financial completion of the three-train liquefaction project and Sempra’s guarantees for a maximum aggregate amount of $4.0 billion were terminated.

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.

Our investments in Oncor Holdings and Cameron LNG JV and our Support Agreement for the benefit of CFIN are variable interests. Sempra’s other businesses may also enter into arrangements that could include variable interests. We discuss variable interests in Note 1 of the Notes to Condensed Consolidated Financial Statements.

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

We view certain accounting policies 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 these accounting policies in “Part II – Item 7. MD&A” in the Annual Report.

We describe our significant accounting policies in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. We follow the same accounting policies for interim reporting purposes.

NEW ACCOUNTING STANDARDS

We discuss the relevant pronouncements that have recently been issued or become effective and have had or may have an impact on our financial statements and/or disclosures in Note 2 of the Notes to Condensed Consolidated Financial Statements.

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

In the first nine months of 2021, there were no significant changes in our exposure to commodity price risk.

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INTEREST RATE RISK

The table below shows the nominal amount of our debt:

NOMINAL AMOUNT OF DEBT(1)
(Dollars in millions)
	September 30, 2021						December 31, 2020
	Sempra		SDG&E		SoCalGas		Sempra		SDG&E		SoCalGas
Short-term:
California Utilities	$	375	$	375	$	—	$	113	$	—	$	113
Other	2,693		—		—		772		—		—
Long-term:
California Utilities fixed-rate	$	10,877	$	6,418	$	4,459	$	10,512	$	6,053	$	4,459
California Utilities variable-rate	300		—		300		500		200		300
Other fixed-rate	10,456		—		—		11,204		—		—
Other variable-rate	339		—		—		51		—		—

(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 September 30, 2021 increased or decreased by 10%, the change in earnings over the 12-month period ending September 30, 2022 would be approximately $1 million. If interest rates increased or decreased by 10% on all variable-rate long-term debt at September 30, 2021, after considering the effects of interest rate swaps, the change in earnings over the 12-month period ending September 30, 2022 would be approximately $1 million.

FOREIGN CURRENCY AND INFLATION RATE RISK

We discuss our foreign currency and inflation exposure 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 September 30, 2021, there were no significant changes to our exposure to foreign currency rate risk since December 31, 2020.

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 September 30, 2021, 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.

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INTERNAL CONTROL OVER FINANCIAL REPORTING

In April 2021, SDG&E implemented a new customer information system to replace its legacy system. The system has been designed and implemented to provide customers an enhanced digital experience and enhance the overall system of internal control over financial reporting through further automation and integration of business processes, including revenue. In connection with the implementation, SDG&E performed pre-implementation planning, design and testing of internal controls that became effective in the second quarter of 2021. SDG&E continues to conduct post-implementation monitoring and process modifications in order to maintain an effective control framework.

In January 2021, IEnova implemented a new enterprise resource planning system (ERP system) to replace its legacy system. The implementation increases user access security and automation of internal controls in certain of IEnova’s business processes, including accounting, back office and financial reporting, which we consider to be material to Sempra. Management has taken steps to help ensure that controls were appropriately designed and implemented in connection with the integration of and transition to the new ERP system. In the third quarter of 2021, IEnova completed its review and enhancement of the design and related documentation of its internal control over financial reporting in connection with its implementation of the new ERP system.

Other than SDG&E’s continued monitoring and modification of its internal controls in connection with its implementation of a new customer information system and IEnova’s completion of its review and enhancement of its internal controls in connection with its implementation of a new ERP system, 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 filed subsequent to this report), including the factors discussed above in “Part I – Item 2. MD&A” and those discussed in “Part I – Item 1A. Risk Factors” in the Annual Report. This section supplements the risk factors described in our Annual Report by replacing with modified and updated information the disclosure that appears under the below heading in the Annual Report in “Part I – Item 1A. Risk Factors – Risks Related to Our Businesses Other Than the California Utilities and Our Interest in Oncor – Foreign Operations Risks – Our international businesses and operations expose us to legal, tax, economic, geopolitical, management oversight, foreign currency and inflation risks and challenges.” Any of the risks and other information discussed in this report or any of the risk factors disclosed in “Part I – Item 1A. Risk Factors” 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 businesses, cash flows, results of operations, financial condition, prospects and/or the trading prices of our securities or those of our subsidiaries.

Mexican Government Influence on Economic and Energy Matters

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The Mexican government has exercised, and continues to exercise, significant and increasing influence over the Mexican economy and energy sector and is proposing additional changes that, in each case, could fundamentally impact private investment in this sector.

With respect to the electricity market, the Mexican legislature is currently considering proposed constitutional reform that would, among other things, make the CFE the only entity allowed to commercialize electric energy in Mexico, thereby eliminating the wholesale electricity market entirely. This reform would also limit the overall capacity and types of plants eligible to generate electricity for the CFE to commercialize, resulting in the cancelation of electricity generation permits and contracts for the sale of electricity to the CFE, including permits at all of IEnova’s operational power generation facilities. Recent Mexican governmental actions in the electricity market also include resolutions, orders, decrees, regulations and proposed amendments to Mexican law that could, among other things, threaten the prospects for private-party renewable energy generation in the country; limit the ability to dispatch renewable energy and receive or maintain operation permits; and increase costs of electricity for legacy renewables and cogeneration energy contract holders.

With respect to midstream and downstream activities, recent governmental actions include amendments in June 2021 to Mexico’s General Foreign Trade Rules designed to limit private parties from obtaining authorizations for the import and export of hydrocarbons, refined products, petrochemicals, and biofuels. IEnova has filed amparo claims to challenge these amendments, which would negatively impact the ability to renew the existing authorizations held by the ECA Regas Facility and the Veracruz terminal and the ability to obtain authorizations for terminals or other projects under construction or in development in the vicinity of Topolobampo, Manzanillo and Ensenada, including the proposed ECA LNG liquefaction projects. In addition, amendments to Mexico’s Hydrocarbons Law that give SENER and the CRE additional powers to suspend and revoke permits were published in May 2021. While the courts have enjoined enforcement of these amendments pending a final disposition, the amendments provide that suspension of permits will be determined by SENER or the CRE when a danger to national security, energy security, or the national economy is foreseen, and also provide new grounds for the revocation of permits under certain circumstances. Additionally, in the case of existing permits, the amendments direct authorities to revoke 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.

Finally, 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 IEnova’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 IEnova’s custody. We are unable to predict when the investigation will be completed and whether the facility will be able to resume normal operations.

We discuss these Mexican governmental actions further in “Part I – Item 2. MD&A – Capital Resources and Liquidity – Sempra Mexico” and Note 11 of the Notes to Condensed Consolidated Financial Statements. We cannot predict whether proposed changes like the constitutional reform to the electricity market or other similar governmental actions will ultimately be passed or otherwise become effective in their current forms, nor can we predict the nature or level of impact of this constitutional reform on non-electric segments of the energy sector. We also cannot predict whether actions to enjoin enforcement or suspend or overturn existing laws and other governmental actions will be successful. More generally, we cannot predict the impact that the political, social, and judicial landscape in Mexico will have on that country’s economy and energy sector and our business in Mexico. If any of the recent Mexican governmental actions are passed or otherwise become effective, if efforts to enjoin their enforcement or suspend or overturn them fail, or if other similar moves by the Mexican government are taken to curb private-party participation in the energy sector, including the passage of additional laws or regulations or increased investigative and enforcement activities, this could materially impact our ability to operate our facilities at existing levels or at all, may result in increased costs for IEnova and its customers, may adversely affect our ability to develop new projects, 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, financial condition, results of operations, cash flows and/or prospects.

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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
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 4 -- INSTRUMENTS DEFINING THE RIGHTS OF SECURITY HOLDERS, INCLUDING INDENTURES
Certain instruments defining the rights of holders of long-term debt instruments are not required to be filed or incorporated by reference herein pursuant to Item 601(b)(4)(iii)(A) of Regulation S-K. Each registrant agrees to furnish a copy of such instruments to the SEC upon request.
Sempra Energy / San Diego Gas & Electric Company
4.1	Seventy-First Supplemental Indenture, dated as of August 13, 2021.		8-K	4.1	08/13/21
EXHIBIT 10 -- MATERIAL CONTRACTS
10.1	Master Agreement to Resolve JCCP No. 4861 Private Party Claims, effective September 26, 2021, by and among Sempra Energy, Southern California Gas Company, and the plaintiff’s law firms listed on the signature pages thereto.		8-K	10.1	09/27/21

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EXHIBIT INDEX (CONTINUED)
Exhibit Number	Exhibit Description	Filed or Furnished Herewith
EXHIBIT 31 -- SECTION 302 CERTIFICATIONS
Sempra
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
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

126

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).

127

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: November 5, 2021	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: November 5, 2021	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: November 5, 2021	By: /s/ Mia L. DeMontigny
	Mia L. DeMontigny
	Chief Financial Officer, Controller and Chief Accounting Officer (Duly Authorized Officer)

128

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.

November 5, 2021	/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.

November 5, 2021	/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.

November 5, 2021	/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.

November 5, 2021	/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.

November 5, 2021	/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.

November 5, 2021	/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 September 30, 2021 (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.

November 5, 2021	/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 September 30, 2021 (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.

November 5, 2021	/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 September 30, 2021 (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.

November 5, 2021	/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 September 30, 2021 (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.

November 5, 2021	/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 September 30, 2021 (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.

November 5, 2021	/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 September 30, 2021 (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.

November 5, 2021	/s/ Mia L. DeMontigny
	Mia L. DeMontigny
	Chief Financial Officer

XML

COVER - shares	9 Months Ended
	Sep. 30, 2021	Nov. 01, 2021
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2021
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		319,337,462
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0001032208
San Diego Gas and Electric Company [Member]
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 [Member]
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 [Member]
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 [Member]
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

XML

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
REVENUES
Utilities operating revenue	$ 2,560	$ 2,301	$ 7,839	$ 7,199
Energy-related businesses	453	343	1,174	1,000
Total revenues	3,013	2,644	9,013	8,199
Operating expenses
Operation and maintenance	(1,073)	(1,018)	(3,098)	(2,767)
Aliso Canyon litigation and regulatory matters	(1,571)	(27)	(1,571)	(127)
Depreciation and amortization	(471)	(418)	(1,376)	(1,242)
Franchise fees and other taxes	(151)	(139)	(442)	(397)
Operating expenses
Aliso Canyon litigation and regulatory matters	1,571	27	1,571	127
Other (expense) income, net	(55)	29	52	(163)
Interest income	16	27	50	76
Interest expense	(259)	(264)	(776)	(818)
(Loss) income from continuing operations before income taxes and equity earnings	(1,365)	201	(316)	1,061
Income tax benefit (expense)	342	(99)	45	(60)
Equity earnings	391	326	1,022	822
(Loss) income from continuing operations, net of income tax	(632)	428	751	1,823
(Loss) income from discontinued operations, net of income tax	0	(7)	0	1,850
Net (loss) income	(632)	421	751	3,673
Earnings attributable to noncontrolling interests	(5)	(22)	(48)	(201)
Preferred dividends	(11)	(48)	(52)	(121)
Preferred dividends of subsidiary	0	0	(1)	(1)
(Losses) earnings attributable to common shares	$ (648)	$ 351	$ 650	$ 3,350
Basic EPS:
(Losses) earnings from continuing operations (in dollars per share)	$ (2.03)	$ 1.23	$ 2.10	$ 5.17
(Losses) earnings from discontinued operations (in dollars per share)	0	(0.02)	0	6.31
(Losses) earnings (in dollars per share)	$ (2.03)	$ 1.21	$ 2.10	$ 11.48
Weighted-average common shares outstanding	319,144	289,490	309,350	291,771
Diluted EPS:
(Losses) earnings from continuing operations (in dollars per share)	$ (2.03)	$ 1.23	$ 2.09	$ 5.15
(Losses) earnings from discontinued operations (in dollars per share)	0	(0.02)	0	6.28
(Losses) earnings from continuing operations attributable to common shares (in dollars per share)	$ (2.03)	$ 1.21	$ 2.09	$ 11.43
Weighted-average common shares outstanding, diluted (in shares)	319,144	290,582	310,854	292,935
Natural gas [Member]
Operating expenses
Operating expenses	$ (282)	$ (114)	$ (892)	$ (582)
Electric fuel and purchased power [Member]
Operating expenses
Operating expenses	(312)	(429)	(828)	(918)
Energy-related businesses [Member]
Operating expenses
Operating expenses	(220)	(90)	(448)	(200)
San Diego Gas and Electric Company [Member]
REVENUES
Electric	1,307	1,338	3,534	3,478
Natural gas	157	134	585	498
Utilities operating revenue	1,464	1,472	4,119	3,976
Operating expenses
Cost of electric fuel and purchased power	324	430	869	921
Cost of natural gas	37	27	159	118
Operation and maintenance	389	414	1,152	1,050
Depreciation and amortization	226	200	659	598
Franchise fees and other taxes	93	86	264	237
Total operating expenses	1,069	1,157	3,103	2,924
Operating income	395	315	1,016	1,052
Other (expense) income, net	4	(2)	61	47
Interest income	0	1	1	2
Interest expense	(104)	(103)	(307)	(307)
(Loss) income from continuing operations before income taxes and equity earnings	295	211	771	794
Income tax benefit (expense)	(90)	(33)	(168)	(161)
Net (loss) income			603	633
(Losses) earnings attributable to common shares	205	178	603	633
Southern California Gas Company [Member]
REVENUES
Utilities operating revenue	1,106	842	3,738	3,247
Operating expenses
Aliso Canyon litigation and regulatory matters	(1,571)	(27)	(1,571)	(127)
Operating expenses
Cost of natural gas	240	92	736	476
Operation and maintenance	546	494	1,574	1,399
Aliso Canyon litigation and regulatory matters	1,571	27	1,571	127
Depreciation and amortization	180	165	533	486
Franchise fees and other taxes	54	48	163	142
Total operating expenses	2,591	826	4,577	2,630
Operating income	(1,485)	16	(839)	617
Other (expense) income, net	(39)	(7)	(2)	21
Interest income	0	0	0	2
Interest expense	(39)	(39)	(118)	(119)
(Loss) income from continuing operations before income taxes and equity earnings	(1,563)	(30)	(959)	521
Income tax benefit (expense)	437	6	335	(95)
Net (loss) income	(1,126)	(24)	(624)	426
Preferred dividends	0	0	(1)	(1)
(Losses) earnings attributable to common shares	$ (1,126)	$ (24)	$ (625)	$ 425

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Net (loss) income	$ (632)	$ 421	$ 751	$ 3,673
Other comprehensive income (loss):
Foreign currency translation adjustments	(6)	8	(6)	517
Financial instruments	29	25	118	(135)
Pension and other postretirement benefits	(5)	5	9	24
Total other comprehensive (loss) income	18	38	121	406
Comprehensive (loss) income	(614)	459	872	4,079
Preferred dividends of subsidiary			(1)	(1)
Comprehensive (loss) income, after preferred dividends of subsidiary			871	4,078
Pretax amount [Member]
Net (loss) income	(979)	489	658	4,718
Other comprehensive income (loss):
Foreign currency translation adjustments	(4)	9	(4)	533
Financial instruments	38	36	145	(167)
Pension and other postretirement benefits	(7)	6	11	27
Total other comprehensive (loss) income	27	51	152	393
Comprehensive (loss) income	(952)	540	810	5,111
Preferred dividends of subsidiary			(1)	(1)
Comprehensive (loss) income, after preferred dividends of subsidiary			809	5,110
Income tax (expense) benefit [Member]
Net (loss) income	342	(90)	45	(1,246)
Other comprehensive income (loss):
Foreign currency translation adjustments	0	0	0	0
Financial instruments	(9)	(16)	(36)	41
Pension and other postretirement benefits	2	(1)	(2)	(3)
Total other comprehensive (loss) income	(7)	(17)	(38)	38
Comprehensive (loss) income	335	(107)	7	(1,208)
Preferred dividends of subsidiary			0	0
Comprehensive (loss) income, after preferred dividends of subsidiary			7	(1,208)
Net-of-tax amount [Member]
Net (loss) income	(637)	399	703	3,472
Other comprehensive income (loss):
Foreign currency translation adjustments	(4)	9	(4)	533
Financial instruments	29	20	109	(126)
Pension and other postretirement benefits	(5)	5	9	24
Total other comprehensive (loss) income	20	34	114	431
Comprehensive (loss) income	(617)	433	817	3,903
Preferred dividends of subsidiary			(1)	(1)
Comprehensive (loss) income, after preferred dividends of subsidiary			816	3,902
Noncontrolling Interests (after-tax) [Member]
Net (loss) income	5	22	48	201
Other comprehensive income (loss):
Foreign currency translation adjustments	(2)	(1)	(2)	(16)
Financial instruments	0	5	9	(9)
Pension and other postretirement benefits	0	0	0	0
Total other comprehensive (loss) income	(2)	4	7	(25)
Comprehensive (loss) income	3	26	55	176
Preferred dividends of subsidiary			0	0
Comprehensive (loss) income, after preferred dividends of subsidiary			55	176
San Diego Gas and Electric Company [Member]
Net (loss) income			603	633
San Diego Gas and Electric Company [Member] | Pretax amount [Member]
Net (loss) income	295	211	771	794
Other comprehensive income (loss):
Pension and other postretirement benefits	1		1	5
Total other comprehensive (loss) income	1		1	5
Comprehensive (loss) income, after preferred dividends of subsidiary	296	211	772	799
San Diego Gas and Electric Company [Member] | Income tax (expense) benefit [Member]
Net (loss) income	(90)	(33)	(168)	(161)
Other comprehensive income (loss):
Pension and other postretirement benefits	0		0	(1)
Total other comprehensive (loss) income	0		0	(1)
Comprehensive (loss) income, after preferred dividends of subsidiary	(90)	(33)	(168)	(162)
San Diego Gas and Electric Company [Member] | Net-of-tax amount [Member]
Net (loss) income	205	178	603	633
Other comprehensive income (loss):
Pension and other postretirement benefits	1		1	4
Total other comprehensive (loss) income	1		1	4
Comprehensive (loss) income, after preferred dividends of subsidiary	206	178	604	637
Southern California Gas Company [Member]
Net (loss) income	(1,126)	(24)	(624)	426
Other comprehensive income (loss):
Total other comprehensive (loss) income	1		2	1
Southern California Gas Company [Member] | Pretax amount [Member]
Net (loss) income	(1,563)	(30)	(959)	521
Other comprehensive income (loss):
Pension and other postretirement benefits	1		2	1
Total other comprehensive (loss) income	1		2	1
Comprehensive (loss) income, after preferred dividends of subsidiary	(1,562)	(30)	(957)	522
Southern California Gas Company [Member] | Income tax (expense) benefit [Member]
Net (loss) income	437	6	335	(95)
Other comprehensive income (loss):
Pension and other postretirement benefits	0		0	0
Total other comprehensive (loss) income	0		0	0
Comprehensive (loss) income, after preferred dividends of subsidiary	437	6	335	(95)
Southern California Gas Company [Member] | Net-of-tax amount [Member]
Net (loss) income	(1,126)	(24)	(624)	426
Other comprehensive income (loss):
Pension and other postretirement benefits	1		2	1
Total other comprehensive (loss) income	1		2	1
Comprehensive (loss) income, after preferred dividends of subsidiary	$ (1,125)	$ (24)	$ (622)	$ 427

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CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Current assets:
Cash and cash equivalents	$ 873	$ 960	[1]
Restricted cash	31	22	[1]
Accounts receivable – trade, net	1,416	1,578	[1]
Accounts receivable – other, net	470	403	[1]
Due from unconsolidated affiliates	30	20	[1]
Income taxes receivable	93	113	[1]
Inventories	371	308	[1]
Regulatory assets	290	190	[1]
Greenhouse gas allowances	546	553	[1]
Other current assets	473	364	[1]
Total current assets	4,593	4,511	[1]
Other assets:
Restricted cash	3	3	[1]
Due from unconsolidated affiliates	684	780	[1]
Regulatory assets	2,280	1,822	[1]
Nuclear decommissioning trusts	1,003	1,019	[1]
Investment in Oncor Holdings	12,475	12,440	[1]
Other investments	1,483	1,388	[1]
Goodwill	1,602	1,602	[1]
Other intangible assets	376	202	[1]
Dedicated assets in support of certain benefit plans	539	512	[1]
Insurance receivable for Aliso Canyon costs	414	445	[1]
Deferred income taxes	151	136	[1]
Greenhouse gas allowances	356	101	[1]
Right-of-use assets – operating leases	499	543	[1]
Wildfire fund	342	363	[1]
Other long-term assets	914	753	[1]
Total other assets	23,121	22,109	[1]
Property, plant and equipment:
Property, plant and equipment	57,474	53,928	[1]
Less accumulated depreciation and amortization	(14,716)	(13,925)	[1]
Property, plant and equipment, net	42,758	40,003	[1]
Total assets	70,472	66,623	[1]
Current liabilities:
Short-term debt	3,068	885	[1]
Accounts payable – trade	1,400	1,359	[1]
Accounts payable – other	179	154	[1]
Due to unconsolidated affiliates	42	45	[1]
Dividends and interest payable	592	551	[1]
Accrued compensation and benefits	454	446	[1]
Regulatory liabilities	515	140	[1]
Current portion of long-term debt and finance leases	2,994	1,540	[1]
Reserve for Aliso Canyon costs	1,962	150	[1]
Greenhouse gas obligations	546	553	[1]
Other current liabilities	1,192	1,016	[1]
Total current liabilities	12,944	6,839	[1]
Long-term debt and finance leases	20,042	21,781	[1]
Deferred credits and other liabilities:
Due to unconsolidated affiliates	286	234	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	964	1,059	[1]
Deferred income taxes	2,882	2,871	[1]
Regulatory liabilities	3,378	3,372	[1]
Reserve for Aliso Canyon costs	14	301	[1]
Greenhouse gas obligations	190	0	[1]
Asset retirement obligations	3,187	3,113	[1]
Deferred credits and other	1,981	2,119	[1]
Total deferred credits and other liabilities	12,882	13,069	[1]
Commitments and contingencies (Note 11)			[1]
Equity:
Common stock	10,791	7,053	[1]
Retained earnings	13,292	13,673	[1]
Accumulated other comprehensive income (loss)	(418)	(500)	[1]
Total shareholders’ equity	24,554	23,373	[1]
Preferred stock of subsidiary	20	20	[1]
Other noncontrolling interests	30	1,541	[1]
Total equity	24,604	24,934	[1]
Total liabilities and equity	70,472	66,623	[1]
San Diego Gas and Electric Company [Member]
Current assets:
Cash and cash equivalents	239	262	[1]
Accounts receivable – trade, net	642	573	[1]
Accounts receivable – other, net	96	143	[1]
Due from unconsolidated affiliates	1	0
Income taxes receivable	18	0	[1]
Inventories	112	104	[1]
Prepaid expenses	197	153	[1]
Regulatory assets	253	174	[1]
Fixed-price contracts and other derivatives	73	56	[1]
Greenhouse gas allowances	113	113	[1]
Other current assets	4	22	[1]
Total current assets	1,748	1,600	[1]
Other assets:
Regulatory assets	751	534	[1]
Nuclear decommissioning trusts	1,003	1,019	[1]
Greenhouse gas allowances	83	83	[1]
Right-of-use assets – operating leases	82	102	[1]
Wildfire fund	342	363	[1]
Other long-term assets	213	189	[1]
Total other assets	2,474	2,290	[1]
Property, plant and equipment:
Property, plant and equipment	25,824	24,436	[1]
Less accumulated depreciation and amortization	(6,263)	(6,015)	[1]
Property, plant and equipment, net	19,561	18,421	[1]
Total assets	23,783	22,311	[1]
Current liabilities:
Short-term debt	375	0	[1]
Accounts payable	602	553	[1]
Due to unconsolidated affiliates	61	64	[1]
Interest payable	74	46	[1]
Accrued compensation and benefits	138	135	[1]
Accrued franchise fees	59	56	[1]
Regulatory liabilities	53	61	[1]
Current portion of long-term debt and finance leases	48	611	[1]
Customer deposits	33	56	[1]
Greenhouse gas obligations	113	113	[1]
Asset retirement obligations	130	117	[1]
Other current liabilities	233	199	[1]
Total current liabilities	1,919	2,011	[1]
Long-term debt and finance leases	7,587	6,866	[1]
Deferred credits and other liabilities:
Pension and other postretirement benefit plan obligations, net of plan assets	61	92	[1]
Deferred income taxes	2,203	2,019	[1]
Deferred investment tax credits	13	13	[1]
Regulatory liabilities	2,311	2,195	[1]
Greenhouse gas obligations	30	0	[1]
Asset retirement obligations	744	759	[1]
Deferred credits and other	581	626	[1]
Total deferred credits and other liabilities	5,943	5,704	[1]
Commitments and contingencies (Note 11)			[1]
Equity:
Preferred stock	0	0	[1]
Common stock	1,660	1,660	[1]
Retained earnings	6,683	6,080	[1]
Accumulated other comprehensive income (loss)	(9)	(10)	[1]
Total shareholders’ equity	8,334	7,730	[1]
Total liabilities and equity	23,783	22,311	[1]
Southern California Gas Company [Member]
Current assets:
Cash and cash equivalents	226	4	[1]
Accounts receivable – trade, net	462	786	[1]
Accounts receivable – other, net	86	64	[1]
Due from unconsolidated affiliates	11	22	[1]
Income taxes receivable	16	0
Inventories	168	153	[1]
Regulatory assets	37	16	[1]
Greenhouse gas allowances	384	390	[1]
Other current assets	62	47	[1]
Total current assets	1,452	1,482	[1]
Other assets:
Regulatory assets	1,449	1,208	[1]
Insurance receivable for Aliso Canyon costs	414	445	[1]
Greenhouse gas allowances	262	9	[1]
Right-of-use assets – operating leases	61	74	[1]
Other long-term assets	575	499	[1]
Total other assets	2,761	2,235	[1]
Property, plant and equipment:
Property, plant and equipment	22,445	21,180	[1]
Less accumulated depreciation and amortization	(6,739)	(6,437)	[1]
Property, plant and equipment, net	15,706	14,743	[1]
Total assets	19,919	18,460	[1]
Current liabilities:
Short-term debt	0	113	[2]
Accounts payable – trade	488	600	[2]
Accounts payable – other	133	122	[2]
Due to unconsolidated affiliates	45	31	[2]
Accrued compensation and benefits	203	189	[2]
Regulatory liabilities	462	79	[2]
Current portion of long-term debt and finance leases	10	10	[2]
Customer deposits	15	48
Reserve for Aliso Canyon costs	1,962	150	[2]
Greenhouse gas obligations	384	390	[2]
Asset retirement obligations	58	59	[2]
Other current liabilities	310	291	[2]
Total current liabilities	4,070	2,082	[2]
Long-term debt and finance leases	4,769	4,763	[2]
Deferred credits and other liabilities:
Pension and other postretirement benefit plan obligations, net of plan assets	784	853	[2]
Deferred income taxes	1,032	1,406	[2]
Deferred investment tax credits	7	8	[2]
Regulatory liabilities	1,067	1,177	[2]
Reserve for Aliso Canyon costs	14	301	[2]
Greenhouse gas obligations	140	0	[2]
Asset retirement obligations	2,377	2,309	[2]
Deferred credits and other	413	417	[1]
Total deferred credits and other liabilities	5,834	6,471	[1]
Commitments and contingencies (Note 11)			[2]
Equity:
Preferred stock	22	22	[2]
Common stock	1,666	866	[2]
Retained earnings	3,587	4,287	[2]
Accumulated other comprehensive income (loss)	(29)	(31)	[2]
Total shareholders’ equity	5,246	5,144	[1]
Total equity	5,246	5,144
Total liabilities and equity	19,919	18,460	[2]
Convertible Preferred Stock Series A [Member]
Equity:
Preferred stock	0	1,693	[1]
Convertible Preferred Stock Series B [Member]
Equity:
Preferred stock	0	565	[1]
Series C Preferred Stock [Member]
Equity:
Preferred stock	$ 889	$ 889	[1]

[1] Derived from audited financial statements.

[2] Derived from audited financial statements.

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CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - shares	Sep. 30, 2021	Dec. 31, 2020
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)	319,000,000	288,000,000
San Diego Gas and Electric Company [Member]
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
Southern California Gas Company [Member]
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
Convertible Preferred Stock Series A [Member]
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares outstanding (in shares)		17,250,000
Convertible Preferred Stock Series B [Member]
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares outstanding (in shares)		5,750,000
Series C Preferred Stock [Member]
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	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income	$ 751	$ 3,673
Less: Income from discontinued operations, net of income tax	0	(1,850)
(Loss) income from continuing operations, net of income tax	751	1,823
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,376	1,242
Deferred income taxes and investment tax credits	(159)	(12)
Equity earnings	(1,022)	(822)
Foreign currency transaction losses, net	10	95
Share-based compensation expense	48	57
Fixed-price contracts and other derivatives	338	25
Other	70	107
Reserve for Aliso Canyon costs	1,525	259
Net change in other working capital components	(186)	(396)
Distributions from investments	727	429
Insurance receivable for Aliso Canyon costs	31	(165)
Changes in other noncurrent assets and liabilities, net	(528)	38
Net cash provided by continuing operations	2,981	2,680
Net cash used in discontinued operations	0	(1,051)
Net cash provided by operating activities	2,981	1,629
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(3,606)	(3,313)
Expenditures for investments and acquisitions	(216)	(229)
Proceeds from sale of assets	0	22
Distributions from investments	365	761
Purchases of nuclear decommissioning trust assets	(729)	(1,091)
Proceeds from sales of nuclear decommissioning trust assets	729	1,091
Advances to unconsolidated affiliates	(8)	(32)
Repayments of advances to unconsolidated affiliates	0	7
Other	9	13
Net cash used in continuing operations	(3,456)	(2,771)
Net cash provided by discontinued operations	0	5,186
Net cash (used in) provided by investing activities	(3,456)	2,415
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(981)	(872)
Preferred dividends paid	(77)	(107)
Issuances of preferred stock	0	890
Issuances of common stock	5	10
Repurchases of common stock	(39)	(565)
Issuances of debt (maturities greater than 90 days)	1,992	5,934
Payments on debt (maturities greater than 90 days) and finance leases	(2,315)	(4,387)
Increase (decrease) in short-term, debt, net	1,999	(1,871)
Advances from unconsolidated affiliates	40	64
Proceeds from sales of noncontrolling interests	7	0
Purchases of noncontrolling interests	(221)	(178)
Other	(13)	(29)
Net cash provided by (used in) continuing operations	397	(1,111)
Net cash provided by discontinued operations	0	401
Net cash provided by (used in) financing activities	397	(710)
Effect of exchange rate changes in continuing operations	0	(2)
Effect of exchange rate changes in discontinued operations	0	(3)
Effect of exchange rate changes on cash, cash equivalents and restricted cash	0	(5)
(Decrease) increase in cash, cash equivalents and restricted cash, including discontinued operations	(78)	3,329
Cash, cash equivalents and restricted cash, including discontinued operations, January 1	985	217
Cash, cash equivalents and restricted cash, including discontinued operations, September 30	907	3,546
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	741	781
Income tax payments, including discontinued operations, net of refunds	101	1,376
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Increase in Cameron LNG JV investment for guarantee	22	0
Accrued capital expenditures	572	460
Increase in ARO for investment in PP&E	33	0
Increase in finance lease obligations for investment in PP&E	35	72
Derecognized PP&E for net investment in sales-type lease	44	0
Issuance of common stock in exchange for NCI and related AOCI	1,373	0
Contribution to Cameron LNG JV	0	50
Distribution from Cameron LNG JV	0	50
Distribution from Oncor Holdings	8	0
Equitization of long-term debt for deficit held by NCI	0	22
Conversion of mandatory convertible preferred stock	2,258	0
Common dividends issued in stock	0	23
Preferred stock [Member]
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends declared but not paid	22	50
Common Stock [Member]
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends declared but not paid	351	301
San Diego Gas and Electric Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income	603	633
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	659	598
Deferred income taxes and investment tax credits	133	36
Other	(1)	13
Net change in other working capital components	(187)	(184)
Changes in other noncurrent assets and liabilities, net	(183)	(113)
Net cash provided by operating activities	1,024	983
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,560)	(1,323)
Purchases of nuclear decommissioning trust assets	(729)	(1,091)
Proceeds from sales of nuclear decommissioning trust assets	729	1,091
Other	7	8
Net cash (used in) provided by investing activities	(1,553)	(1,315)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	0	(200)
Issuances of debt (maturities greater than 90 days)	1,120	1,598
Payments on debt (maturities greater than 90 days) and finance leases	(606)	(252)
Increase (decrease) in short-term, debt, net	0	(80)
Debt issuance costs	(8)	(11)
Net cash provided by (used in) financing activities	506	1,055
(Decrease) increase in cash, cash equivalents and restricted cash, including discontinued operations	(23)	723
Cash, cash equivalents and restricted cash, including discontinued operations, January 1	262	10
Cash, cash equivalents and restricted cash, including discontinued operations, September 30	239	733
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	275	276
Income tax payments, including discontinued operations, net of refunds	64	20
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	217	184
Increase in ARO for investment in PP&E	18	0
Increase in finance lease obligations for investment in PP&E	23	26
Southern California Gas Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income	(624)	426
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	533	486
Deferred income taxes and investment tax credits	(467)	(38)
Other	47	42
Reserve for Aliso Canyon costs	1,525	259
Net change in other working capital components	385	254
Insurance receivable for Aliso Canyon costs	31	(165)
Changes in other noncurrent assets and liabilities, net	(393)	124
Net cash provided by operating activities	1,037	1,388
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,417)	(1,345)
Net cash (used in) provided by investing activities	(1,417)	(1,345)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(75)	(50)
Preferred dividends paid	(1)	(1)
Equity contribution from Sempra Energy	800	0
Issuances of debt (maturities greater than 90 days)	0	949
Payments on finance leases	(9)	(9)
Increase (decrease) in short-term, debt, net	(113)	(630)
Debt issuance costs	0	(8)
Net cash provided by (used in) financing activities	602	251
(Decrease) increase in cash, cash equivalents and restricted cash, including discontinued operations	222	294
Cash, cash equivalents and restricted cash, including discontinued operations, January 1	4	10
Cash, cash equivalents and restricted cash, including discontinued operations, September 30	226	304
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	119	114
Income tax payments, including discontinued operations, net of refunds	170	1
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	205	146
Increase in finance lease obligations for investment in PP&E	12	46
Dividends declared but not paid	$ 0	$ 50

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CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total		Series A Preferred Stock [Member]	Series B Preferred Stock [Member]	Series C Preferred Stock [Member]	Preferred stock [Member]	Preferred stock [Member] Series A Preferred Stock [Member]	Preferred stock [Member] Series B Preferred Stock [Member]	Preferred stock [Member] Series C Preferred Stock [Member]	Common Stock [Member]	Common Stock [Member] Series A Preferred Stock [Member]	Common Stock [Member] Series B Preferred Stock [Member]	Retained earnings [Member]	Retained earnings [Member] Series A Preferred Stock [Member]	Retained earnings [Member] Series B Preferred Stock [Member]	Retained earnings [Member] Series C Preferred Stock [Member]	Accumulated other comprehensive income (loss) [Member]	Shareholders' equity [Member]	Shareholders' equity [Member] Series A Preferred Stock [Member]	Shareholders' equity [Member] Series B Preferred Stock [Member]	Shareholders' equity [Member] Series C Preferred Stock [Member]	Noncontrolling Interest [Member]	San Diego Gas and Electric Company [Member]	San Diego Gas and Electric Company [Member] Common Stock [Member]	San Diego Gas and Electric Company [Member] Retained earnings [Member]	San Diego Gas and Electric Company [Member] Accumulated other comprehensive income (loss) [Member]	San Diego Gas and Electric Company [Member] Shareholders' equity [Member]	Southern California Gas Company [Member]	Southern California Gas Company [Member] Preferred stock [Member]	Southern California Gas Company [Member] Common Stock [Member]	Southern California Gas Company [Member] Retained earnings [Member]	Southern California Gas Company [Member] Accumulated other comprehensive income (loss) [Member]	Cumulative Effect, Period of Adoption, Adjustment [Member]	Cumulative Effect, Period of Adoption, Adjustment [Member] Retained earnings [Member]	Cumulative Effect, Period of Adoption, Adjustment [Member] Shareholders' equity [Member]	Cumulative Effect, Period of Adoption, Adjustment [Member] Noncontrolling Interest [Member]	Cumulative Effect, Period of Adoption, Adjusted Balance [Member]	Cumulative Effect, Period of Adoption, Adjusted Balance [Member] Preferred stock [Member]	Cumulative Effect, Period of Adoption, Adjusted Balance [Member] Common Stock [Member]	Cumulative Effect, Period of Adoption, Adjusted Balance [Member] Retained earnings [Member]	Cumulative Effect, Period of Adoption, Adjusted Balance [Member] Accumulated other comprehensive income (loss) [Member]	Cumulative Effect, Period of Adoption, Adjusted Balance [Member] Shareholders' equity [Member]	Cumulative Effect, Period of Adoption, Adjusted Balance [Member] Noncontrolling Interest [Member]
Beginning Balance at Dec. 31, 2019	$ 21,805					$ 2,258				$ 7,480			$ 11,130				$ (939)	$ 19,929				$ 1,876		$ 1,660	$ 5,456	$ (16)	$ 7,100	$ 4,748	$ 22	$ 866	$ 3,883	$ (23)	$ (9)	$ (7)	$ (7)	$ (2)	$ 21,796	$ 2,258	$ 7,480	$ 11,123	$ (939)	$ 19,922	$ 1,874
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	3,673												3,472					3,472				201	$ 633		633		633	426			426
Other comprehensive (loss) income	406																431	431				(25)				4	4	1				1
Share-based compensation expense	57									57								57
Dividends declared:
Preferred dividends			$ (78)	$ (29)	$ (14)									$ (78)	$ (29)	$ (14)			$ (78)	$ (29)	$ (14)							(1)			(1)
Common stock dividends declared	(913)												(913)					(913)							(200)		(200)	(100)			(100)
Preferred dividends of subsidiary	(1)												(1)					(1)
Issuances of stock	33				889				$ 889	33								33			889
Repurchases of common stock	(565)									(565)								(565)
Noncontrolling interest activities:
Purchases	(184)									29							(5)	24				(208)
Distributions	(1)																					(1)
Acquisition	1																					1
Equitization of long-term debt for deficit held by NCI	22																					22
Deconsolidation	(236)																					(236)
Ending balance at Sep. 30, 2020	24,856					3,147				7,034			13,560				(513)	23,228				1,628		1,660	5,889	(12)	7,537	5,074	22	866	4,208	(22)
Beginning Balance at Jun. 30, 2020	25,386					3,147				7,490			13,511				(542)	23,606				1,780		1,660	5,711	(12)	7,359	5,148	22	866	4,282	(22)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	421												399					399				22			178		178	(24)			(24)
Other comprehensive (loss) income	38																34	34				4
Share-based compensation expense	19									19								19
Dividends declared:
Preferred dividends			(26)	(10)	(12)									$ (26)	(10)	(12)			(26)	(10)	(12)							0			0
Common stock dividends declared	(302)												(302)					(302)										(50)			(50)
Repurchases of common stock	(501)									(501)								(501)
Noncontrolling interest activities:
Purchases	(157)									26							(5)	21				(178)
Ending balance at Sep. 30, 2020	24,856					3,147				7,034			13,560				(513)	23,228				1,628		1,660	5,889	(12)	7,537	5,074	22	866	4,208	(22)
Beginning Balance at Dec. 31, 2020	24,934	[1]				3,147				7,053			13,673				(500)	23,373				1,561		1,660	6,080	(10)	7,730	5,144	22	866	4,287	(31)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	751												703					703				48	$ 603		603		603	(624)			(624)
Other comprehensive (loss) income	121																114	114				7				1	1	2				2
Share-based compensation expense	48									48								48
Equity contribution from Sempra Energy																												800		800
Dividends declared:
Preferred dividends				(19)	(33)										$ (19)	(33)				$ (19)	(33)							(1)			(1)
Common stock dividends declared	(1,031)												(1,031)					(1,031)										(75)			(75)
Conversion of stock			$ 0	0			$ (1,693)	$ (565)			$ 1,693	$ 565							$ 0
Preferred dividends of subsidiary	(1)												(1)					(1)
Issuances of stock	5									5								5
Repurchases of common stock	(39)									(39)								(39)
Noncontrolling interest activities:
Purchases	(137)									1,462							(32)	1,430				(1,567)
Sale	5									4								4				1
Ending balance at Sep. 30, 2021	24,604					889				10,791			13,292				(418)	24,554				50		1,660	6,683	(9)	8,334	5,246	22	1,666	3,587	(29)
Beginning Balance at Jun. 30, 2021	25,692					1,454				10,150			14,291				(444)	25,451				241		1,660	6,478	(10)	8,128	5,571	22	866	4,713	(30)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(632)												(637)					(637)				5			205		205	(1,126)			(1,126)
Other comprehensive (loss) income	18																20	20				(2)				1	1	1				1
Share-based compensation expense	14									14								14
Equity contribution from Sempra Energy																												800		800
Dividends declared:
Preferred dividends					$ (11)											$ (11)					$ (11)							0			0
Common stock dividends declared	(351)												(351)					(351)
Conversion of stock				$ 0				$ (565)				$ 565
Repurchases of common stock	(1)									(1)								(1)
Noncontrolling interest activities:
Purchases	(125)									63							6	69				(194)
Ending balance at Sep. 30, 2021	$ 24,604					$ 889				$ 10,791			$ 13,292				$ (418)	$ 24,554				$ 50		$ 1,660	$ 6,683	$ (9)	$ 8,334	$ 5,246	$ 22	$ 1,666	$ 3,587	$ (29)

[1] Derived from audited financial statements.

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CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Dividends declared per share of common stock (in dollars per share)	$ 1.10	$ 1.05	$ 3.30	$ 3.14
San Diego Gas and Electric Company [Member]
Dividends declared per share of common stock (in dollars per share)				1.72
Southern California Gas Company [Member]
Dividends declared per share of preferred stock (in dollars per share)	0.38	0.38	1.13	1.13
Dividends declared per share of common stock (in dollars per share)		0.55	0.82	1.10
Series A Preferred Stock [Member]
Dividends declared per share of preferred stock (in dollars per share)		1.50		4.50
Series B Preferred Stock [Member]
Dividends declared per share of preferred stock (in dollars per share)		1.68	3.38	5.06
Series C Preferred Stock [Member]
Dividends declared per share of preferred stock (in dollars per share)	$ 12.19	$ 14.08	$ 36.57	$ 15.71

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GENERAL INFORMATION AND OTHER FINANCIAL DATA

9 Months Ended

Sep. 30, 2021

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. Sempra’s business activities are organized under five 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. References in this report to “we,” “our,” “us” and “Sempra” are to Sempra and its consolidated entities, collectively, unless otherwise stated or indicated by the context. We refer to SDG&E and SoCalGas collectively as the California Utilities. Sempra Infrastructure Partners (formerly Sempra Global) is the holding company for our subsidiaries that are not subject to California or Texas utility regulation. We have eliminated intercompany accounts and transactions within the consolidated financial statements of each reporting entity.

Throughout these Notes, 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.

We have prepared our Condensed Consolidated Financial Statements in conformity with U.S. GAAP and in accordance with the interim-period-reporting requirements of Form 10-Q and applicable rules of the SEC. The financial statements reflect all adjustments that are necessary for a fair presentation of the results for the interim periods. These adjustments are only of a normal, recurring nature. Results of operations for interim periods are not necessarily indicative of results for the entire year or for any other period. We evaluated events and transactions that occurred after September 30, 2021 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, 2020 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2020 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.

You should read the information in this report in conjunction with the Annual Report.

Discontinued Operations

In January 2019, our board of directors approved a plan to sell our South American businesses based on our strategic focus on North America. We determined that these businesses, which previously constituted the Sempra South American Utilities segment, and certain activities associated with these businesses, met the held-for-sale criteria. These businesses are presented as discontinued operations, which we discuss further in Note 5. We completed the sales of our South American businesses in the second quarter of 2020. Our discussions in the Notes below relate only to our continuing operations unless otherwise noted.

Regulated Operations

The California Utilities and Sempra Mexico’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 Mexico 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 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

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

RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
(Dollars in millions)
	September 30,		December 31,
	2021		2020
Cash and cash equivalents	$	873	$	960
Restricted cash, current	31		22
Restricted cash, noncurrent	3		3
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	907	$	985

CREDIT LOSSES

We are exposed to credit losses from financial assets measured at amortized cost, including trade and other accounts receivable and amounts due from unconsolidated affiliates. 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 receivable, historical and industry trends, counterparty creditworthiness, economic conditions and specific events, such as bankruptcies. 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 connection with the COVID-19 pandemic, the California Utilities implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for all customers (except for SoCalGas’ noncore customers), waiving late payment fees, and offering flexible payment plans. Such measures ended on June 30, 2021, except for the suspension of service disconnections that ended on September 30, 2021. At the CPUC’s direction, the California Utilities have started to automatically enroll residential and small business customers with past-due balances in long-term repayment plans. The CPUC is continuing to consider the impacts of any state or federal relief programs on customer arrearages and if further debt relief is warranted.

As we discuss in Note 4, the CPUC authorized each of the California Utilities to track and request recovery of incremental costs, including uncollectible expenses, associated with complying with customer protection measures ordered by the CPUC related to the COVID-19 pandemic.

In connection with a separate CPUC decision addressing residential service disconnections, the California Utilities each established a two-way balancing account to record the uncollectible expenses associated with residential customers’ inability to pay their electric or gas bills, including as a result of the relief from outstanding utility bill amounts provided under the AMP. We discuss the AMP in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report.

The California Utilities have recorded increases in their allowances for expected credit losses primarily related to expected forgiveness of outstanding utility bill amounts, including increases due to the effect of the COVID-19 pandemic, for participating, income-qualified residential customers eligible under the AMP. Our businesses will continue to monitor macroeconomic factors and customer payment patterns when evaluating their allowances for credit losses, which may increase significantly due to the effects of the COVID-19 pandemic or other factors.

We provide below allowances and changes in allowances for credit losses for trade and other accounts receivable. The California Utilities record changes in the allowances for credit losses related to Accounts Receivable – Trade in regulatory accounts.

TRADE AND OTHER ACCOUNTS RECEIVABLE – ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	2021		2020
Sempra:
Allowances for credit losses at January 1	$	138	$	29
Incremental allowance upon adoption of ASU 2016-13	—		1
Provisions for expected credit losses	96		84
Write-offs	(28)		(11)
Allowances for credit losses at September 30(1)	$	206	$	103
SDG&E:
Allowances for credit losses at January 1	$	69	$	14
Provisions for expected credit losses	30		44
Write-offs	(16)		(6)
Allowances for credit losses at September 30(2)	$	83	$	52
SoCalGas:
Allowances for credit losses at January 1	$	68	$	15
Provisions for expected credit losses	64		40
Write-offs	(12)		(5)
Allowances for credit losses at September 30(3)	$	120	$	50

(1)    At September 30, 2021, includes $146 million in Accounts Receivable – Trade, Net, $50 million in Accounts Receivable – Other, Net and $10 million in Other Long-Term Assets.

(2)    At September 30, 2021, includes $58 million in Accounts Receivable – Trade, Net, $21 million in Accounts Receivable – Other, Net and $4 million in Other Long-Term Assets.

(3)    At September 30, 2021, includes $85 million in Accounts Receivable – Trade, Net, $29 million in Accounts Receivable – Other, Net and $6 million in Other Long-Term Assets.

For amounts due from unconsolidated affiliates, on a quarterly basis, we evaluate credit losses and record allowances for expected credit losses, 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.

As we discuss below in “Transactions with Affiliates,” Sempra has loans due from unconsolidated affiliates with varying tenors, interest rates and currencies. We provide below the allowances and changes in allowances for credit losses for loans and other amounts due from unconsolidated affiliates.

AMOUNTS DUE FROM UNCONSOLIDATED AFFILIATES – ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	2021		2020
Sempra:
Allowances for credit losses at January 1	$	3	$	—
Allowance established upon adoption of ASU 2016-13	—		6
Reductions to expected credit losses	(2)		(3)
Allowances for credit losses at September 30(1)	$	1	$	3

(1)    At September 30, 2021, $1 million is included in Due from Unconsolidated Affiliates – Noncurrent.

As we discuss in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report, Sempra previously provided guarantees for the benefit of Cameron LNG JV related to its construction-period debt obligations for a maximum aggregate amount of $4.0 billion. In March 2021, Cameron LNG JV reached financial completion of the three-train liquefaction project, which terminated the guarantees. There are no longer any expected credit losses related to these terminated guarantees.

As we discuss below in Note 6, Sempra provided a guarantee for the benefit of Cameron LNG JV related to amounts withdrawn by Sempra LNG from the SDSRA. At September 30, 2021, expected credit losses of $7 million related to this guarantee are included in Deferred Credits and Other on Sempra’s Condensed Consolidated Balance Sheet.

INVENTORIES

The components of inventories are as follows:

INVENTORY BALANCES
(Dollars in millions)
	Natural gas				LNG				Materials and supplies				Total
	September 30, 2021		December 31, 2020		September 30, 2021		December 31, 2020		September 30, 2021		December 31, 2020		September 30, 2021		December 31, 2020
Sempra	$	169	$	118	$	17	$	7	$	185	$	183	$	371	$	308
SDG&E	—		—		—		—		112		104		112		104
SoCalGas	110		94		—		—		58		59		168		153

WILDFIRE FUND

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

In July 2021, the CPUC approved SDG&E’s 2021 Wildfire Mitigation Plan Update. In July 2021, the CPUC’s Wildfire Safety Division became the Office of Energy Infrastructure Safety (OEIS) under the California Natural Resources Agency. As successor to the Wildfire Safety Division, OEIS maintains the duties and responsibilities of the former Wildfire Safety Division with respect to Wildfire Mitigation Plans.

SDG&E submitted its request to OEIS for a 2021 wildfire safety certification in September 2021. OEIS has until December 7, 2021 to issue the certification or provide written notice explaining why additional time is needed. SDG&E’s existing safety certification remains valid until this pending request is resolved.

In a complaint filed in U.S. District Court for the Northern District of California in July 2019, plaintiffs seek to invalidate AB 1054 based on allegations that the legislation violates federal law. The district court dismissed the complaint and the plaintiffs have petitioned the U.S. Court of Appeals for the Ninth Circuit for review.

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 interest and AFUDC.

CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Sempra	$	52	$	51	$	166	$	149
SDG&E	24		26		82		79
SoCalGas	18		14		49		39

OTHER INTANGIBLE ASSETS

Other Intangible Assets included on Sempra’s Condensed Consolidated Balance Sheets are as follows:

OTHER INTANGIBLE ASSETS
(Dollars in millions)
	Amortization period (years)	September 30, 2021		December 31, 2020
Renewable energy transmission and consumption permits	15 to 19	$	169	$	169
O&M agreement	23	66		66
PPA	14	190		—
Other	10 to indefinite	15		15
		440		250
Less accumulated amortization:
Renewable energy transmission and consumption permits		(38)		(32)
O&M agreement		(11)		(9)
PPA		(7)		—
Other		(8)		(7)
		(64)		(48)
		$	376	$	202

Other Intangible Assets at September 30, 2021 primarily include:

▪renewable energy transmission and consumption permits previously granted by the CRE at the Ventika wind power generation facilities, Don Diego Solar and Border Solar;

▪a favorable O&M agreement acquired in connection with the acquisition of Ductos y Energéticos del Norte, S. de R.L. de C.V.; and

▪an intangible asset of $190 million, representing the relative fair value of the PPA that was acquired in connection with the acquisition of ESJ in March 2021.

Intangible assets subject to amortization are amortized over their estimated useful lives. Amortization expense for intangible assets was $6 million, including $4 million recorded against revenues, and $3 million in the three months ended September 30, 2021 and 2020, respectively, and $16 million, including $7 million recorded against revenues, and $8 million in the nine months ended September 30, 2021 and 2020, respectively. We estimate the remaining amortization expense in 2021 to be $7 million, including $3 million recorded against revenues, and amortization expense of $26 million per year for the next four years, including $13 million recorded against revenues.

VARIABLE INTEREST ENTITIES

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

▪the purpose and design of the VIE;

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

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

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

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

SDG&E

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

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

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

SDG&E determined that none of its PPAs and tolling agreements resulted in SDG&E being the primary beneficiary of a VIE at September 30, 2021 and December 31, 2020. 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 $1,223 million and $1,237 million at September 30, 2021 and December 31, 2020, 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

Our 100% interest in Oncor Holdings is a VIE that owns an 80.25% interest in Oncor. 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 $12,475 million at September 30, 2021 and $12,440 million at December 31, 2020.

Sempra LNG

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 $454 million at September 30, 2021 and $433 million at

December 31, 2020. 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, which was amended in June 2021, 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 LNG consolidated $522 million and $207 million of assets at September 30, 2021 and December 31, 2020, respectively, consisting primarily of PP&E, net, attributable to ECA LNG Phase 1 that could be used only to settle obligations of this VIE and that are not available to settle obligations of Sempra, and $367 million and $49 million of liabilities at September 30, 2021 and December 31, 2020, respectively, consisting primarily of long-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 of the Notes to Consolidated Financial Statements in the Annual Report, Sempra, IEnova and TOTAL 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

Settlement Accounting for Lump Sum Payments

Sempra recorded settlement charges of $7 million in the nine months ended September 30, 2021 and $13 million and $22 million in the three months and nine months ended September 30, 2020, respectively, in net periodic benefit cost for lump sum payments from its nonqualified pension plan that were in excess of the plan’s service cost plus interest cost.

Net Periodic Benefit Cost

The following three tables provide the components of net periodic benefit cost.

NET PERIODIC BENEFIT COST – SEMPRA
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended September 30,
	2021		2020		2021		2020
Service cost	$	36	$	31	$	6	$	5
Interest cost	28		32		7		8
Expected return on assets	(44)		(41)		(14)		(14)
Amortization of:
Prior service cost (credit)	3		3		(1)		(1)
Actuarial loss (gain)	12		9		(3)		(2)
Settlement charges	—		13		—		—
Net periodic benefit cost (credit)	35		47		(5)		(4)
Regulatory adjustments	73		37		5		4
Total expense recognized	$	108	$	84	$	—	$	—
	Nine months ended September 30,
	2021		2020		2021		2020
Service cost	$	109	$	97	$	17	$	14
Interest cost	84		97		21		24
Expected return on assets	(130)		(126)		(44)		(41)
Amortization of:
Prior service cost (credit)	8		9		(2)		(2)
Actuarial loss (gain)	34		26		(7)		(7)
Settlement charges	7		22		—		—
Net periodic benefit cost (credit)	112		125		(15)		(12)
Regulatory adjustments	66		31		15		12
Total expense recognized	$	178	$	156	$	—	$	—

NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended September 30,
	2021		2020		2021		2020
Service cost	$	9	$	7	$	2	$	1
Interest cost	6		7		1		2
Expected return on assets	(11)		(12)		(2)		(3)
Amortization of:
Prior service cost	—		1		—		—
Actuarial loss (gain)	1		1		(1)		(1)
Net periodic benefit cost (credit)	5		4		—		(1)
Regulatory adjustments	21		22		—		1
Total expense recognized	$	26	$	26	$	—	$	—
	Nine months ended September 30,
	2021		2020		2021		2020
Service cost	$	26	$	23	$	4	$	3
Interest cost	18		22		4		5
Expected return on assets	(36)		(37)		(7)		(8)
Amortization of:
Prior service cost	—		2		—		—
Actuarial loss (gain)	2		3		(2)		(2)
Net periodic benefit cost (credit)	10		13		(1)		(2)
Regulatory adjustments	30		28		1		2
Total expense recognized	$	40	$	41	$	—	$	—

NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended September 30,
	2021		2020		2021		2020
Service cost	$	23	$	20	$	5	$	3
Interest cost	19		22		5		7
Expected return on assets	(27)		(27)		(12)		(11)
Amortization of:
Prior service cost (credit)	2		2		(1)		(1)
Actuarial loss (gain)	8		6		(2)		(1)
Net periodic benefit cost (credit)	25		23		(5)		(3)
Regulatory adjustments	52		15		5		3
Total expense recognized	$	77	$	38	$	—	$	—
	Nine months ended September 30,
	2021		2020		2021		2020
Service cost	$	73	$	64	$	13	$	10
Interest cost	59		66		16		19
Expected return on assets	(85)		(81)		(36)		(32)
Amortization of:
Prior service cost (credit)	6		6		(2)		(2)
Actuarial loss (gain)	27		19		(5)		(5)
Net periodic benefit cost (credit)	80		74		(14)		(10)
Regulatory adjustments	36		3		14		10
Total expense recognized	$	116	$	77	$	—	$	—

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 $539 million and $512 million at September 30, 2021 and December 31, 2020, respectively.

SEMPRA EARNINGS PER COMMON SHARE

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

EARNINGS PER COMMON SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Numerator for continuing operations:
(Loss) income from continuing operations, net of income tax	$	(632)	$	428	$	751	$	1,823
Earnings attributable to noncontrolling interests	(5)		(22)		(48)		(191)
Preferred dividends	(11)		(48)		(52)		(121)
Preferred dividends of subsidiary	—		—		(1)		(1)
(Losses) earnings from continuing operations attributable to common shares	$	(648)	$	358	$	650	$	1,510
Numerator for discontinued operations:
(Loss) income from discontinued operations, net of income tax	$	—	$	(7)	$	—	$	1,850
Earnings attributable to noncontrolling interests	—		—		—		(10)
(Losses) earnings from discontinued operations attributable to common shares	$	—	$	(7)	$	—	$	1,840
Numerator for (losses) earnings:
(Losses) earnings attributable to common shares	$	(648)	$	351	$	650	$	3,350
Denominator:
Weighted-average common shares outstanding for basic EPS(1)	319,144		289,490		309,350		291,771
Dilutive effect of stock options and RSUs(2)(3)	—		1,092		797		1,164
Dilutive effect of mandatory convertible preferred stock	—		—		707		—
Weighted-average common shares outstanding for diluted EPS	319,144		290,582		310,854		292,935
Basic EPS:
(Losses) earnings from continuing operations	$	(2.03)	$	1.23	$	2.10	$	5.17
(Losses) earnings from discontinued operations	$	—	$	(0.02)	$	—	$	6.31
(Losses) earnings	$	(2.03)	$	1.21	$	2.10	$	11.48
Diluted EPS:
(Losses) earnings from continuing operations	$	(2.03)	$	1.23	$	2.09	$	5.15
(Losses) earnings from discontinued operations	$	—	$	(0.02)	$	—	$	6.28
(Losses) earnings	$	(2.03)	$	1.21	$	2.09	$	11.43

(1)    Includes 451 and 535 fully vested RSUs held in our Deferred Compensation Plan for the three months ended September 30, 2021 and 2020, respectively, and 453 and 536 of such RSUs for the nine months ended September 30, 2021 and 2020, 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)    In the three months ended September 30, 2021, the total weighted-average number of potentially dilutive stock options and RSUs was 699. However, these securities were not included in the computation of EPS because to do so would have decreased losses per share.

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

The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect. The computation of diluted EPS for the three months and nine months ended September 30, 2021 excludes 147,840 and 240,654 potentially dilutive shares, respectively, because to include them would be antidilutive for the period. The computation of diluted EPS for the three months and nine months ended September 30, 2020 excludes 142,100 and 204,426 potentially dilutive shares, respectively, of such potentially dilutive shares. However, these shares could potentially dilute basic EPS in the future.

The potentially dilutive impact from mandatory convertible preferred stock is 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. As we discuss below in “Shareholders’ Equity and Noncontrolling Interests,” we converted our

series A preferred stock into common stock on January 15, 2021 and our series B preferred stock into common stock on July 15, 2021. The computation of diluted EPS for the three months and nine months ended September 30, 2021 excludes 639,733 and 3,037,812 potentially dilutive shares, respectively. The computation of diluted EPS for both the three months and nine months ended September 30, 2020 excludes 19,292,641 potentially dilutive shares.

Pursuant to Sempra’s share-based compensation plans, the Compensation and Talent Committee of Sempra’s board of directors granted 222,620 nonqualified stock options, 323,889 performance-based RSUs and 143,980 service-based RSUs in the nine months ended September 30, 2021, primarily in January.

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

COMPREHENSIVE INCOME

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

CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1)
(Dollars in millions)
	Foreign currency translation adjustments		Financial instruments		Pension and other postretirement benefits		Total accumulated other comprehensive income (loss)
	Three months ended September 30, 2021 and 2020
Sempra:
Balance at June 30, 2021	$	(88)	$	(265)	$	(91)	$	(444)
OCI before reclassifications	—		15		(8)		7
Amounts reclassified from AOCI	—		16		3		19
Net OCI(2)	—		31		(5)		26
Balance at September 30, 2021	$	(88)	$	(234)	$	(96)	$	(418)
Balance at June 30, 2020	$	(83)	$	(361)	$	(98)	$	(542)
OCI before reclassifications	6		14		(7)		13
Amounts reclassified from AOCI	—		4		12		16
Net OCI(2)	6		18		5		29
Balance at September 30, 2020	$	(77)	$	(343)	$	(93)	$	(513)
SDG&E:
Balance at June 30, 2021					$	(10)	$	(10)
Amounts reclassified from AOCI					1		1
Net OCI					1		1
Balance at September 30, 2021					$	(9)	$	(9)
Balance as of June 30, 2020 and September 30, 2020					$	(12)	$	(12)
SoCalGas:
Balance at June 30, 2021			$	(13)	$	(17)	$	(30)
Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance at September 30, 2021			$	(13)	$	(16)	$	(29)
Balance as of June 30, 2020 and September 30, 2020			$	(13)	$	(9)	$	(22)

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

(2)    Total AOCI includes $(4) million and $3 million of foreign currency translation adjustments and $(2) million and $2 million of financial instruments associated with the IEnova cash tender offer in 2021 and purchases of NCI in 2020, respectively, which we discuss below in “Other Noncontrolling Interests – Sempra Mexico,” and which do 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)
	Nine months ended September 30, 2021 and 2020
Sempra(2):
Balance as of December 31, 2020	$	(64)	$	(331)	$	(105)	$	(500)
OCI before reclassifications	(24)		52		(3)		25
Amounts reclassified from AOCI	—		45		12		57
Net OCI(3)	(24)		97		9		82
Balance as of September 30, 2021	$	(88)	$	(234)	$	(96)	$	(418)
Balance as of December 31, 2019	$	(607)	$	(215)	$	(117)	$	(939)
OCI before reclassifications(4)	(115)		(153)		(5)		(273)
Amounts reclassified from AOCI(4)	645		25		29		699
Net OCI(3)	530		(128)		24		426
Balance as of September 30, 2020	$	(77)	$	(343)	$	(93)	$	(513)
SDG&E:
Balance as of December 31, 2020					$	(10)	$	(10)
Amounts reclassified from AOCI					1		1
Net OCI					1		1
Balance at September 30, 2021					$	(9)	$	(9)
Balance as of December 31, 2019					$	(16)	$	(16)
Amounts reclassified from AOCI(4)					4		4
Net OCI					4		4
Balance as of September 30, 2020					$	(12)	$	(12)
SoCalGas:
Balance as of December 31, 2020			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			—		2		2
Net OCI			—		2		2
Balance as of September 30, 2021			$	(13)	$	(16)	$	(29)
Balance as of December 31, 2019			$	(13)	$	(10)	$	(23)
Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance as of September 30, 2020			$	(13)	$	(9)	$	(22)

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

(2)    Includes discontinued operations in 2020.

(3)    Total AOCI includes $20 million and $3 million of foreign currency translation adjustments and $12 million and $2 million of financial instruments associated with the IEnova exchange and cash tender offers in 2021 and purchases of NCI in 2020, respectively, which we discuss below in “Other Noncontrolling Interests – Sempra Mexico,” and which do not impact the Condensed Consolidated Statement of Comprehensive Income (Loss).

(4)    Pension and Other Postretirement Benefits and Total AOCI include $3 million in transfers of liabilities from SDG&E to Sempra in 2020 related to the nonqualified pension plans.

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 September 30,
	2021		2020
Sempra:
Financial instruments:
Interest rate instruments	$	(1)	$	3	Interest Expense
Interest rate instruments	19		5		Equity Earnings(1)
Interest rate and foreign exchange instruments	5		(4)		Other (Expense) Income, Net
Total before income tax	23		4
	(7)		—		Income Tax Benefit (Expense)
Net of income tax	$	16	$	4
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	3	$	3	Other (Expense) Income, Net
Amortization of prior service cost	1		1		Other (Expense) Income, Net
Settlement charges	—		13		Other (Expense) Income, Net
Total before income tax	4		17
	(1)		(5)		Income Tax Benefit (Expense)
Net of income tax	$	3	$	12
Total reclassifications for the period, net of tax	$	19	$	16
SDG&E:
Pension and other postretirement benefits(2):
Amortization of prior service cost	$	1	$	—	Other Income (Expense), Net
Total reclassifications for the period, net of tax	$	1	$	—
SoCalGas:
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	1	$	—	Other (Expense) Income, Net
Total reclassifications for the period, net of tax	$	1	$	—

(1)    Equity earnings at Sempra Mexico 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
	Nine months ended September 30,
	2021		2020
Sempra:
Foreign currency translation adjustments	$	—	$	645	(Loss) Income from Discontinued Operations, Net of Income Tax
Financial instruments:
Interest rate instruments	$	—	$	6	Interest Expense
Interest rate instruments	57		8		Equity Earnings(1)
Foreign exchange instruments	1		(2)		Revenues: Energy-Related Businesses
	—		(1)		Other (Expense) Income, Net
Foreign exchange instruments	1		(2)		Equity Earnings(1)
Interest rate and foreign exchange instruments	—		1		Interest Expense
	4		33		Other (Expense) Income, Net
Total before income tax	63		43
	(16)		(12)		Income Tax Benefit (Expense)
Net of income tax	47		31
	(2)		(6)		Earnings Attributable to Noncontrolling Interests
	$	45	$	25
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	6	$	6	Other (Expense) Income, Net
Amortization of actuarial loss	—		6		(Loss) Income from Discontinued Operations, Net of Income Tax
Amortization of prior service cost	3		3		Other (Expense) Income, Net
Settlement charges	7		22		Other (Expense) Income, Net
Total before income tax	16		37
	—		(2)		(Loss) Income from Discontinued Operations, Net of Income Tax
	(4)		(9)		Income Tax Benefit (Expense)
Net of income tax	$	12	$	26
Total reclassifications for the period, net of tax	$	57	$	696
SDG&E:
Pension and other postretirement benefits(2):
Amortization of prior service cost	$	1	$	1	Other Income (Expense), Net
Total reclassifications for the period, net of tax	$	1	$	1
SoCalGas:
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	1	$	—	Other (Expense) Income, Net
Amortization of prior service cost	1		1		Other (Expense) Income, Net
Total reclassifications for the period, net of tax	$	2	$	1

(1)    Equity earnings at Sempra Mexico are recognized after tax.

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

SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS

Sempra Series A Preferred Stock

On January 15, 2021, we converted 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 have returned to the status of authorized and unissued shares of preferred stock.

Sempra Series B Preferred Stock

The terms of our series B preferred stock require a notice to holders when the aggregate adjustment to the conversion rates at which shares of series B preferred stock are convertible into shares of Sempra common stock is more than 1%. On July 7, 2021, we notified the holders of the series B preferred stock of such an adjustment. These adjustments, which resulted from the incremental impact of our second quarter dividend declared on our common stock and which became effective as of July 6, 2021, the ex-dividend date for such dividend, included adjustments to the minimum and maximum conversion rates and the related initial and threshold appreciation prices.

As of July 15, 2021, we had converted, pursuant to either early conversions at the election of the holder or the mandatory conversion of all outstanding shares, all 5,750,000 shares of series B preferred stock into an aggregate of 4,256,720 shares of our common stock and a nominal amount of cash in lieu of fractional share interests, based on a conversion rate of 0.7403 shares of our common stock for each issued and outstanding share of series B preferred stock. As a consequence, no shares of series B preferred stock were outstanding after July 15, 2021 and the 5,750,000 shares that were formerly series B preferred stock have returned to the status of authorized and unissued shares of preferred stock.

Sempra Series C Preferred Stock

On June 19, 2020, we issued 900,000 shares of our 4.875% fixed-rate reset cumulative redeemable perpetual preferred stock, series C (series C preferred stock) in a registered public offering at a price to the public of $1,000 per share and received net proceeds of $889 million after deducting the underwriting discount and equity issuance costs of $11 million. We used the net proceeds for working capital and other general corporate purposes, including the repayment of indebtedness.

Sempra Common Stock Repurchases

On September 11, 2007, our board of directors authorized the repurchase of shares of our common stock, provided that the amounts spent for such purpose do not exceed the greater of $2 billion or amounts spent to purchase no more than 40,000,000 shares. On July 1, 2020, we entered into an ASR program under which we prepaid $500 million to repurchase shares of our common stock in a share forward transaction. The total number of shares purchased was determined by dividing the $500 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 July 2, 2020 through August 4, 2020, minus a fixed discount. The program was completed on August 4, 2020 with an aggregate of 4,089,375 shares of Sempra common stock repurchased at an average price of $122.27 per share. Following the completion of the ASR program, the aggregate dollar amount authorized by the September 11, 2007 share repurchase authorization was exhausted.

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. No shares have been repurchased under this authorization.

Other Noncontrolling Interests

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

OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
	Percent ownership held by noncontrolling interests				Equity held by noncontrolling interests
	September 30, 2021		December 31, 2020		September 30, 2021		December 31, 2020
Sempra Mexico:
IEnova	0.1	%	29.8	%	$	2	$	1,487
ICM Ventures Holdings B.V.	—		17.5		—		7
Sempra LNG:
ECA LNG Phase 1	16.6		29.0		28		46
Parent and other:
PXiSE	20.0		20.0		—		1
Total Sempra					$	30	$	1,541

Sempra Mexico

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. In addition to being traded on the New York Stock Exchange, Sempra’s common stock is now also listed on the Mexican Stock Exchange under the ticker symbol SRE.MX. We acquired the IEnova shares at an exchange ratio of 0.0323 shares of our common stock for each one IEnova ordinary share. In connection with the exchange offer, we recorded an increase in Sempra’s shareholders’ equity of $1,361 million, net of $12 million in transactions costs, and increased our ownership interest in IEnova from 70.2% to 96.4%.

In September 2021, we acquired 51,014,545 publicly owned shares of IEnova for 4.0 billion Mexican pesos (approximately $202 million in U.S. dollars) in cash upon completion of our tender offer launched in the U.S. and Mexico in August 2021, which increased our ownership interest in IEnova from 96.4% to 99.9%. We acquired these IEnova shares at a price of 78.97 Mexican pesos per share (approximately $3.95 per share in U.S. dollars). Following the cash tender offer, we recorded a decrease in Sempra’s shareholders’ equity of $14 million, including $1 million in transaction costs. 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 remaining publicly owned IEnova shares for 78.97 Mexican pesos per share, the same price per share that was offered in our cash tender offer. The trust will be in place through the earlier of April 14, 2022 or the date on which we acquire all the remaining publicly owned IEnova shares.

As a result of the increase in our ownership interest in IEnova, we recorded an increase in Sempra’s shareholders’ equity of $84 million offset by a deferred income tax asset related to the outside basis difference in IEnova’s shares. Upon completing the sale of a 20% equity interest in Sempra Infrastructure Partners in October 2021, which we discuss below, we recorded $72 million in net income tax expense related to the utilization of this deferred income tax asset, net of the income tax effect reclassified from AOCI to earnings.

In the nine months ended September 30, 2020, IEnova repurchased 57,547,381 shares of its outstanding common stock held by NCI for $167 million, resulting in an increase in Sempra’s ownership interest in IEnova from 66.6% at December 31, 2019 to 69.2% at September 30, 2020.

In the first quarter of 2020, IEnova purchased additional shares in ICM Ventures Holdings B.V. for $9 million, increasing its ownership from 53.7% to 82.5%. ICM Ventures Holdings B.V. owns certain permits and land where IEnova is building a terminal for the receipt, storage and delivery of liquid fuels. In July 2021, IEnova acquired the remaining 17.5% interest held by NCI in ICM Ventures Holdings B.V. for $7 million.

Sempra LNG

In March 2020, Sempra LNG purchased for $7 million the 24.6% minority interest in Liberty Gas Storage LLC, which owns 100% of LA Storage, LLC, increasing Sempra LNG’s ownership in Liberty Gas Storage LLC to 100%. Prior to the purchase, the minority partner converted $22 million in notes payable due from Sempra LNG to equity. As a result of the purchase, we recorded an increase in Sempra’s shareholders’ equity of $2 million for the difference between the carrying value and fair value related to the change in ownership.

Sempra Infrastructure Partners

Sale of NCI. On October 1, 2021, Sempra, its wholly owned subsidiary, Sempra Infrastructure Partners (formerly Sempra Global), and KKR consummated the transactions contemplated under a purchase and contribution agreement dated April 4, 2021 (as amended on September 27, 2021 to reflect immaterial revisions prior to closing, the Purchase Agreement). Pursuant to the Purchase Agreement, KKR acquired for a purchase price of $3.37 billion, which remains subject to post-closing adjustments, newly designated Class A Units representing 20% of the equity interests of Sempra Infrastructure Partners. Prior to closing the transaction, we completed an internal legal reorganization to consolidate the assets of Sempra LNG and our ownership of IEnova under Sempra Global, which was renamed Sempra Infrastructure Partners. On October 1, 2021, Sempra Infrastructure Partners paid $149 million to KKR for reimbursement of certain expenses that KKR incurred in connection with closing the transaction. As of September 30, 2021, the composition of our reportable segments did not change.

At the closing of the transactions contemplated under the Purchase Agreement on October 1, 2021, we owned 99.9% of the outstanding ordinary shares of IEnova. Under the terms of the Purchase Agreement, the base purchase price was adjusted downward at closing by $1 million based on the number of IEnova ordinary shares we did not own at the closing. If we later acquire additional shares of IEnova after the closing, such additional shares will be acquired by Sempra Infrastructure Partners and KKR will provide 20% of the funding.

We estimate that Sempra Infrastructure Partners had approximately $8.37 billion of direct and indirect net debt at the closing, and there will be a customary upward or downward adjustment to the purchase price to the extent the actual net debt at closing was greater or less than such estimated amount. Direct and indirect net debt at Sempra Infrastructure Partners includes consolidated long-term and short-term debt less cash at Sempra LNG and IEnova plus their proportionate ownership share of equity method investees’ long-term and short-term debt less cash.

Pursuant to the Purchase Agreement, we have agreed to indemnify Sempra Infrastructure Partners for, among other things, certain losses arising from liabilities of Sempra Infrastructure Partners and its subsidiaries to the extent not primarily relating to the undertaking of the business of Sempra Infrastructure Partners, and we have agreed to indemnify KKR for losses attributable to pre-closing taxes.

We have also entered into an accommodation and support agreement under which KKR has the ability to borrow from Sempra up to $300 million plus reimbursement of certain fees related to such borrowing, which we fully funded on November 1, 2021. This loan is due to be repaid in full no later than October 1, 2029 and bears compound interest at 5% per annum.

Limited Partnership Agreement. At the closing of the sale of NCI in Sempra Infrastructure Partners, Sempra and KKR entered into a limited partnership agreement (the LP Agreement), which governs our and their respective rights and obligations in respect of our ownership of Sempra Infrastructure Partners. We maintain control of Sempra Infrastructure Partners as the 80% owner with KKR having certain minority protections commensurate with the size of its investment.

Sempra Infrastructure Partners has two authorized classes of units, designated as “Class A Units” (which are common voting units) and “Sole Risk Interests.” If KKR approves our request that a project not be pursued jointly, or if KKR decides not to participate in any proposed project for which we nevertheless desire to make a positive final investment decision, we will be permitted to proceed with such project either independently through a different investment vehicle or as a “Sole Risk Project” within Sempra Infrastructure Partners and receive Sole Risk Interests in respect thereof. Sole Risk Projects are separated from other Sempra Infrastructure Partners projects and are conducted at our sole cost, expense and liability and we receive, through the acquisition of Sole Risk Interests, any economic and other benefits from such projects. KKR is not entitled to any benefits or rights in respect of any Sole Risk Project. The Guaymas-El Oro segment of the Sonora pipeline at IEnova currently constitutes a Sole Risk Project. Until a specified date, KKR has certain discretionary rights to cause the Guaymas-El Oro segment of the Sonora pipeline to cease to be a Sole Risk Project and be pursued jointly within Sempra Infrastructure Partners.

Under the LP Agreement, Sempra Infrastructure Partners is managed by a board of managers comprised of members designated by us and by KKR. Matters are generally decided by majority vote. The managers designated by us and the managers designated by KKR each, as a group, have voting power equivalent to the ownership percentage of their respective designating member. However, Sempra Infrastructure Partners and its controlled subsidiaries are prohibited from taking certain actions without the prior written approval of KKR (subject to KKR maintaining certain ownership thresholds in Sempra Infrastructure Partners).

The LP Agreement contains certain default remedies if we or KKR fails to fund any amounts required to be funded under the LP Agreement.

The LP Agreement also requires that Sempra Infrastructure Partners distribute to us and to KKR at least 85% of distributable cash flow of Sempra Infrastructure Partners and its subsidiaries on a quarterly basis, subject to certain exceptions and reserves. Generally, distributions from Sempra Infrastructure Partners are made to us and KKR on a pro rata basis in accordance with our and their respective ownership interests in Sempra Infrastructure Partners. However, KKR is entitled to certain priority distributions in the event of material deviations between certain specified projected cash flows and actual cash flows. Additionally, KKR is entitled to certain priority distributions in the event a specified project that reaches a positive final investment decision does not have projected internal rates of return over a specified threshold or in the event we have not made a positive final investment decision by a certain date on specified LNG projects that are currently in development.

In addition, under the LP Agreement, both parties are granted customary registration rights in the event of an initial public offering of Sempra Infrastructure Partners, which is subject to certain consent rights of KKR.

Management Agreement. At the closing of the transactions contemplated under the Purchase Agreement, Sempra Infrastructure Partners entered into a management agreement with Sempra to engage Sempra for certain staffing and general and administrative services. The management agreement governs the services that Sempra will provide to Sempra Infrastructure Partners and the charges associated with those services.

Discontinued Operations

As we discuss in Note 5, we completed the sales of our equity interests in our Peruvian and Chilean businesses in the second quarter of 2020. The minority interests in Luz del Sur and Tecsur were deconsolidated upon the sale of our Peruvian businesses in April 2020, and the minority interests in Chilquinta Energía and its subsidiaries were deconsolidated upon the sale of our Chilean businesses in June 2020.

TRANSACTIONS WITH AFFILIATES

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

AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	September 30, 2021		December 31, 2020
Sempra:
Total due from various unconsolidated affiliates – current	$	30	$	20
Sempra Mexico(1):
ESJ – Note due December 31, 2022, net of negligible allowance for credit losses at December 31, 2020(2)	$	—	$	85
IMG JV – Note due March 15, 2022, net of allowance for credit losses of $1 and $3 at September 30, 2021 and December 31, 2020, respectively(3)	684		695
Total due from unconsolidated affiliates – noncurrent	$	684	$	780
Sempra Mexico – TAG Pipelines Norte, S. de. R.L. de C.V. – Note due December 20, 2021(1)(4)	$	(42)	$	(41)
Various affiliates	—		(4)
Total due to unconsolidated affiliates – current	$	(42)	$	(45)
Sempra Mexico(1)(5):
TAG Pipelines Norte, S. de. R.L. de C.V.:
5.5% Note due January 9, 2024	$	(71)	$	(68)
5.5% Note due January 14, 2025	(21)		—
5.5% Note due July 16, 2025	(20)		—
TAG JV – 5.74% Note due December 17, 2029	(174)		(166)
Total due to unconsolidated affiliates – noncurrent	$	(286)	$	(234)
SDG&E:
Total due from various unconsolidated affiliates – current	$	1	$	—
Sempra	$	(45)	$	(38)
SoCalGas	(9)		(21)
Various affiliates	(7)		(5)
Total due to unconsolidated affiliates – current	$	(61)	$	(64)
Income taxes due from Sempra(6)	$	29	$	—
SoCalGas:
SDG&E	$	9	$	21
Various affiliates	2		1
Total due from unconsolidated affiliates – current	$	11	$	22
Sempra	$	(45)	$	(31)
Total due to unconsolidated affiliates – current	$	(45)	$	(31)
Income taxes due from (to) Sempra(6)	$	1	$	(37)

(1)    Amounts include principal balances plus accumulated interest outstanding.

(2)    U.S. dollar-denominated loan at a variable interest rate based on 1-month LIBOR plus 196 bps (2.11% at December 31, 2020). At December 31, 2020, $1 million of accrued interest receivable is included in Due from Unconsolidated Affiliates – Current. In March 2021, IEnova acquired the 50% equity interest in ESJ that it did not already own and ESJ became a wholly owned, consolidated subsidiary, resulting in the elimination of this note receivable.

(3)    Mexican peso-denominated revolving line of credit for up to 14.2 billion Mexican pesos or approximately $689 million U.S. dollar-equivalent at September 30, 2021, at a variable interest rate based on the 91-day Interbank Equilibrium Interest Rate plus 220 bps (7.02% at September 30, 2021), to finance construction of a natural gas marine pipeline. At both September 30, 2021 and December 31, 2020, $2 million of accrued interest receivable is included in Due from Unconsolidated Affiliates – Current. At September 30, 2021, we classified this revolving line of credit as noncurrent because we expect to extend the maturity date on a long-term basis prior to its stated maturity date.

(4)    U.S. dollar-denominated loan at a variable interest rate based on 6-month LIBOR plus 290 bps (3.06% at September 30, 2021).

(5)     U.S. dollar-denominated loans at fixed interest rates.

(6)    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.

The following table summarizes income statement information from unconsolidated affiliates.

INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Sempra:
Revenues	$	7	$	9	$	22	$	31
Cost of sales	—		9		11		35
Interest income	11		12		38		44
Interest expense	4		4		11		11
SDG&E:
Revenues	$	3	$	1	$	7	$	4
Cost of sales	20		17		75		56
SoCalGas:
Revenues	$	24	$	23	$	72	$	61
Cost of sales(1)	(2)		2		1		2

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

Guarantees

Sempra provided guarantees related to Cameron LNG JV’s construction-period debt, which were terminated in March 2021, as well as 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 September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Sempra:
Allowance for equity funds used during construction	$	31	$	34	$	103	$	96
Investment gains, net(1)	—		16		28		9
(Losses) gains on interest rate and foreign exchange instruments, net	(3)		19		(26)		(129)
Foreign currency transaction (losses) gains, net(2)	(17)		15		(10)		(95)
Non-service component of net periodic benefit cost	(66)		(48)		(52)		(45)
Fine related to Energy Efficiency Program inquiry	—		(6)		—		(6)
Interest on regulatory balancing accounts, net	2		—		5		13
Sundry, net	(2)		(1)		4		(6)
Total	$	(55)	$	29	$	52	$	(163)
SDG&E:
Allowance for equity funds used during construction	$	18	$	21	$	63	$	61
Non-service component of net periodic benefit cost	(15)		(18)		(10)		(15)
Fine related to Energy Efficiency Program inquiry	—		(6)		—		(6)
Interest on regulatory balancing accounts, net	2		—		5		8
Sundry, net	(1)		1		3		(1)
Total	$	4	$	(2)	$	61	$	47
SoCalGas:
Allowance for equity funds used during construction	$	13	$	11	$	36	$	29
Non-service component of net periodic benefit cost	(49)		(15)		(30)		(3)
Interest on regulatory balancing accounts, net	—		—		—		5
Sundry, net	(3)		(3)		(8)		(10)
Total	$	(39)	$	(7)	$	(2)	$	21

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

(2)    Includes losses of $18 million and $13 million in the three months and nine months ended September 30, 2021, respectively, and gains of $15 million and losses of $120 million in the three months and nine months ended September 30, 2020, respectively, from translation to U.S. dollars of a Mexican peso-denominated loan to IMG JV, 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 (BENEFIT) EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended September 30,						Nine months ended September 30,
	2021			2020			2021			2020
Sempra:
Income tax (benefit) expense from continuing operations	$	(342)		$	99		$	(45)		$	60
(Loss) income from continuing operations before income taxes and equity earnings	$	(1,365)		$	201		$	(316)		$	1,061
Equity earnings, before income tax(1)	137			117			457			158
Pretax (loss) income	$	(1,228)		$	318		$	141		$	1,219
Effective income tax rate	28		%	31		%	(32)		%	5		%
SDG&E:
Income tax expense	$	90		$	33		$	168		$	161
Income before income taxes	$	295		$	211		$	771		$	794
Effective income tax rate	31		%	16		%	22		%	20		%
SoCalGas:
Income tax (benefit) expense	$	(437)		$	(6)		$	(335)		$	95
(Loss) income before income taxes	$	(1,563)		$	(30)		$	(959)		$	521
Effective income tax rate	28		%	20		%	35		%	18		%

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

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

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

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

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

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

▪utility self-developed software expenditures

▪depreciation on a certain portion of utility plant assets

▪state income taxes

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

We record income tax (expense) benefit from the transactional effects of foreign currency and inflation. Through the first quarter of 2021, such effects were offset by net gains (losses) from foreign currency derivatives that were hedging Sempra Mexico parent’s exposure to movements in the Mexican peso from its controlling interest in IEnova.

Discontinued Operations

In January 2019, our board of directors approved a plan to sell our South American businesses. We completed the sales in the second quarter of 2020, as we discuss in Note 5. Because of our decision to sell our South American businesses, we no longer asserted indefinite reinvestment of basis differences related to these businesses. Accordingly, in the nine months ended September 30, 2020, we recorded a $7 million income tax benefit from changes in outside basis differences in our discontinued operations in South America.

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NEW ACCOUNTING STANDARDS

9 Months Ended

Sep. 30, 2021

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 financial condition, results of operations, 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 conversion and cash conversion features. The standard also amends ASC 260, “Earnings Per Share,” as follows:

▪requires an entity to apply the if-converted method when calculating diluted EPS for convertible instruments and no longer use the treasury stock method, which was previously allowed for certain convertible instruments;

▪requires an entity to include the effect of potential share settlement in the diluted EPS calculation when an instrument may be settled in cash or shares, and no longer allows an entity to rebut the presumption of share settlement if it has a history or policy of cash settlement;

▪requires an entity to include equity-classified convertible preferred stock that contains down-round features whereby, if the down-round feature is triggered, its effect is treated as a dividend and as a reduction of income available to common shareholders in basic EPS;

▪clarifies that the average market price should be used to calculate the diluted EPS denominator when the exercise price or the number of shares that may be issued is variable, except for certain contingently issuable shares; and

▪clarifies that the weighted-average share count from each quarter should be used when calculating the year-to-date weighted-average share count.

For public entities, ASU 2020-06 is effective for fiscal years beginning after December 15, 2021, including interim periods therein, with early adoption permitted for fiscal years beginning after December 15, 2020. 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 plan to adopt the standard on January 1, 2022 and are currently evaluating the effect of the standard on our ongoing financial reporting.

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REVENUES

9 Months Ended

Sep. 30, 2021

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 Mexico		Sempra LNG		Consolidating adjustments and Parent and Other		Sempra
	Three months ended September 30, 2021
By major service line:
Utilities	$	1,369	$	966	$	17	$	—	$	(27)	$	2,325
Energy-related businesses	—		—		324		144		(145)		323
Revenues from contracts with customers	$	1,369	$	966	$	341	$	144	$	(172)	$	2,648
By market:
Gas	$	145	$	966	$	231	$	143	$	(165)	$	1,320
Electric	1,224		—		110		1		(7)		1,328
Revenues from contracts with customers	$	1,369	$	966	$	341	$	144	$	(172)	$	2,648
Revenues from contracts with customers	$	1,369	$	966	$	341	$	144	$	(172)	$	2,648
Utilities regulatory revenues	95		140		—		—		—		235
Other revenues	—		—		256		(25)		(101)		130
Total revenues	$	1,464	$	1,106	$	597	$	119	$	(273)	$	3,013
	Nine months ended September 30, 2021
By major service line:
Utilities	$	3,755	$	3,685	$	61	$	—	$	(79)	$	7,422
Energy-related businesses	—		—		859		260		(282)		837
Revenues from contracts with customers	$	3,755	$	3,685	$	920	$	260	$	(361)	$	8,259
By market:
Gas	$	580	$	3,685	$	635	$	257	$	(334)	$	4,823
Electric	3,175		—		285		3		(27)		3,436
Revenues from contracts with customers	$	3,755	$	3,685	$	920	$	260	$	(361)	$	8,259
Revenues from contracts with customers	$	3,755	$	3,685	$	920	$	260	$	(361)	$	8,259
Utilities regulatory revenues	364		53		—		—		—		417
Other revenues	—		—		448		107		(218)		337
Total revenues	$	4,119	$	3,738	$	1,368	$	367	$	(579)	$	9,013

DISAGGREGATED REVENUES (CONTINUED)
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Mexico		Sempra LNG		Consolidating adjustments and Parent and other		Sempra
	Three months ended September 30, 2020
By major service line:
Utilities	$	1,301	$	813	$	12	$	—	$	(25)	$	2,101
Energy-related businesses	—		—		244		35		(32)		247
Revenues from contracts with customers	$	1,301	$	813	$	256	$	35	$	(57)	$	2,348
By market:
Gas	$	126	$	813	$	159	$	33	$	(54)	$	1,077
Electric	1,175		—		97		2		(3)		1,271
Revenues from contracts with customers	$	1,301	$	813	$	256	$	35	$	(57)	$	2,348
Revenues from contracts with customers	$	1,301	$	813	$	256	$	35	$	(57)	$	2,348
Utilities regulatory revenues	171		29		—		—		—		200
Other revenues	—		—		95		28		(27)		96
Total revenues	$	1,472	$	842	$	351	$	63	$	(84)	$	2,644
	Nine months ended September 30, 2020
By major service line:
Utilities	$	3,610	$	3,261	$	42	$	—	$	(66)	$	6,847
Energy-related businesses	—		—		616		56		(40)		632
Revenues from contracts with customers	$	3,610	$	3,261	$	658	$	56	$	(106)	$	7,479
By market:
Gas	$	518	$	3,261	$	439	$	51	$	(98)	$	4,171
Electric	3,092		—		219		5		(8)		3,308
Revenues from contracts with customers	$	3,610	$	3,261	$	658	$	56	$	(106)	$	7,479
Revenues from contracts with customers	$	3,610	$	3,261	$	658	$	56	$	(106)	$	7,479
Utilities regulatory revenues	366		(14)		—		—		—		352
Other revenues	—		—		277		199		(108)		368
Total revenues	$	3,976	$	3,247	$	935	$	255	$	(214)	$	8,199

Remaining Performance Obligations

For contracts greater than one year, at September 30, 2021, we expect to recognize revenue related to the fixed fee component of the consideration as shown below. SoCalGas did not have any such performance obligations at September 30, 2021.

REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra		SDG&E
2021 (excluding first nine months of 2021)	$	88	$	1
2022	368		4
2023	367		4
2024	367		4
2025	364		4
Thereafter	4,129		67
Total revenues to be recognized	$	5,683	$	84

(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 nine months ended September 30, 2021 or 2020.

CONTRACT LIABILITIES
(Dollars in millions)
	2021		2020
Sempra:
Contract liabilities at January 1	$	(207)	$	(163)
Revenue from performance obligations satisfied during reporting period	36		3
Payments received in advance	(1)		—
Contract liabilities at September 30(1)	$	(172)	$	(160)
SDG&E:
Contract liabilities at January 1	$	(87)	$	(91)
Revenue from performance obligations satisfied during reporting period	3		3
Contract liabilities at September 30(1)	$	(84)	$	(88)

(1)     At September 30, 2021, includes $8 million and $4 million in Other Current Liabilities and $164 million and $80 million 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)
	September 30, 2021		December 31, 2020
Sempra:
Accounts receivable – trade, net	$	1,216	$	1,447
Accounts receivable – other, net	17		12
Due from unconsolidated affiliates – current(1)	2		3
Other long-term assets	115		—
Total	$	1,350	$	1,462
SDG&E:
Accounts receivable – trade, net	$	642	$	573
Accounts receivable – other, net	11		8
Due from unconsolidated affiliates – current(1)	3		2
Other long-term assets	47		—
Total	$	703	$	583
SoCalGas:
Accounts receivable – trade, net	$	462	$	786
Accounts receivable – other, net	6		4
Other long-term assets	68		—
Total	$	536	$	790

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

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REGULATORY MATTERS

9 Months Ended

Sep. 30, 2021

Regulated Operations [Abstract]

REGULATORY MATTERS

REGULATORY MATTERSWe discuss regulatory matters in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report and provide updates to those discussions and information about new regulatory matters below. With the exception of regulatory balancing accounts, we generally do not earn a return on our regulatory assets until such time as a related cash expenditure has been made. Upon the occurrence of a cash expenditure associated with a regulatory asset, the related amounts are recoverable through a regulatory account mechanism for which we earn a return authorized by applicable regulators, which currently 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 AND LIABILITIES

We show the details of regulatory assets and liabilities in the following table.

REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	September 30, 2021		December 31, 2020
SDG&E:
Fixed-price contracts and other derivatives	$	(88)	$	(53)
Deferred income taxes recoverable in rates	72		22
Pension and other postretirement benefit plan obligations	19		50
Removal obligations	(2,228)		(2,121)
Environmental costs	55		56
Sunrise Powerlink fire mitigation	121		121
Regulatory balancing accounts(1)(2)
Commodity – electric	85		72
Gas transportation	23		35
Safety and reliability	60		67
Public purpose programs	(138)		(158)
2019 GRC retroactive impacts	14		56
Other balancing accounts	535		233
Other regulatory assets, net(2)	110		72
Total SDG&E	(1,360)		(1,548)
SoCalGas:
Deferred income taxes recoverable (refundable) in rates	9		(82)
Pension and other postretirement benefit plan obligations	342		417
Employee benefit costs	37		37
Removal obligations	(649)		(685)
Environmental costs	35		36
Regulatory balancing accounts(1)(2)
Commodity – gas, including transportation	(138)		(56)
Safety and reliability	299		335
Public purpose programs	(274)		(253)
2019 GRC retroactive impacts	51		202
Other balancing accounts	85		(58)
Other regulatory assets, net(2)	160		75
Total SoCalGas	(43)		(32)
Sempra Mexico:
Deferred income taxes recoverable in rates	80		80
Total Sempra	$	(1,323)	$	(1,500)

(1)    At September 30, 2021 and December 31, 2020, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $331 million and $139 million, respectively, and for SoCalGas was $472 million and $218 million, respectively.

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

CALIFORNIA UTILITIES

COVID-19 Pandemic Protections

In connection with the COVID-19 pandemic, the California Utilities implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for all customers (except for SoCalGas’ noncore customers), waiving late payment fees, and offering flexible payment plans. Such measures ended on June 30, 2021, except for the suspension of service disconnections that ended on September 30, 2021. At the CPUC’s direction, the California Utilities have started to automatically enroll residential and small business customers with past-due balances in long-term repayment plans. The CPUC is continuing to consider the impacts of any state or federal relief programs on customer arrearages and if further debt relief is warranted.

Each of the California Utilities has been authorized to track and request recovery of incremental costs associated with complying with customer protection measures implemented by the CPUC related to the COVID-19 pandemic, including costs associated

with suspending service disconnections and uncollectible expenses that arise from customers’ failure to pay. The California Utilities expect to pursue recovery of small and medium-large commercial and industrial customers’ tracked costs in rates in a future CPUC proceeding, which recovery is not assured. Uncollectible expenses related to residential customers are recorded in a two-way balancing account as we discuss below.

Disconnection OIR

In June 2020, the CPUC issued a decision to adopt certain customer protections to reduce residential customer disconnections and improve reconnection processes, including, among other things, imposing limitations on service disconnections, elimination of deposit requirements and reconnection fees, establishment of the AMP that provides successfully participating, income-qualified residential customers with relief from outstanding utility bill amounts, and increased outreach and marketing efforts. As permitted by the decision, each of the California Utilities has established a two-way balancing account to record the uncollectible expenses associated with residential customers’ inability to pay their electric or gas bills, including as a result of the relief from outstanding utility bill amounts provided under the AMP.

CPUC GRC

The CPUC uses GRCs to set rates designed to allow the California Utilities to recover their reasonable operating costs and to provide the opportunity to realize their authorized rates of return on their investments.

In January 2020, the CPUC issued a final decision implementing a four-year GRC cycle for California IOUs and the California Utilities were directed to file a petition for modification to revise their 2019 GRC to add two additional attrition years, resulting in a transitional five-year GRC period (2019-2023). The California Utilities filed the petition in April 2020.

In May 2021, the CPUC issued a final decision approving the California Utilities’ request to continue their authorized post-test year mechanisms for 2022 and 2023. For SDG&E, the decision authorizes revenue requirement increases of $87 million (3.92%) for 2022 and $86 million (3.70%) for 2023. For SoCalGas, the decision authorizes revenue requirement increases of $142 million (4.53%) for 2022 and $130 million (3.97%) for 2023.

The 2019 GRC FD clarified that differences between incurred and forecasted income tax expense due to forecasting differences are not subject to tracking in the income tax expense memorandum account beginning in 2019. SDG&E and SoCalGas previously recorded regulatory liabilities, inclusive of interest, associated with the 2016 through 2018 tracked forecasting differences of $86 million and $89 million, respectively. In April 2020, the CPUC confirmed treatment of the two-way income tax expense memorandum account for these 2016 through 2018 balances, at which time the California Utilities released these regulatory liability balances to revenues and regulatory interest.

We provide additional information concerning the 2019 GRC FD in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report.

CPUC Cost of Capital

A CPUC cost of capital proceeding determines a utility’s authorized capital structure and authorized return on rate base. In December 2019, the CPUC approved the cost of capital and rate structures 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. The CCM considers 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. 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.

Alternatively, under the CCM, each of the California Utilities 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. In August 2021, SDG&E filed an application with the CPUC to update its cost of capital effective January 1, 2022 due to the ongoing effects of the COVID-19 pandemic. In this application, SDG&E proposed to adjust its authorized capital structure by increasing its common equity ratio from 52% to 54%. SDG&E also proposed to increase its authorized ROE from 10.20% to 10.55% and decrease its authorized cost of debt from 4.59% to 3.84%. As a result, SDG&E’s proposed return on rate base would decrease from 7.55% to 7.46% if such application is approved by the CPUC as filed. SDG&E filed a joint motion with PG&E and Edison to consolidate all three utilities’ cost of capital applications given the overlapping issues of law and fact, which joint motion was granted in October 2021.

For the measurement period ended September 30, 2021, the CCM would trigger for SDG&E 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%. However, SDG&E’s application to update its cost of capital effective January 1, 2022, if accepted by the CPUC, would supersede the CCM from applying. If such application is not accepted, the CCM would be effective 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. SDG&E has requested that a final CPUC decision on its interim cost of capital application be issued in the first half of 2022.

For the measurement period ended September 30, 2021, the CCM was not triggered for SoCalGas. SoCalGas expects to file its next cost of capital application in April 2022 for a January 1, 2023 effective date.

SDG&E

FERC Rate Matters and Cost of Capital

SDG&E files separately with the FERC for its authorized ROE on FERC-regulated electric transmission operations and assets.

SDG&E’s TO4 ROE of 10.05% was the basis of SDG&E’s FERC-related revenue recognition until March 2020, when the FERC approved the settlement terms that SDG&E and all settling parties reached in October 2019 on SDG&E’s TO5 filing. The settlement agreement provided for a ROE of 10.60%, consisting of a base ROE of 10.10% plus an additional 50 bps for participation in the California ISO (the California ISO adder). If the FERC issues an order ruling that California IOUs are no longer eligible for the California ISO adder, SDG&E would refund the California ISO adder as of the refund effective date (June 1, 2019) if such a refund is determined to be required by the terms of the TO5 settlement. The TO5 term is effective June 1, 2019 and shall remain in effect each calendar year until terminated by a notice at least six months before the end of a calendar year. In the first quarter of 2020, SDG&E recorded retroactive revenues of $12 million related to 2019, and additional FERC revenues of $17 million to conclude a rate base matter, net of certain refunds to be paid to CPUC-jurisdictional customers.

Energy Efficiency Program Inquiry

In January 2020, the CPUC issued a ruling seeking comments on a report prepared by its consultant regarding SDG&E’s Upstream Lighting Program for the program year 2017. The CPUC subsequently expanded the scope of the comments to cover the program year 2018. The Upstream Lighting Program was one of SDG&E’s Energy Efficiency Programs designed to produce energy efficiency savings for which SDG&E could earn a performance-based incentive.

Pursuant to the CPUC ruling, intervenors representing ratepayers questioned SDG&E’s management of the program and alleged that certain program expenditures did not benefit the purpose of the program. As a result of the inquiry, SDG&E voluntarily expanded its review to include the program year 2019. Based on this review, SDG&E concluded some concessions were appropriate, which included refunding certain costs to customers and reducing certain performance-based incentives. Accordingly, in the three months and nine months ended September 30, 2020, SDG&E reduced revenues by $36 million and $51 million, respectively, and recorded a fine of $6 million in Other (Expense) Income, Net, on the SDG&E and Sempra Condensed Consolidated Statements of Operations. The after-tax impact for the three months and nine months ended September 30, 2020 was $29 million and $44 million, respectively. In October 2020, SDG&E executed a settlement agreement with intervenors consistent with these concessions. In September 2021, the CPUC approved the settlement agreement.

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. The OSC stemmed from a short period of transitional energy efficiency (EE) codes and standards advocacy activities undertaken by SoCalGas in 2018, following a CPUC decision disallowing SoCalGas’ future engagement in EE statewide codes and standards advocacy. We are awaiting a CPUC decision.

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, whether its shareholders should bear the costs of those advocacy activities, and to address whether any other remedies are appropriate. The scope of this OSC was later expanded to include EE program years 2014 and 2015, and SoCalGas’ engagement with local governments on proposed reach codes. In April 2021, the assigned Administrative Law Judge issued a Presiding Officer’s Decision (POD) on the second OSC. The POD 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. The POD, which is currently under appeal by intervenors, orders customer refunds that SoCalGas expects will be negligible (subject to a CPUC audit). Additionally, the POD precludes SoCalGas

from seeking cost recovery associated with EE codes and standards advocacy programs until lifted by the CPUC, and orders certain nonfinancial remedies.

Intervenors in these OSCs have suggested the CPUC order various financial and non-financial penalties. If the CPUC were to assess fines or penalties on SoCalGas associated with these OSCs, they could be material.

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.

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 September 2020, the foundation filed another writ petition under the California Coastal Act in LA Superior Court seeking to set aside the California Coastal Commission’s July 2020 approval of the inspection and maintenance plan for the SONGS’ canisters and to obtain injunctive relief to stop decommissioning work. A trial date for this petition has been set for April 2022. To date, decommissioning work has not been interrupted as a result of these writ petitions.

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. The amounts 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 2020, SDG&E received authorization from the CPUC to access NDT funds of up to $89 million for forecasted 2021 costs.

The following table shows the fair values and gross unrealized gains and losses for the securities held in the NDT. 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
At September 30, 2021:
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	52	$	—	$	—	$	52
Municipal bonds(2)	307		14		(1)		320
Other securities(3)	261		10		(1)		270
Total debt securities	620		24		(2)		642
Equity securities	103		255		(2)		356
Cash and cash equivalents	7		—		—		7
Payables, net	(2)		—		—		(2)
Total	$	728	$	279	$	(4)	$	1,003
At December 31, 2020:
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	$	64	$	1	$	—	$	65
Municipal bonds	308		18		—		326
Other securities	253		17		—		270
Total debt securities	625		36		—		661
Equity securities	112		254		(2)		364
Cash and cash equivalents	3		—		—		3
Payables, net	(9)		—		—		(9)
Total	$	731	$	290	$	(2)	$	1,019

(1)    Maturity dates are 2021-2051.

(2)    Maturity dates are 2022-2056.

(3)    Maturity dates are 2021-2072.

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 NDT
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Proceeds from sales	$	187	$	294	$	729	$	1,091
Gross realized gains	9		9		48		108
Gross realized losses	(1)		(2)		(4)		(13)

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 AND SPENT NUCLEAR FUEL

The present value of SDG&E’s ARO related to decommissioning costs for the SONGS units was $551 million at September 30, 2021. That amount includes the cost to decommission Units 2 and 3, and the remaining cost to complete the decommissioning of Unit 1, which is substantially complete. The ARO for all three units is based on a cost study prepared in 2017 that is pending CPUC approval. The ARO for Units 2 and 3 reflects the acceleration of the start of decommissioning of these units as a result of the early closure of the plant. SDG&E’s share of total decommissioning costs in 2021 dollars is approximately $886 million.

NUCLEAR INSURANCE

SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. Currently, this insurance provides $450 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides an additional $110 million of coverage. If a nuclear liability loss occurs at SONGS and exceeds the $450 million insurance limit, this additional coverage would be available to provide a total of $560 million in coverage limits per incident.

The SONGS co-owners have nuclear property damage insurance of $130 million, which exceeds the minimum federal requirements 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 $4.3 million of retrospective premiums based on overall member claims.

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

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ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS

9 Months Ended

Sep. 30, 2021

Business Combinations [Abstract]

ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS

ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS

ACQUISITION

Sempra Mexico

ESJ

In March 2021, IEnova completed the acquisition of Saavi Energía’s 50% equity interest in ESJ for a purchase price of approximately $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 IEnova that eliminates upon consolidation). IEnova previously accounted for its 50% interest in ESJ as an equity method investment. This acquisition increased IEnova’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. IEnova 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. ESJ is constructing a second wind power generation facility with a nameplate capacity of 108 MW that we expect will be completed in the first quarter of 2022.

DISCONTINUED OPERATIONS

In April 2020, we completed the sale of our equity interests in our Peruvian businesses, including our 83.6% interest in Luz del Sur and its interest in Tecsur, to an affiliate of China Yangtze Power International (Hongkong) Co., Limited for cash proceeds of $3,549 million, net of transaction costs and as adjusted for post-closing adjustments, and recorded a pretax gain of $2,271 million ($1,499 million after tax).

In June 2020, we completed the sale of our equity interests in our Chilean businesses, including our 100% interest in Chilquinta Energía and Tecnored and our 50% interest in Eletrans, to State Grid International Development Limited for cash proceeds of $2,216 million, net of transaction costs and as adjusted for post-closing adjustments, and recorded a pretax gain of $628 million ($248 million after tax).

In the three months and nine months ended September 30, 2020, the pretax gains from the sales of our South American businesses are included in (Loss) Gain on Sale of Discontinued Operations in the table below and the after-tax gains are included in (Loss) Income from Discontinued Operations, Net of Income Tax, on Sempra’s Condensed Consolidated Statements of Operations.

Summarized results from discontinued operations were as follows:

DISCONTINUED OPERATIONS
(Dollars in millions)
	Three months ended September 30, 2020(1)		Nine months ended September 30, 2020(2)
Revenues	$	—	$	570
Cost of sales	—		(364)
(Loss) gain on sale of discontinued operations	(16)		2,899
Operating expenses	—		(66)
Interest and other	—		(3)
Income before income taxes	(16)		3,036
Income tax benefit (expense)	9		(1,186)
(Loss) income from discontinued operations, net of income tax	(7)		1,850
Earnings attributable to noncontrolling interests	—		(10)
(Losses) earnings from discontinued operations attributable to Sempra	$	(7)	$	1,840

(1)    Represents post-closing adjustments related to the sale of our equity interests in our Chilean businesses.    

(2)    Results include activity until the sale of our Peruvian businesses on April 24, 2020 and Chilean businesses on June 24, 2020.

As a result of the sales of our South American businesses, in the second quarter of 2020, we reclassified $645 million of cumulative foreign currency translation losses from AOCI to (Loss) Gain on Sale of Discontinued Operations, which is included in (Loss) Income from Discontinued Operations, Net of Income Tax, on Sempra’s Condensed Consolidated Statements of Operations.

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INVESTMENTS IN UNCONSOLIDATED ENTITIES

9 Months Ended

Sep. 30, 2021

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 nine months ended September 30, 2021 and 2020, Sempra contributed $151 million and $209 million, respectively, to Oncor Holdings, and Oncor Holdings distributed $239 million and $220 million, respectively, to Sempra. Additionally, in the nine months ended September 30, 2021, Oncor Holdings distributed a $361 million return of investment to Sempra.

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

SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Operating revenues	$	1,286	$	1,232	$	3,572	$	3,394
Operating expenses	(866)		(819)		(2,531)		(2,387)
Income from operations	420		413		1,041		1,007
Interest expense	(104)		(102)		(308)		(305)
Income tax expense	(54)		(50)		(124)		(115)
Net income	255		255		587		557
Noncontrolling interest held by TTI	(51)		(50)		(118)		(111)
Earnings attributable to Sempra(1)	204		205		469		446

(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 MEXICO

ESJ

As we discuss in Note 5, in March 2021, IEnova completed the acquisition of the remaining 50% equity interest in ESJ and ESJ became a wholly owned, consolidated subsidiary. Prior to the acquisition date, IEnova owned 50% of ESJ and accounted for its interest as an equity method investment. In the nine months ended September 30, 2021 and 2020, ESJ distributed a $4 million and $8 million, respectively, return of investment to IEnova.

SEMPRA LNG

Cameron LNG JV

In the nine months ended September 30, 2021, Cameron LNG JV distributed to Sempra LNG $496 million, of which $165 million relates to the distribution from Cameron LNG JV’s SDSRA that we discuss below.

In the nine months ended September 30, 2020, Sempra LNG contributed $54 million to Cameron LNG JV, and Cameron LNG JV distributed to Sempra LNG $209 million and a return of investment of $803 million.

In March 2021, Cameron LNG JV reached financial completion of the three-train liquefaction project, and Sempra’s related guarantees for a maximum aggregate amount of $4.0 billion were terminated. We discuss these guarantees in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.

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 LNG 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 LNG from the SDSRA, or $165 million. We recorded a guarantee liability of $22 million in June 2021, with an associated carrying value of $22 million at September 30, 2021, for the fair value of the promissory note, which is being reduced over the duration of the guarantee through Sempra LNG’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 LNG 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 LNG’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 LNG 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 LNG 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 LNG 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 LNG.

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 LNG 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 September 30, 2021, the fair value of the Support Agreement was $5 million, of which $7 million is included in Other Current Assets offset by $2 million included in Deferred Credits and Other on Sempra’s Condensed Consolidated Balance Sheet.

PARENT AND OTHER

RBS Sempra Commodities

As we discuss in Note 11, in the nine months ended September 30, 2020, we recorded a charge of $100 million in Equity Earnings on Sempra’s Condensed Consolidated Statement of Operations representing our share of estimated losses in excess of the carrying value of our equity method investment in RBS Sempra Commodities. In the nine months ended September 30, 2021, we reduced this charge by $50 million based on the favorable outcome of a settlement with HMRC and revised assumptions on the High Court of Justice case.

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DEBT AND CREDIT FACILITIES

9 Months Ended

Sep. 30, 2021

Debt Disclosure [Abstract]

DEBT AND CREDIT FACILITIES

DEBT AND CREDIT FACILITIES

LINES OF CREDIT

Primary U.S. Committed Lines of Credit

In May 2021, Sempra Global assigned its $3.2 billion, five-year committed line of credit facility to Sempra and Sempra assumed all rights and responsibilities under the credit agreement. Also, in May 2021, Sempra established a commercial paper program to replace Sempra Global’s commercial paper program that was terminated in June 2021.

At September 30, 2021, Sempra had an aggregate capacity of $6.7 billion from primary U.S. committed lines of credit, which provide liquidity and support commercial paper. The principal terms of these committed lines of credit, which expire in May 2024, are described below and in Note 7 of the Notes to Consolidated Financial Statements in the Annual Report.

PRIMARY U.S. COMMITTED LINES OF CREDIT
(Dollars in millions)
	September 30, 2021
	Total facility		Commercial paper outstanding(1)(2)		Available unused credit
Sempra(3)	$	4,435	$	(2,112)	$	2,323
SDG&E(4)	1,500		—		1,500
SoCalGas(4)	750		—		750
Total	$	6,685	$	(2,112)	$	4,573

(1)    Because the commercial paper programs are supported by these lines, we reflect the amount of commercial paper outstanding as a reduction to the available unused credit.

(2)    Commercial paper outstanding is before reductions of a negligible amount of unamortized discount.

(3)    The facility also provides for issuance of $200 million of letters of credit on behalf of Sempra with the amount of borrowings otherwise available under the facility reduced by the amount of outstanding letters of credit. Subject to obtaining commitments from existing or new lenders and satisfaction of other specified conditions, Sempra has the right to increase the letter of credit commitment up to $500 million. No letters of credit were outstanding at September 30, 2021.

(4)    The facility also provides for issuance of $100 million of letters of credit on behalf of the borrowing utility with the amount of borrowings otherwise available under the facility reduced by the amount of outstanding letters of credit. Subject to obtaining commitments from existing or new lenders and satisfaction of other specified conditions, the borrowing utility has the right to increase the letter of credit commitment up to $250 million. No letters of credit were outstanding at September 30, 2021.

Sempra, SDG&E and SoCalGas each must maintain a ratio of indebtedness to total capitalization (as defined in each of the applicable credit facilities) of no more than 65% at the end of each quarter. At September 30, 2021, each entity was in compliance with this ratio under its respective credit facility.

Foreign Committed Lines of Credit

Our foreign operations in Mexico have committed lines of credit with an aggregate capacity of $1.9 billion at September 30, 2021. The principal terms of these committed lines of credit are described in Note 7 of the Notes to Consolidated Financial Statements in the Annual Report.

FOREIGN COMMITTED LINES OF CREDIT
(U.S. dollar equivalent in millions)
	September 30, 2021
Expiration date of facility	Total facility		Amounts outstanding		Available unused credit
February 2024	$	1,500	$	—	$	1,500
September 2023(1)	350		(294)		56
Total	$	1,850	$	(294)	$	1,556

(1)    In September 2021, IEnova amended this revolving credit facility to increase the amount available under the facility from $280 million to $350 million and extend the expiration of the facility from September 2021 to September 2023. Borrowings continue to bear interest at a per annum rate equal to 3-month LIBOR plus 54 bps.

Foreign Uncommitted Lines of Credit

In addition to our committed lines of credit, our foreign operations in Mexico have uncommitted lines of credit with an aggregate capacity of $470 million at September 30, 2021, which are generally used for working capital requirements.

FOREIGN UNCOMMITTED LINES OF CREDIT
(U.S. dollar equivalent in millions)
		September 30, 2021
Expiration date of facility	Borrowing denomination	Total facility		Amounts outstanding		Available unused credit
September 2022(1)	U.S. dollars	$	250	$	(250)	$	—
August 2023(2)	U.S. dollars or Mexican pesos	100		(37)		63
October 2023(3)	U.S. dollars	100		—		100
October 2023(4)	U.S. dollars or Mexican pesos	20		—		20
Total		$	470	$	(287)	$	183

(1)    IEnova’s one-year credit agreement under which borrowings bear interest at a per annum rate equal to 3-month LIBOR plus 10 bps.

(2)    ECA LNG Phase 1’s two-year credit agreement under which outstanding amounts were borrowed in Mexican pesos and bear interest at a variable rate based on the 28-day Interbank Equilibrium Interest Rate plus 105 bps and are before reductions from negligible unamortized discount. Borrowings made in U.S. dollars bear interest at a variable rate based on the 1-month or 3-month LIBOR plus 105 bps.

(3)    IEnova’s three-year credit agreement under which borrowings bear interest at a per annum rate equal to 6-month LIBOR plus 52 bps.

(4)    IEnova’s three-year credit agreement under which borrowings made in Mexican pesos bear interest at a variable rate based on the 28-day Interbank Equilibrium Interest Rate plus an applicable margin. Borrowings made in U.S. dollars bear interest at a variable rate based on 1-month LIBOR plus an applicable margin. The applicable margin is determined on the date of borrowing.

Letters of Credit

Outside of our domestic and foreign committed credit facilities, we have bilateral unsecured standby letter of credit capacity with select lenders that is uncommitted and supported by reimbursement agreements. At September 30, 2021, we had approximately $697 million in standby letters of credit outstanding under these agreements.

TERM LOAN

In June 2021, SDG&E entered into a $375 million, 364-day term loan with a maturity date of June 27, 2022. At September 30, 2021, $375 million, net of negligible issuance costs, was outstanding under the term loan. The borrowing bears interest at benchmark rates plus 62.5 bps. The term loan provides SDG&E with additional liquidity outside of its line of credit.

WEIGHTED-AVERAGE INTEREST RATES

The weighted-average interest rates on the total short-term debt at September 30, 2021 and December 31, 2020 were as follows:

WEIGHTED-AVERAGE INTEREST RATES
	September 30, 2021		December 31, 2020
Sempra	0.39	%	0.83	%
SDG&E	0.76		—
SoCalGas	—		0.14

LONG-TERM DEBT

SDG&E

In August 2021, SDG&E issued $750 million of 2.95% green first mortgage bonds maturing in 2051 and received proceeds of $737 million (net of debt discount, underwriting discounts and debt issuance costs of $13 million). SDG&E intends to use the net proceeds to finance or refinance eligible projects that fall into one or more of the following categories: climate change adaptation, clean energy solutions and clean transportation.

Sempra Mexico

As we discuss in Note 5, through its acquisition of ESJ, Sempra Mexico assumed a $177 million (net of $6 million in unamortized debt issuance costs) variable rate loan payable to a syndicate of five lenders that matures in June 2033. To moderate exposure to interest rate and associated cash flow variability, ESJ entered into floating-to-fixed rate swaps for 90% of the principal balance, resulting in a fixed rate of 6.13%. The remaining 10% of the principal balance bears interest at 6-month LIBOR plus a margin of 2.63% with an increase of 25 bps every four years (2.80% at September 30, 2021). On October 8, 2021, Sempra Mexico used proceeds from borrowings against its committed and uncommitted lines of credit to fully repay $175 million of outstanding principal plus accrued and unpaid interest on the ESJ loan prior to its scheduled maturity in 2033, and recognized approximately $16 million ($10 million after tax and NCI) in charges associated with hedge termination costs and a write-off of unamortized debt issuance costs.

On October 13, 2021, Sempra Mexico used proceeds from borrowings against its committed and uncommitted lines of credit to fully repay $375 million of outstanding principal plus accrued and unpaid interest on the Ventika fixed- and variable-rate loans prior to scheduled maturity dates through 2032, and recognized approximately $34 million ($20 million after tax and NCI) in charges associated with hedge termination costs and a write-off of unamortized debt issuance costs.

Sempra LNG

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. At September 30, 2021 and December 31, 2020, $291 million and $17 million, respectively, was outstanding, with a weighted-average interest rate of 2.84% and 2.82%, respectively. We discuss the details of this agreement in Note 7 of the Notes to Consolidated Financial Statements in the Annual Report.

Parent and Other

On November 1, 2021, Sempra issued notices to redeem, at respective make-whole redemption prices, an aggregate principal amount of $2.35 billion of senior unsecured notes prior to scheduled maturities in 2022 through 2025. Upon redemption, which is scheduled to occur in December 2021, we expect to recognize approximately $128 million ($93 million after tax) in charges associated with the make-whole premiums from the early redemptions and write-off of unamortized discount and debt issuance costs. As a result of our expected early redemption, this debt was classified as Current Portion of Long-Term Debt and Finance Leases on Sempra’s Condensed Consolidated Balance Sheet at September 30, 2021.

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DERIVATIVE FINANCIAL INSTRUMENTS

9 Months Ended

Sep. 30, 2021

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 have derivatives that are (1) cash flow hedges, (2) fair value hedges, or (3) undesignated. Depending on the applicability of hedge accounting and, for the California Utilities 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 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:

▪The California Utilities use natural gas and 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 Mexico and Sempra LNG 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 the California Utilities, may use other energy derivatives to hedge exposures such as the price of vehicle fuel and greenhouse gas allowances.

The following table summarizes net energy derivative volumes.

NET ENERGY DERIVATIVE VOLUMES
(Quantities in millions)
Commodity	Unit of measure	September 30, 2021	December 31, 2020
Sempra:
Natural gas	MMBtu	(14)	5
Electricity	MWh	1	1
Congestion revenue rights	MWh	48	43
SDG&E:
Natural gas	MMBtu	10	16
Electricity	MWh	1	1
Congestion revenue rights	MWh	48	43
SoCalGas:
Natural gas	MMBtu	—	1

In addition to the amounts noted above, we use commodity derivatives to manage risks associated with the physical locations of contractual obligations and assets, such as natural gas purchases and sales.

INTEREST RATE DERIVATIVES

We are exposed to interest rates primarily as a result of our current and expected use of financing. The California Utilities, 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 JVs.

INTEREST RATE DERIVATIVES
(Dollars in millions)
	September 30, 2021			December 31, 2020
	Notional debt		Maturities	Notional debt		Maturities
Sempra:
Cash flow hedges	$	747	2021-2034	$	1,486	2021-2034

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 variable interest rates for U.S. fixed interest rates. From time to time, Sempra Mexico 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.

We also utilized foreign currency derivatives in 2020 to hedge exposure to fluctuations in the Peruvian sol and Chilean peso related to the sales of our operations in Peru and Chile, respectively.

The following table presents the net notional amounts of our foreign currency derivatives, excluding JVs.

FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	September 30, 2021			December 31, 2020
	Notional amount		Maturities	Notional amount		Maturities
Sempra:
Cross-currency swaps	$	306	2021-2023	$	306	2021-2023
Other foreign currency derivatives	130		2021-2023	1,764		2021-2022

FINANCIAL STATEMENT PRESENTATION

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

DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	September 30, 2021
	Other current assets(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	$	—	$	6	$	(42)	$	(134)
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	252		19		(300)		(21)
Associated offsetting commodity contracts	(225)		(15)		225		15
Associated offsetting cash collateral	—		—		11		—
Commodity contracts subject to rate recovery	50		76		(52)		(3)
Associated offsetting commodity contracts	(4)		—		4		—
Net amounts presented on the balance sheet	73		86		(154)		(143)
Additional cash collateral for commodity contracts not subject to rate recovery	47		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	30		—		—		—
Total(2)	$	150	$	86	$	(154)	$	(143)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	47	$	76	$	(18)	$	(2)
Associated offsetting commodity contracts	(3)		—		3		—
Net amounts presented on the balance sheet	44		76		(15)		(2)
Additional cash collateral for commodity contracts subject to rate recovery	28		—		—		—
Total(2)	$	72	$	76	$	(15)	$	(2)
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	3	$	—	$	(34)	$	(1)
Associated offsetting commodity contracts	(1)		—		1		—
Net amounts presented on the balance sheet	2		—		(33)		(1)
Additional cash collateral for commodity contracts subject to rate recovery	2		—		—		—
Total	$	4	$	—	$	(33)	$	(1)

(1)    Included in Current Assets: Fixed-Price Contracts and Other Derivatives for SDG&E.

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

DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	December 31, 2020
	Other current assets(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	$	—	$	1	$	(26)	$	(160)
Derivatives not designated as hedging instruments:
Foreign exchange instruments	24		—		—		—
Commodity contracts not subject to rate recovery	82		17		(95)		(16)
Associated offsetting commodity contracts	(82)		(13)		82		13
Commodity contracts subject to rate recovery	35		95		(35)		(25)
Associated offsetting commodity contracts	(2)		—		2		—
Net amounts presented on the balance sheet	57		100		(72)		(188)
Additional cash collateral for commodity contracts not subject to rate recovery	21		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	30		—		—		—
Total(2)	$	108	$	100	$	(72)	$	(188)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	32	$	95	$	(28)	$	(25)
Associated offsetting commodity contracts	(1)		—		1		—
Net amounts presented on the balance sheet	31		95		(27)		(25)
Additional cash collateral for commodity contracts subject to rate recovery	24		—		—		—
Total(2)	$	55	$	95	$	(27)	$	(25)
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	3	$	—	$	(7)	$	—
Associated offsetting commodity contracts	(1)		—		1		—
Net amounts presented on the balance sheet	2		—		(6)		—
Additional cash collateral for commodity contracts subject to rate recovery	6		—		—		—
Total	$	8	$	—	$	(6)	$	—

(1)    Included in Current Assets: Fixed-Price Contracts and Other Derivatives for SDG&E.

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

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

CASH FLOW HEDGE IMPACTS
(Dollars in millions)
	Pretax gain (loss) recognized in OCI					Pretax gain (loss) reclassified from AOCI into earnings
	Three months ended September 30,					Three months ended September 30,
	2021		2020		Location	2021		2020
Sempra:
Interest rate instruments	$	7	$	8	Interest Expense	$	1	$	(3)
Interest rate instruments	3		25		Equity Earnings(1)	(19)		(5)
Foreign exchange instruments	5		(2)		Revenues: Energy- Related Businesses	—		—
Foreign exchange instruments	3		(1)		Equity Earnings(1)	—		—
Interest rate and foreign exchange instruments	(3)		6		Other (Expense) Income, Net	(5)		4
Total	$	15	$	36		$	(23)	$	(4)
	Nine months ended September 30,					Nine months ended September 30,
	2021		2020		Location	2021		2020
Sempra:
Interest rate instruments	$	27	$	(42)	Interest Expense	$	—	$	(6)
Interest rate instruments	54		(175)		Equity Earnings(1)	(57)		(8)
Foreign exchange instruments	7		14		Revenues: Energy- Related Businesses	(1)		2
					Other (Expense) Income, Net	—		1
Foreign exchange instruments	5		9		Equity Earnings(1)	(1)		2
Interest rate and foreign exchange instruments	(2)		(31)		Interest Expense	—		(1)
					Other (Expense) Income, Net	(4)		(33)
Total	$	91	$	(225)		$	(63)	$	(43)

(1)    Equity earnings at Sempra Mexico are recognized after tax.

For Sempra, we expect that net losses of $104 million, which are 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. SoCalGas expects that $1 million of losses, net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. Actual amounts ultimately reclassified into earnings depend on the interest rates in effect when derivative contracts mature.

For all forecasted transactions, the maximum remaining term over which we are hedging exposure to the variability of cash flows at September 30, 2021 is approximately 13 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 18 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 September 30,				Nine months ended September 30,
	Location	2021		2020		2021		2020
Sempra:
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	$	(154)	$	(39)	$	(344)	$	25
Commodity contracts subject to rate recovery	Cost of Natural Gas	(26)		—		(24)		(6)
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	8		41		51		41
Foreign exchange instruments	Other (Expense) Income, Net	2		15		(22)		(97)
Total		$	(170)	$	17	$	(339)	$	(37)
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	8	$	41	$	51	$	41
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas	$	(26)	$	—	$	(24)	$	(6)

CONTINGENT FEATURES

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

For Sempra, the total fair value of this group of derivative instruments in a liability position at September 30, 2021 and December 31, 2020 was $63 million and $16 million, respectively. For SoCalGas, the total fair value of this group of derivative instruments in a liability position at September 30, 2021 and December 31, 2020 was $34 million and $6 million, respectively. At September 30, 2021, if the credit ratings of Sempra or SoCalGas were reduced below investment grade, $63 million and $34 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

9 Months Ended

Sep. 30, 2021

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

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

RECURRING FAIR VALUE MEASURES

The three tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis at September 30, 2021 and December 31, 2020. 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, 2020.

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 cash balances, 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 marketable securities 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). These investments in marketable securities were negligible at both September 30, 2021 and December 31, 2020.

▪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 LNG.”

RECURRING FAIR VALUE MEASURES – SEMPRA
(Dollars in millions)
	Fair value at September 30, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	350	$	6	$	—	$	356
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	40		12		—		52
Municipal bonds	—		320		—		320
Other securities	—		270		—		270
Total debt securities	40		602		—		642
Total nuclear decommissioning trusts(1)	390		608		—		998
Interest rate and foreign exchange instruments	—		6		—		6
Commodity contracts not subject to rate recovery	—		31		—		31
Effect of netting and allocation of collateral(2)	47		—		—		47
Commodity contracts subject to rate recovery	32		2		88		122
Effect of netting and allocation of collateral(2)	24		—		6		30
Support Agreement, net of related guarantee fees	—		—		7		7
Total	$	493	$	647	$	101	$	1,241
Liabilities:
Interest rate and foreign exchange instruments	$	—	$	176	$	—	$	176
Commodity contracts not subject to rate recovery	—		81		—		81
Effect of netting and allocation of collateral(2)	—		(11)		—		(11)
Commodity contracts subject to rate recovery	—		35		16		51
Support Agreement, net of related guarantee fees	—		—		2		2
Total	$	—	$	281	$	18	$	299
	Fair value at December 31, 2020
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	358	$	6	$	—	$	364
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	41		24		—		65
Municipal bonds	—		326		—		326
Other securities	—		270		—		270
Total debt securities	41		620		—		661
Total nuclear decommissioning trusts(1)	399		626		—		1,025
Interest rate and foreign exchange instruments	—		25		—		25
Commodity contracts not subject to rate recovery	—		4		—		4
Effect of netting and allocation of collateral(2)	21		—		—		21
Commodity contracts subject to rate recovery	6		1		121		128
Effect of netting and allocation of collateral(2)	19		5		6		30
Support Agreement, net of related guarantee fees	—		—		7		7
Total	$	445	$	661	$	134	$	1,240
Liabilities:
Interest rate and foreign exchange instruments	$	—	$	186	$	—	$	186
Commodity contracts not subject to rate recovery	—		16		—		16
Commodity contracts subject to rate recovery	—		6		52		58
Support Agreement, net of related guarantee fees	—		—		4		4
Total	$	—	$	208	$	56	$	264

(1)    Excludes cash, cash equivalents and 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 September 30, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	350	$	6	$	—	$	356
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	40		12		—		52
Municipal bonds	—		320		—		320
Other securities	—		270		—		270
Total debt securities	40		602		—		642
Total nuclear decommissioning trusts(1)	390		608		—		998
Commodity contracts subject to rate recovery	32		—		88		120
Effect of netting and allocation of collateral(2)	22		—		6		28
Total	$	444	$	608	$	94	$	1,146
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	1	$	16	$	17
Total	$	—	$	1	$	16	$	17
	Fair value at December 31, 2020
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	358	$	6	$	—	$	364
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	41		24		—		65
Municipal bonds	—		326		—		326
Other securities	—		270		—		270
Total debt securities	41		620		—		661
Total nuclear decommissioning trusts(1)	399		626		—		1,025
Commodity contracts subject to rate recovery	5		—		121		126
Effect of netting and allocation of collateral(2)	18		—		6		24
Total	$	422	$	626	$	127	$	1,175
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	—	$	52	$	52
Total	$	—	$	—	$	52	$	52

(1)    Excludes cash, cash equivalents and 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 September 30, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	—	$	2	$	—	$	2
Effect of netting and allocation of collateral(1)	2		—		—		2
Total	$	2	$	2	$	—	$	4
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	34	$	—	$	34
Total	$	—	$	34	$	—	$	34
	Fair value at December 31, 2020
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	1	$	1	$	—	$	2
Effect of netting and allocation of collateral(1)	1		5		—		6
Total	$	2	$	6	$	—	$	8
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	6	$	—	$	6
Total	$	—	$	6	$	—	$	6

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

Level 3 Information

SDG&E

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

LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)
	Three months ended September 30,
	2021		2020
Balance at July 1	$	80	$	17
Realized and unrealized losses	(35)		(4)
Allocated transmission instruments	1		1
Settlements	26		19
Balance at September 30	$	72	$	33
Change in unrealized gains (losses) relating to instruments still held at September 30	$	9	$	7
	Nine months ended September 30,
	2021		2020
Balance at January 1	$	69	$	28
Realized and unrealized losses	(29)		(18)
Allocated transmission instruments	(1)		2
Settlements	33		21
Balance at September 30	$	72	$	33
Change in unrealized gains (losses) relating to instruments still held at September 30	$	5	$	(1)

(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
2021	$	(1.81)	to	$	14.11	$	(0.12)
2020	(3.77)		to	6.03		(1.58)

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 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 September 30 were as follows:

LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS
Settlement year	Price per MWh					Weighted-average price per MWh
2021	$	24.05	to	$	130.40	$	57.36
2020		19.45	to		71.25		38.14

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 LNG

The table below sets forth a reconciliation 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 RECONCILIATION
(Dollars in millions)
	Three months ended September 30,
	2021		2020
Balance at July 1	$	4	$	—
Realized and unrealized gains(1)	3		7
Settlements	(2)		(1)
Balance at September 30(2)	$	5	$	6
Change in unrealized gains (losses) relating to instruments still held at September 30	$	3	$	6
	Nine months ended September 30,
	2021		2020
Balance at January 1	$	3	$	—
Realized and unrealized gains(1)	8		7
Settlements	(6)		(1)
Balance at September 30(2)	$	5	$	6
Change in unrealized gains (losses) relating to instruments still held at September 30	$	7	$	6

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

(2)    Includes $7 million in Other Current Assets offset by $2 million in Deferred Credits and Other at September 30, 2021 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.

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SAN ONOFRE NUCLEAR GENERATING STATION

9 Months Ended

Sep. 30, 2021

Regulated Operations [Abstract]

SAN ONOFRE NUCLEAR GENERATING STATION

REGULATORY MATTERSWe discuss regulatory matters in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report and provide updates to those discussions and information about new regulatory matters below. With the exception of regulatory balancing accounts, we generally do not earn a return on our regulatory assets until such time as a related cash expenditure has been made. Upon the occurrence of a cash expenditure associated with a regulatory asset, the related amounts are recoverable through a regulatory account mechanism for which we earn a return authorized by applicable regulators, which currently 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 AND LIABILITIES

We show the details of regulatory assets and liabilities in the following table.

REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	September 30, 2021		December 31, 2020
SDG&E:
Fixed-price contracts and other derivatives	$	(88)	$	(53)
Deferred income taxes recoverable in rates	72		22
Pension and other postretirement benefit plan obligations	19		50
Removal obligations	(2,228)		(2,121)
Environmental costs	55		56
Sunrise Powerlink fire mitigation	121		121
Regulatory balancing accounts(1)(2)
Commodity – electric	85		72
Gas transportation	23		35
Safety and reliability	60		67
Public purpose programs	(138)		(158)
2019 GRC retroactive impacts	14		56
Other balancing accounts	535		233
Other regulatory assets, net(2)	110		72
Total SDG&E	(1,360)		(1,548)
SoCalGas:
Deferred income taxes recoverable (refundable) in rates	9		(82)
Pension and other postretirement benefit plan obligations	342		417
Employee benefit costs	37		37
Removal obligations	(649)		(685)
Environmental costs	35		36
Regulatory balancing accounts(1)(2)
Commodity – gas, including transportation	(138)		(56)
Safety and reliability	299		335
Public purpose programs	(274)		(253)
2019 GRC retroactive impacts	51		202
Other balancing accounts	85		(58)
Other regulatory assets, net(2)	160		75
Total SoCalGas	(43)		(32)
Sempra Mexico:
Deferred income taxes recoverable in rates	80		80
Total Sempra	$	(1,323)	$	(1,500)

(1)    At September 30, 2021 and December 31, 2020, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $331 million and $139 million, respectively, and for SoCalGas was $472 million and $218 million, respectively.

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

CALIFORNIA UTILITIES

COVID-19 Pandemic Protections

In connection with the COVID-19 pandemic, the California Utilities implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for all customers (except for SoCalGas’ noncore customers), waiving late payment fees, and offering flexible payment plans. Such measures ended on June 30, 2021, except for the suspension of service disconnections that ended on September 30, 2021. At the CPUC’s direction, the California Utilities have started to automatically enroll residential and small business customers with past-due balances in long-term repayment plans. The CPUC is continuing to consider the impacts of any state or federal relief programs on customer arrearages and if further debt relief is warranted.

Each of the California Utilities has been authorized to track and request recovery of incremental costs associated with complying with customer protection measures implemented by the CPUC related to the COVID-19 pandemic, including costs associated

with suspending service disconnections and uncollectible expenses that arise from customers’ failure to pay. The California Utilities expect to pursue recovery of small and medium-large commercial and industrial customers’ tracked costs in rates in a future CPUC proceeding, which recovery is not assured. Uncollectible expenses related to residential customers are recorded in a two-way balancing account as we discuss below.

Disconnection OIR

In June 2020, the CPUC issued a decision to adopt certain customer protections to reduce residential customer disconnections and improve reconnection processes, including, among other things, imposing limitations on service disconnections, elimination of deposit requirements and reconnection fees, establishment of the AMP that provides successfully participating, income-qualified residential customers with relief from outstanding utility bill amounts, and increased outreach and marketing efforts. As permitted by the decision, each of the California Utilities has established a two-way balancing account to record the uncollectible expenses associated with residential customers’ inability to pay their electric or gas bills, including as a result of the relief from outstanding utility bill amounts provided under the AMP.

CPUC GRC

The CPUC uses GRCs to set rates designed to allow the California Utilities to recover their reasonable operating costs and to provide the opportunity to realize their authorized rates of return on their investments.

In January 2020, the CPUC issued a final decision implementing a four-year GRC cycle for California IOUs and the California Utilities were directed to file a petition for modification to revise their 2019 GRC to add two additional attrition years, resulting in a transitional five-year GRC period (2019-2023). The California Utilities filed the petition in April 2020.

In May 2021, the CPUC issued a final decision approving the California Utilities’ request to continue their authorized post-test year mechanisms for 2022 and 2023. For SDG&E, the decision authorizes revenue requirement increases of $87 million (3.92%) for 2022 and $86 million (3.70%) for 2023. For SoCalGas, the decision authorizes revenue requirement increases of $142 million (4.53%) for 2022 and $130 million (3.97%) for 2023.

The 2019 GRC FD clarified that differences between incurred and forecasted income tax expense due to forecasting differences are not subject to tracking in the income tax expense memorandum account beginning in 2019. SDG&E and SoCalGas previously recorded regulatory liabilities, inclusive of interest, associated with the 2016 through 2018 tracked forecasting differences of $86 million and $89 million, respectively. In April 2020, the CPUC confirmed treatment of the two-way income tax expense memorandum account for these 2016 through 2018 balances, at which time the California Utilities released these regulatory liability balances to revenues and regulatory interest.

We provide additional information concerning the 2019 GRC FD in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report.

CPUC Cost of Capital

A CPUC cost of capital proceeding determines a utility’s authorized capital structure and authorized return on rate base. In December 2019, the CPUC approved the cost of capital and rate structures 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. The CCM considers 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. 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.

Alternatively, under the CCM, each of the California Utilities 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. In August 2021, SDG&E filed an application with the CPUC to update its cost of capital effective January 1, 2022 due to the ongoing effects of the COVID-19 pandemic. In this application, SDG&E proposed to adjust its authorized capital structure by increasing its common equity ratio from 52% to 54%. SDG&E also proposed to increase its authorized ROE from 10.20% to 10.55% and decrease its authorized cost of debt from 4.59% to 3.84%. As a result, SDG&E’s proposed return on rate base would decrease from 7.55% to 7.46% if such application is approved by the CPUC as filed. SDG&E filed a joint motion with PG&E and Edison to consolidate all three utilities’ cost of capital applications given the overlapping issues of law and fact, which joint motion was granted in October 2021.

For the measurement period ended September 30, 2021, the CCM would trigger for SDG&E 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%. However, SDG&E’s application to update its cost of capital effective January 1, 2022, if accepted by the CPUC, would supersede the CCM from applying. If such application is not accepted, the CCM would be effective 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. SDG&E has requested that a final CPUC decision on its interim cost of capital application be issued in the first half of 2022.

For the measurement period ended September 30, 2021, the CCM was not triggered for SoCalGas. SoCalGas expects to file its next cost of capital application in April 2022 for a January 1, 2023 effective date.

SDG&E

FERC Rate Matters and Cost of Capital

SDG&E files separately with the FERC for its authorized ROE on FERC-regulated electric transmission operations and assets.

SDG&E’s TO4 ROE of 10.05% was the basis of SDG&E’s FERC-related revenue recognition until March 2020, when the FERC approved the settlement terms that SDG&E and all settling parties reached in October 2019 on SDG&E’s TO5 filing. The settlement agreement provided for a ROE of 10.60%, consisting of a base ROE of 10.10% plus an additional 50 bps for participation in the California ISO (the California ISO adder). If the FERC issues an order ruling that California IOUs are no longer eligible for the California ISO adder, SDG&E would refund the California ISO adder as of the refund effective date (June 1, 2019) if such a refund is determined to be required by the terms of the TO5 settlement. The TO5 term is effective June 1, 2019 and shall remain in effect each calendar year until terminated by a notice at least six months before the end of a calendar year. In the first quarter of 2020, SDG&E recorded retroactive revenues of $12 million related to 2019, and additional FERC revenues of $17 million to conclude a rate base matter, net of certain refunds to be paid to CPUC-jurisdictional customers.

Energy Efficiency Program Inquiry

In January 2020, the CPUC issued a ruling seeking comments on a report prepared by its consultant regarding SDG&E’s Upstream Lighting Program for the program year 2017. The CPUC subsequently expanded the scope of the comments to cover the program year 2018. The Upstream Lighting Program was one of SDG&E’s Energy Efficiency Programs designed to produce energy efficiency savings for which SDG&E could earn a performance-based incentive.

Pursuant to the CPUC ruling, intervenors representing ratepayers questioned SDG&E’s management of the program and alleged that certain program expenditures did not benefit the purpose of the program. As a result of the inquiry, SDG&E voluntarily expanded its review to include the program year 2019. Based on this review, SDG&E concluded some concessions were appropriate, which included refunding certain costs to customers and reducing certain performance-based incentives. Accordingly, in the three months and nine months ended September 30, 2020, SDG&E reduced revenues by $36 million and $51 million, respectively, and recorded a fine of $6 million in Other (Expense) Income, Net, on the SDG&E and Sempra Condensed Consolidated Statements of Operations. The after-tax impact for the three months and nine months ended September 30, 2020 was $29 million and $44 million, respectively. In October 2020, SDG&E executed a settlement agreement with intervenors consistent with these concessions. In September 2021, the CPUC approved the settlement agreement.

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. The OSC stemmed from a short period of transitional energy efficiency (EE) codes and standards advocacy activities undertaken by SoCalGas in 2018, following a CPUC decision disallowing SoCalGas’ future engagement in EE statewide codes and standards advocacy. We are awaiting a CPUC decision.

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, whether its shareholders should bear the costs of those advocacy activities, and to address whether any other remedies are appropriate. The scope of this OSC was later expanded to include EE program years 2014 and 2015, and SoCalGas’ engagement with local governments on proposed reach codes. In April 2021, the assigned Administrative Law Judge issued a Presiding Officer’s Decision (POD) on the second OSC. The POD 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. The POD, which is currently under appeal by intervenors, orders customer refunds that SoCalGas expects will be negligible (subject to a CPUC audit). Additionally, the POD precludes SoCalGas

from seeking cost recovery associated with EE codes and standards advocacy programs until lifted by the CPUC, and orders certain nonfinancial remedies.

Intervenors in these OSCs have suggested the CPUC order various financial and non-financial penalties. If the CPUC were to assess fines or penalties on SoCalGas associated with these OSCs, they could be material.

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.

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 September 2020, the foundation filed another writ petition under the California Coastal Act in LA Superior Court seeking to set aside the California Coastal Commission’s July 2020 approval of the inspection and maintenance plan for the SONGS’ canisters and to obtain injunctive relief to stop decommissioning work. A trial date for this petition has been set for April 2022. To date, decommissioning work has not been interrupted as a result of these writ petitions.

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. The amounts 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 2020, SDG&E received authorization from the CPUC to access NDT funds of up to $89 million for forecasted 2021 costs.

The following table shows the fair values and gross unrealized gains and losses for the securities held in the NDT. 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
At September 30, 2021:
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	52	$	—	$	—	$	52
Municipal bonds(2)	307		14		(1)		320
Other securities(3)	261		10		(1)		270
Total debt securities	620		24		(2)		642
Equity securities	103		255		(2)		356
Cash and cash equivalents	7		—		—		7
Payables, net	(2)		—		—		(2)
Total	$	728	$	279	$	(4)	$	1,003
At December 31, 2020:
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	$	64	$	1	$	—	$	65
Municipal bonds	308		18		—		326
Other securities	253		17		—		270
Total debt securities	625		36		—		661
Equity securities	112		254		(2)		364
Cash and cash equivalents	3		—		—		3
Payables, net	(9)		—		—		(9)
Total	$	731	$	290	$	(2)	$	1,019

(1)    Maturity dates are 2021-2051.

(2)    Maturity dates are 2022-2056.

(3)    Maturity dates are 2021-2072.

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 NDT
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Proceeds from sales	$	187	$	294	$	729	$	1,091
Gross realized gains	9		9		48		108
Gross realized losses	(1)		(2)		(4)		(13)

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 AND SPENT NUCLEAR FUEL

The present value of SDG&E’s ARO related to decommissioning costs for the SONGS units was $551 million at September 30, 2021. That amount includes the cost to decommission Units 2 and 3, and the remaining cost to complete the decommissioning of Unit 1, which is substantially complete. The ARO for all three units is based on a cost study prepared in 2017 that is pending CPUC approval. The ARO for Units 2 and 3 reflects the acceleration of the start of decommissioning of these units as a result of the early closure of the plant. SDG&E’s share of total decommissioning costs in 2021 dollars is approximately $886 million.

NUCLEAR INSURANCE

SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. Currently, this insurance provides $450 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides an additional $110 million of coverage. If a nuclear liability loss occurs at SONGS and exceeds the $450 million insurance limit, this additional coverage would be available to provide a total of $560 million in coverage limits per incident.

The SONGS co-owners have nuclear property damage insurance of $130 million, which exceeds the minimum federal requirements 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 $4.3 million of retrospective premiums based on overall member claims.

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

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COMMITMENTS AND CONTINGENCIES

9 Months Ended

Sep. 30, 2021

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

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, cash flows, results of operations, financial condition and/or prospects. Unless otherwise indicated, we are unable to estimate reasonably possible losses or a range of losses in excess of any amounts accrued.

At September 30, 2021, loss contingency accruals for legal matters, including associated legal fees and regulatory matters related to the Leak, that are probable and estimable were $2,076 million for Sempra, including $1,998 million for SoCalGas. Amounts for Sempra and SoCalGas include $1,973 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 Estimates, Accounting Impact and Insurance.”

Civil Litigation – Litigation Subject to Agreements to Resolve. As of November 1, 2021, 416 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, wrongful death and violations of Proposition 65 against SoCalGas and Sempra (excluding the Proposition 65 claims, the Individual Plaintiff Litigation). 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.

On September 26, 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 by June 1, 2022, although SoCalGas and Sempra have the right to waive such condition. 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 agreement is further subject to LA Superior Court approval of the process to allocate payments among the plaintiffs and a stay of the Individual Plaintiff Litigation. The plaintiffs who do not agree to participate in the settlement will be able to continue to pursue their claims.

In January 2017, two consolidated class action complaints were filed against SoCalGas and Sempra, one on behalf of a putative class of persons and businesses who own or lease real property within a five-mile radius of the well (the Property Class Action), and a second on behalf of a putative class of all persons and entities conducting business within five miles of the facility (the Business 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. The Business Class Action asserts a claim for violation of the California Unfair Competition Law. Both complaints seek compensatory, statutory and punitive damages, injunctive relief and attorneys’ fees.

On September 26, 2021, SoCalGas and Sempra entered into an agreement to settle the Property Class Action for a total amount of $40 million. If, following a fairness hearing at which any objections to the settlement will be heard, the LA Superior Court gives final approval of the settlement, the agreement provides for a release of SoCalGas, Sempra and their respective affiliates from all claims related to the Leak by all property class members who do not opt out of the class. Members of the property class who opt out of the settlement will have the right to pursue their claims on an individual basis.

On September 27, 2021, SoCalGas and Sempra entered into an agreement to settle the individual claims of the named plaintiffs in the Business Class Action for a total amount of $100,000 in exchange for a dismissal and release of SoCalGas, Sempra and their respective affiliates from all claims related to the Leak.

The Third Amended Consolidated Master Case Complaint for Individual Actions includes claims for violation of Proposition 65 seeking penalties for alleged violation of requirements to warn about certain chemical exposures as a result of the Leak. On November 4, 2021, SoCalGas entered into an agreement to settle these claims for a payment of approximately $2 million; in

addition, SoCalGas agreed to implement certain measures to reduce emissions at the Aliso Canyon natural gas storage facility and to provide warnings to residents if benzene measured at the facility’s fence line exceeds certain levels. The settlement of these claims requires the approval of the LA Superior Court.

An adverse ruling in any of the lawsuits in the Individual Plaintiff Litigation filed by plaintiffs who do not agree to settle, any lawsuits filed by property class members who opt out of the Property Class Action settlement or by members of the putative Business Class Action, or the Proposition 65 claims described above if that settlement is not approved by the court, could have a material adverse effect on SoCalGas’ and Sempra’s cash flows, financial condition and results of operations. In addition, there can be no assurance that the conditions to resolve the Individual Plaintiff Litigation will be satisfied or that the LA Superior Court will approve the settlement for the Property Class Action.

In addition, a federal securities class action alleging violation of the federal securities laws was filed against Sempra and certain of its officers in July 2017 in the U.S. District Court for the Southern District of California. In March 2018, the court dismissed the action with prejudice, and in February 2021, the U.S. Court of Appeals for the Ninth Circuit affirmed the dismissal. The time for appeal has passed and, as a result, this represents the final judgment in this proceeding.

Civil Litigation – Unresolved Litigation. Five property developers filed complaints in July and October of 2018 against SoCalGas and Sempra alleging causes of action for strict liability, negligence per se, negligence, continuing nuisance, permanent nuisance and violation of the California Unfair Competition Law, as well as claims for negligence against certain directors of SoCalGas. The complaints seek compensatory, statutory and punitive damages, injunctive relief and attorneys’ fees. The LA Superior Court has scheduled a trial for one or more of the developers in February 2022.

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 filed a notice of appeal. The remaining action was also dismissed but plaintiffs were given leave to amend their complaint.

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 Safety Enforcement Division (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. 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 sufficiently cooperate 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 2020, the CPUC issued a decision on the interim range of gas inventory levels at the Aliso Canyon natural gas storage facility, setting the interim range between 0 Bcf and 34 Bcf. In November 2021, the CPUC issued a decision approving a new 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 September 30, 2021, the Aliso Canyon natural gas storage facility had a net book value of $863 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 and cash flows.

Cost Estimate, Accounting Impact and Insurance. SoCalGas has incurred significant costs 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 September 30, 2021, SoCalGas estimates these costs related to the Leak are $3,199 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. A portion of the cost estimate has been paid, and $1,976 million is accrued as Reserve for Aliso Canyon Costs at September 30, 2021 on SoCalGas’ and Sempra’s Condensed Consolidated Balance Sheets.

In the first quarter of 2020, SoCalGas recorded $277 million in costs, inclusive of estimated legal costs, related to settlement discussions in connection with civil litigation described above. Of this amount, $177 million was recorded in Insurance Receivable for Aliso Canyon Costs on the SoCalGas and Sempra Condensed Consolidated Balance Sheets and $100 million ($72 million after tax) was recorded in Aliso Canyon Litigation and Regulatory Matters on the SoCalGas and Sempra Condensed Consolidated Statements of Operations. In the third quarter of 2020, SoCalGas recorded an additional charge of $27 million ($22 million after tax) related to the OII described above in “Regulatory Proceedings.”

As a result of entering into the September 26 and 27, 2021 agreements described above, SoCalGas recorded an additional charge of $1.57 billion ($1.13 billion after tax) in the third quarter of 2021 in Aliso Canyon Litigation and Regulatory Matters on the SoCalGas and Sempra Condensed Consolidated Statements of Operations. Sempra has elected to make equity contributions to SoCalGas that are sufficient to maintain SoCalGas’ approved capital structure in connection with the accruals related to these agreements. In connection with this election, in September 2021, Sempra made an initial equity contribution of $800 million to SoCalGas.

Except for the amounts paid or estimated to settle certain legal and regulatory matters as described above, the cost estimate does not include 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. These costs or losses not included in the cost estimate could be significant and could have a material adverse effect on SoCalGas’ and Sempra’s cash flows, financial condition and results of operations.

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 September 30, 2021, we recorded the expected recovery of the cost estimate related to the Leak of $414 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 $865 million of insurance proceeds we received through September 30, 2021. 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, which could be significant, could have a material adverse effect on SoCalGas’ and Sempra’s cash flows, financial condition and results of operations.

Sempra Mexico

Energía Costa Azul

We describe below certain land and customer disputes and permit challenges affecting our ECA Regas Facility and our proposed ECA LNG liquefaction projects. 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, cash flows, financial condition, results of operations and/or prospects.

Land Disputes. IEnova 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 IEnova 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.

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. We expect the plaintiff may appeal.

▪The second disputed area is one 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, the ECA Regas Facility bought the property a second time in 2008 from the plaintiff. 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. IEnova appealed the ruling in July 2021, which is pending resolution. 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 decision was affirmed on 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.

Certain of these land disputes involve land on which portions of the ECA LNG liquefaction facilities, including ECA LNG Phase 1 currently under construction, 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.

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; therefore, the natural gas liquefaction activities have not been affected.

▪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 case is awaiting proceedings.

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 IEnova and a force majeure event. Citing these circumstances, the customers subsequently stopped making payments of amounts due under their respective LNG storage and regasification agreements. IEnova has rejected the customers’ assertions and has drawn on the customers’ letters of credit provided as payment security. The parties engaged in discussions under the applicable contractual dispute resolution procedures without coming to a mutually acceptable resolution. In July 2020, Shell Mexico submitted a request for arbitration of the dispute and although Gazprom has joined the proceeding, Gazprom has since replenished the amounts drawn on its letter of credit and has resumed making regular monthly payments under its LNG storage and regasification agreement. As a consequence, IEnova is not currently drawing on Gazprom’s letter of credit but expects to continue to draw on Shell Mexico’s letter of credit. IEnova intends to avail itself of its available claims, defenses, rights and remedies in the arbitration proceeding, including seeking dismissal of the customers’ claims. In addition to the arbitration proceeding, Shell Mexico also filed a constitutional challenge to the CRE’s approval of the update to the general terms and conditions and an additional constitutional claim against the issuance of the liquefaction permit. Shell Mexico’s request to stay the CRE’s approval of the general terms and conditions was denied in October 2020 and upheld on appeal. A decision on the merits is pending. The claim regarding the liquefaction permit issuance was denied in March 2021 and upheld on appeal. A hearing on the merits of the arbitration case was held in October 2021.

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, cash flows, financial condition, results of operations and/or prospects.

Sonora Pipeline

Guaymas-El Oro Segment. IEnova’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, IEnova 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, IEnova 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, IEnova 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 IEnova from making repairs to put the pipeline back in service. In July 2019, a federal district court ruled in favor of IEnova 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 IEnova 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.

IEnova 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 IEnova 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, IEnova and the CFE agreed to extend the service start date multiple times, most recently to March 14, 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 March 14, 2022, and the parties do not agree on a new service start date, IEnova retains the right to terminate the contract and seek to recover its reasonable and documented costs and lost profits.

At September 30, 2021, Sempra Mexico had $436 million in PP&E, net, related to the Guaymas-El Oro segment of the Sonora pipeline, which could be subject to impairment if IEnova is unable to make such repairs (which have not commenced) or re-route the pipeline (which has not been agreed to by the parties) and resume operations in the Guaymas-El Oro segment of the Sonora pipeline or if IEnova 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, IEnova 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. IEnova intends to file a special judicial action whereby it will ask a civil court to acknowledge the existence of the easement and to determine the consideration the landowner should receive in exchange for the easement. The failure to stay this judgment pending the resolution of IEnova’s planned special judicial action or prevail in preserving the easement in the special judicial action could require us to modify the route of the pipeline and could require a temporary shutdown of this portion of the pipeline, which 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

We describe below certain actions by the Mexican government that could have a material impact on the energy sector in Mexico. IEnova 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. If passed in its current form, the proposed constitutional reform described below introduces significant changes to the legal and economic principles underlying the country’s energy reform of 2013, generating imminent risks for private investments in this sector. An unfavorable decision on one or more of these amparo or other challenges, the potential for extended disputes, or if passed in its current form, the proposed constitutional reform may impact our ability to operate our facilities at existing levels or at all, may result in increased costs for IEnova and its customers, may adversely affect our ability to develop new projects, 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, financial condition, results of operations, 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 IEnova’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 have obtained injunctive relief but are required to guarantee the difference in tariffs, which could be material, until the claims are definitively resolved by the courts. The three facilities obtained favorable resolutions from a lower court and the CRE has appealed one of these decisions.

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. If IEnova is not able to obtain legal protection for these impacted facilities, IEnova 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 significantly lower than the fixed prices in the PPAs that were entered into through self-supply permits. At September 30, 2021, Sempra Mexico 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 IEnova is unable to obtain adequate legal protection. IEnova 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, and it is expected that Mexico’s Supreme Court will ultimately settle the matter. If the proposed amendments are affirmed by the Supreme Court, 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 of IEnova’s facilities participating in the hydrocarbons sector filed lawsuits against the initiative to reform the Hydrocarbons Law and received injunctive relief pending a final resolution by the courts. In May 2021, a Mexican district court ordered the suspension of several of the provisions of the amendments with general application across the sector. 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 filed by several companies in the market, including three of the five lawsuits filed by IEnova. These judgments have been appealed and the granted suspensions will remain valid until the lawsuits are definitively resolved.

Amendments to Mexico’s General Foreign Trade Rules. In June 2021, amendments to Mexico’s General Foreign Trade Rules went into effect, which establish that only state-owned companies may import and export hydrocarbons, refined products, petrochemicals, and biofuels through channels other than those authorized (LDA authorization). These amendments prevent non-state-owned companies from (i) obtaining LDA authorizations, which affect new projects that have not obtained such approval, and (ii) renewing existing LDA authorizations, which affect operational projects and those under construction. The ECA Regas Facility and the Veracruz terminal have LDA authorizations that are valid through 2023 and, as a preventive measure, have filed amparo claims to challenge the newly introduced barrier to renew their existing LDA authorizations. In order to start operations at terminals currently under construction or in development in the vicinity of Topolobampo, Manzanillo and Ensenada, including the proposed ECA LNG liquefaction projects, IEnova filed amparo claims to challenge such amendments that prevent them from obtaining LDA authorizations in the future.

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 to the CFE, including permits at all of IEnova’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.

The initiative must first be submitted to a vote and approved in the respective plenary sessions of the Chamber of Deputies and the Chamber of Senators in Mexico. Additionally, the initiative must be approved by a two-thirds vote of Mexico’s Federal Congress and by the majority of the legislatures of the Mexican States and published in the Federal Official Gazette to be in force. Sempra Mexico is following this legislative procedure while assessing alternatives for its project companies. If passed in its current form, the initiative could have a material adverse effect on our business, financial condition, results of operations, cash flows and/or prospects, our ability to recover the carrying values of our investments in Mexico, and our ability to operate existing facilities and develop new energy projects in the country.

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. RBS, now NatWest Markets plc, our partner in the JV, paid an assessment of £86 million (approximately $138 million in U.S. dollars) in October 2014 to HMRC for denied VAT refund claims filed in connection with the purchase of carbon credit allowances by RBS SEE, a subsidiary of RBS Sempra Commodities. RBS SEE was subsequently sold to J.P. Morgan Chase & Co. and later to Mercuria Energy Group, Ltd. HMRC asserted that RBS was not entitled to reduce its VAT liability by VAT paid on certain carbon credit purchases during 2009 because RBS knew or should have known that certain vendors in the trading chain did not remit their own VAT to HMRC. In July 2021, RBS entered into a settlement with HMRC that resolved this matter.

In 2015, liquidators filed a claim in the High Court of Justice against RBS 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. 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 for 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 $61 million in U.S. dollars at September 30, 2021), plus costs and interest. In October 2020, the High Court of Justice assessed costs and interest to be approximately £21 million (approximately $28 million in U.S. dollars at September 30, 2021) 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. The Liquidating Companies in the High Court of Justice case have applied to the Supreme Court for permission to appeal the Court of Appeals’ decision. J.P. Morgan Chase & Co. has 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.

We recorded $100 million in equity losses from our investment in RBS Sempra Commodities in Equity Earnings on Sempra’s Condensed Consolidated Statement of Operations in the first quarter of 2020, which represented an estimate of our obligations to settle pending VAT matters and related legal costs. In the second quarter of 2021, we reduced this estimate by $50 million based on the settlement with HMRC on the First-Tier Tribunal case and revised assumptions on the High Court of Justice case. The final outcome of the High Court of Justice case remains uncertain.

Asbestos Claims Against EFH Subsidiaries

Certain EFH subsidiaries that we acquired as part of the merger of EFH with an indirect subsidiary of Sempra are defendants in personal injury lawsuits brought in state courts throughout the U.S. As of November 1, 2021, three such lawsuits are pending, all of which have been served. These cases allege 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 seek compensatory and punitive damages. 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 cash flows, financial condition and results of operations.

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.

A lease exists when a contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration. We determine if an arrangement is or contains a lease at inception of the contract.

Some of our lease agreements contain nonlease components, which represent activities that transfer a separate good or service to the lessee. As the lessee for both operating and finance leases, we have elected to combine lease and nonlease components as a single lease component for real estate, fleet vehicles, power generating facilities, and pipelines, whereby fixed or in-substance fixed payments allocable to the nonlease component are accounted for as part of the related lease liability and ROU asset. As the lessor, we have elected to combine lease and nonlease components as a single lease component for real estate, power generating facilities and terminals if the timing and pattern of transfer of the lease and nonlease components are the same and the lease component would be classified as an operating lease if accounted for separately.

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 and peaker plant facilities.

Leases that Have Not Yet Commenced

SDG&E has entered into a battery storage tolling agreement that it expects will commence in the fourth quarter of 2021. SDG&E expects to account for the tolling agreement as an operating lease upon commencement and expects the future minimum lease payments to be $1 million in 2021, $10 million in each of 2022 through 2025 and $103 million thereafter until expiration in 2036.

Lessor Accounting

Sempra Mexico is a lessor for certain of its natural gas and ethane pipelines, compressor stations, LPG storage facilities, a rail facility and two liquid fuels terminals.

Generally, we recognize operating lease income on a straight-line basis over the lease term and evaluate the underlying asset for impairment. Certain of our leases contain rate adjustments or are based on foreign currency exchange rates that may result in lease payments received that vary in amount from one period to the next.

In July 2021, a rail facility agreement commenced, which Sempra Mexico is accounting for as a sales-type lease. The rail facility is being used by the lessee to transport liquid fuels out of the Veracruz terminal. The lessee has the right to direct the use of the rail facility and will obtain substantially all of the economic benefits of the rail facility. At lease commencement, Sempra Mexico derecognized the $44 million carrying value of the rail facility from PP&E and recognized a net investment in sales-type lease asset of $60 million and a selling profit of $16 million. The agreement expires in 2041 and will automatically renew for successive five-year terms unless written notice is provided by Sempra Mexico or the lessee. Fixed lease payments are payable in the first five years of the agreement, which the lessee is required to pay even in the event of lease termination.

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

LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Sales-type leases:
Income recognized at lease commencement	$	16	$	—	$	16	$	1
Interest income	2		—		2		1
Total revenues from sales-type leases(1)	$	18	$	—	$	18	$	2
Operating leases:
Fixed lease payments	$	80	$	48	$	192	$	145
Variable lease payments	2		1		3		1
Total revenues from operating leases(1)	$	82	$	49	$	195	$	146
Depreciation expense	$	13	$	10	$	35	$	29

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

CONTRACTUAL COMMITMENTS

We discuss below significant changes in the first nine months of 2021 to contractual commitments discussed in Notes 1 and 16 of the Notes to Consolidated Financial Statements in the Annual Report.

LNG Purchase Agreement

Sempra LNG has a sale and purchase agreement 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 2021 to 2029. Although this agreement specifies a number of cargoes to be delivered, under its terms, the customer may divert certain cargoes, which would reduce amounts paid under the agreement by Sempra LNG. At September 30, 2021, we expect the commitment amount to decrease by $277 million in 2021 and then increase by $496 million in 2022, $279 million in 2023, $197 million in 2024, $153 million in 2025 and by $499 million thereafter (through contract termination in 2029) compared to December 31, 2020, reflecting changes in estimated forward prices since December 31, 2020 and actual transactions for the first nine months of 2021. 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.

OTHER COMMITMENTS

Franchise Agreements

In December 2020, the City of San Diego and SDG&E agreed to extend SDG&E’s natural gas and electric franchises for the city to June 1, 2021. After completing a competitive bid process, on June 8, 2021, the City of San Diego approved ordinances granting to SDG&E the natural gas and electric franchises for the city. These franchise agreements provide SDG&E the opportunity to serve the City of San Diego for the next 20 years, consisting of 10-year agreements that will automatically renew for an additional 10 years unless the City Council voids the automatic renewal with a supermajority vote. The agreements went into effect in July 2021. Over the 20-year term of the agreements, SDG&E will make principal payments of $110 million and interest payments of $13 million as consideration for the natural gas and electric franchise agreements. The consideration paid will not be recovered from customers and will be amortized over 20 years. SDG&E paid $11 million to the City of San Diego in the first nine months of 2021. At September 30, 2021, SDG&E has commitments to make future payments of $14 million per year in 2022 through 2024, $15 million in 2025 and $55 million thereafter.

Two lawsuits have been filed in the California Superior Court challenging the City’s process for its award of the natural gas and electric franchises and seeking to declare the franchise agreements null and void.

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 $46 million for Sempra, $17 million for SDG&E and $15 million for SoCalGas at September 30, 2021.

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SEGMENT INFORMATION

9 Months Ended

Sep. 30, 2021

Segment Reporting [Abstract]

SEGMENT INFORMATION

SEGMENT INFORMATION

We have five 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 Mexico develops, owns and operates, or holds interests in, natural gas, electric, LNG, LPG, ethane and liquid fuels infrastructure, and has marketing operations for the purchase of LNG and the purchase and sale of natural gas in Mexico.

▪Sempra LNG develops, builds, operates and invests in natural gas liquefaction export facilities, including natural gas pipelines and infrastructure, and buys, sells and transports natural gas through its marketing operations, all within North America.

As we discuss in Note 5, the financial information related to our businesses that constituted the Sempra South American Utilities segment is presented as discontinued operations for all periods presented. The information in the tables below excludes amounts from discontinued operations unless otherwise noted. We completed the sales of our discontinued operations in the second quarter of 2020.

We evaluate each segment’s performance based on its contribution to Sempra’s reported earnings and cash flows. The California Utilities operate in essentially separate service territories, under separate regulatory frameworks and rate structures set by the CPUC and, for SDG&E, the FERC. We describe the accounting policies of all of our segments in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

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 and include certain nominal amounts from our South American businesses that did not qualify for treatment as discontinued operations.

SEGMENT INFORMATION
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
REVENUES
SDG&E	$	1,464	$	1,472	$	4,119	$	3,976
SoCalGas	1,106		842		3,738		3,247
Sempra Mexico	597		351		1,368		935
Sempra LNG	119		63		367		255
All other	2		—		4		1
Adjustments and eliminations	—		2		(1)		—
Intersegment revenues(1)	(275)		(86)		(582)		(215)
Total	$	3,013	$	2,644	$	9,013	$	8,199
INTEREST EXPENSE
SDG&E	$	104	$	103	$	307	$	307
SoCalGas	39		39		118		119
Sempra Mexico	43		31		122		95
Sempra LNG	4		8		10		39
All other	77		93		240		304
Intercompany eliminations	(8)		(10)		(21)		(46)
Total	$	259	$	264	$	776	$	818
INTEREST INCOME
SDG&E	$	—	$	1	$	1	$	2
SoCalGas	—		—		—		2
Sempra Mexico	12		14		36		47
Sempra LNG	6		25		23		65
All other	1		—		2		3
Intercompany eliminations	(3)		(13)		(12)		(43)
Total	$	16	$	27	$	50	$	76
DEPRECIATION AND AMORTIZATION
SDG&E	$	226	$	200	$	659	$	598
SoCalGas	180		165		533		486
Sempra Mexico	60		47		168		141
Sempra LNG	3		2		8		7
All other	2		4		8		10
Total	$	471	$	418	$	1,376	$	1,242
INCOME TAX EXPENSE (BENEFIT)
SDG&E	$	90	$	33	$	168	$	161
SoCalGas	(437)		(6)		(335)		95
Sempra Mexico	24		92		145		(161)
Sempra LNG	(11)		18		19		59
All other	(8)		(38)		(42)		(94)
Total	$	(342)	$	99	$	(45)	$	60
EQUITY EARNINGS (LOSSES)
Equity earnings (losses), before income tax:
Sempra Texas Utilities	$	—	$	1	$	3	$	1
Sempra LNG	137		116		404		257
All other	—		—		50		(100)
	137		117		457		158
Equity earnings, net of income tax:
Sempra Texas Utilities	207		208		480		457
Sempra Mexico	47		1		85		207
	254		209		565		664
Total	$	391	$	326	$	1,022	$	822

SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E	$	205	$	178	$	603	$	633
SoCalGas	(1,126)		(24)		(625)		425
Sempra Texas Utilities	206		209		479		458
Sempra Mexico	164		50		225		302
Sempra LNG	1		71		194		207
Discontinued operations	—		(7)		—		1,840
All other	(98)		(126)		(226)		(515)
Total	$	(648)	$	351	$	650	$	3,350
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E					$	1,560	$	1,323
SoCalGas					1,417		1,345
Sempra Mexico					260		443
Sempra LNG					362		196
All other					7		6
Total					$	3,606	$	3,313
					September 30, 2021		December 31, 2020
ASSETS
SDG&E					$	23,783	$	22,311
SoCalGas					19,919		18,460
Sempra Texas Utilities					12,580		12,542
Sempra Mexico					11,339		10,752
Sempra LNG					3,335		2,205
All other					1,094		1,209
Intersegment receivables					(1,578)		(856)
Total					$	70,472	$	66,623
EQUITY METHOD AND OTHER INVESTMENTS
Sempra Texas Utilities					$	12,580	$	12,542
Sempra Mexico					924		852
Sempra LNG					454		433
All other					—		1
Total					$	13,958	$	13,828

(1)    Revenues for reportable segments include intersegment revenues of $3 million, $24 million, $52 million and $196 million for the three months ended September 30, 2021; $7 million, $72 million, $114 million and $389 million for the nine months ended September 30, 2021; $1 million, $23 million, $18 million and $44 million for the three months ended September 30, 2020 and $4 million, $61 million, $69 million and $81 million for the nine months ended September 30, 2020 for SDG&E, SoCalGas, Sempra Mexico and Sempra LNG, respectively.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA (Policies)

9 Months Ended

Sep. 30, 2021

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. Sempra’s business activities are organized under five 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. References in this report to “we,” “our,” “us” and “Sempra” are to Sempra and its consolidated entities, collectively, unless otherwise stated or indicated by the context. We refer to SDG&E and SoCalGas collectively as the California Utilities. Sempra Infrastructure Partners (formerly Sempra Global) is the holding company for our subsidiaries that are not subject to California or Texas utility regulation. We have eliminated intercompany accounts and transactions within the consolidated financial statements of each reporting entity.

Throughout these Notes, 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.

We have prepared our Condensed Consolidated Financial Statements in conformity with U.S. GAAP and in accordance with the interim-period-reporting requirements of Form 10-Q and applicable rules of the SEC. The financial statements reflect all adjustments that are necessary for a fair presentation of the results for the interim periods. These adjustments are only of a normal, recurring nature. Results of operations for interim periods are not necessarily indicative of results for the entire year or for any other period. We evaluated events and transactions that occurred after September 30, 2021 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, 2020 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2020 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.

You should read the information in this report in conjunction with the Annual Report.

Discontinued Operations

Discontinued OperationsIn January 2019, our board of directors approved a plan to sell our South American businesses based on our strategic focus on North America. We determined that these businesses, which previously constituted the Sempra South American Utilities segment, and certain activities associated with these businesses, met the held-for-sale criteria. These businesses are presented as discontinued operations, which we discuss further in Note 5. We completed the sales of our South American businesses in the second quarter of 2020. Our discussions in the Notes below relate only to our continuing operations unless otherwise noted.

Credit Loss Policy

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 receivable, historical and industry trends, counterparty creditworthiness, economic conditions and specific events, such as bankruptcies. 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.For amounts due from unconsolidated affiliates, on a quarterly basis, we evaluate credit losses and record allowances for expected credit losses, 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.

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 (from both continuing and discontinued operations) 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. The potentially dilutive impact from mandatory convertible preferred stock is 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, 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 Mexico has similar flow-through treatment.

We record income tax (expense) benefit from the transactional effects of foreign currency and inflation. Through the first quarter of 2021, such effects were offset by net gains (losses) from foreign currency derivatives that were hedging Sempra Mexico parent’s exposure to movements in the Mexican peso from its controlling interest in IEnova.

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 conversion and cash conversion features. The standard also amends ASC 260, “Earnings Per Share,” as follows:

▪requires an entity to apply the if-converted method when calculating diluted EPS for convertible instruments and no longer use the treasury stock method, which was previously allowed for certain convertible instruments;

▪requires an entity to include the effect of potential share settlement in the diluted EPS calculation when an instrument may be settled in cash or shares, and no longer allows an entity to rebut the presumption of share settlement if it has a history or policy of cash settlement;

▪requires an entity to include equity-classified convertible preferred stock that contains down-round features whereby, if the down-round feature is triggered, its effect is treated as a dividend and as a reduction of income available to common shareholders in basic EPS;

▪clarifies that the average market price should be used to calculate the diluted EPS denominator when the exercise price or the number of shares that may be issued is variable, except for certain contingently issuable shares; and

▪clarifies that the weighted-average share count from each quarter should be used when calculating the year-to-date weighted-average share count.

For public entities, ASU 2020-06 is effective for fiscal years beginning after December 15, 2021, including interim periods therein, with early adoption permitted for fiscal years beginning after December 15, 2020. 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 plan to adopt the standard on January 1, 2022 and are currently evaluating the effect of the standard on our ongoing financial reporting.

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:

▪The California Utilities use natural gas and 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 Mexico and Sempra LNG 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 the California Utilities, may use other energy derivatives to hedge exposures such as the price of vehicle fuel and greenhouse gas allowances.

In addition to the amounts noted above, we use commodity derivatives to manage risks associated with the physical locations of contractual obligations and assets, such as natural gas purchases and sales.

INTEREST RATE DERIVATIVES

We are exposed to interest rates primarily as a result of our current and expected use of financing. The California Utilities, 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 variable interest rates for U.S. fixed interest rates. From time to time, Sempra Mexico 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.

We also utilized foreign currency derivatives in 2020 to hedge exposure to fluctuations in the Peruvian sol and Chilean peso related to the sales of our operations in Peru and Chile, respectively.

Fair Value Measurement Policy

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, 2020.

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 cash balances, 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 marketable securities 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). These investments in marketable securities were negligible at both September 30, 2021 and December 31, 2020.

▪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 LNG.”

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.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 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.

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, short-term amounts due to/from unconsolidated affiliates, 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, cash flows, results of operations, financial condition and/or prospects. Unless otherwise indicated, we are unable to estimate reasonably 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.

Lessee, Leases Policy

Some of our lease agreements contain nonlease components, which represent activities that transfer a separate good or service to the lessee. As the lessee for both operating and finance leases, we have elected to combine lease and nonlease components as a single lease component for real estate, fleet vehicles, power generating facilities, and pipelines, whereby fixed or in-substance fixed payments allocable to the nonlease component are accounted for as part of the related lease liability and ROU asset. As the lessor, we have elected to combine lease and nonlease components as a single lease component for real estate, power generating facilities and terminals if the timing and pattern of transfer of the lease and nonlease components are the same and the lease component would be classified as an operating lease if accounted for separately.

Lessor, Leases Policy

Generally, we recognize operating lease income on a straight-line basis over the lease term and evaluate the underlying asset for impairment. Certain of our leases contain rate adjustments or are based on foreign currency exchange rates that may result in lease payments received that vary in amount from one period to the next.

Segment Information

We have five 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 Mexico develops, owns and operates, or holds interests in, natural gas, electric, LNG, LPG, ethane and liquid fuels infrastructure, and has marketing operations for the purchase of LNG and the purchase and sale of natural gas in Mexico.

▪Sempra LNG develops, builds, operates and invests in natural gas liquefaction export facilities, including natural gas pipelines and infrastructure, and buys, sells and transports natural gas through its marketing operations, all within North America.

As we discuss in Note 5, the financial information related to our businesses that constituted the Sempra South American Utilities segment is presented as discontinued operations for all periods presented. The information in the tables below excludes amounts from discontinued operations unless otherwise noted. We completed the sales of our discontinued operations in the second quarter of 2020.

We evaluate each segment’s performance based on its contribution to Sempra’s reported earnings and cash flows. The California Utilities operate in essentially separate service territories, under separate regulatory frameworks and rate structures set by the CPUC and, for SDG&E, the FERC. We describe the accounting policies of all of our segments in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

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)

9 Months Ended

Sep. 30, 2021

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. We provide information about the nature of restricted cash in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
(Dollars in millions)
	September 30,		December 31,
	2021		2020
Cash and cash equivalents	$	873	$	960
Restricted cash, current	31		22
Restricted cash, noncurrent	3		3
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	907	$	985

Accounts Receivable, Allowance for Credit Loss Table

TRADE AND OTHER ACCOUNTS RECEIVABLE – ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	2021		2020
Sempra:
Allowances for credit losses at January 1	$	138	$	29
Incremental allowance upon adoption of ASU 2016-13	—		1
Provisions for expected credit losses	96		84
Write-offs	(28)		(11)
Allowances for credit losses at September 30(1)	$	206	$	103
SDG&E:
Allowances for credit losses at January 1	$	69	$	14
Provisions for expected credit losses	30		44
Write-offs	(16)		(6)
Allowances for credit losses at September 30(2)	$	83	$	52
SoCalGas:
Allowances for credit losses at January 1	$	68	$	15
Provisions for expected credit losses	64		40
Write-offs	(12)		(5)
Allowances for credit losses at September 30(3)	$	120	$	50

(1)    At September 30, 2021, includes $146 million in Accounts Receivable – Trade, Net, $50 million in Accounts Receivable – Other, Net and $10 million in Other Long-Term Assets.

(2)    At September 30, 2021, includes $58 million in Accounts Receivable – Trade, Net, $21 million in Accounts Receivable – Other, Net and $4 million in Other Long-Term Assets.

(3)    At September 30, 2021, includes $85 million in Accounts Receivable – Trade, Net, $29 million in Accounts Receivable – Other, Net and $6 million in Other Long-Term Assets.

Financing Receivable, Allowance for Credit Loss

AMOUNTS DUE FROM UNCONSOLIDATED AFFILIATES – ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	2021		2020
Sempra:
Allowances for credit losses at January 1	$	3	$	—
Allowance established upon adoption of ASU 2016-13	—		6
Reductions to expected credit losses	(2)		(3)
Allowances for credit losses at September 30(1)	$	1	$	3

(1)    At September 30, 2021, $1 million is included in Due from Unconsolidated Affiliates – Noncurrent.

Inventory Table

The components of inventories are as follows:

INVENTORY BALANCES
(Dollars in millions)
	Natural gas				LNG				Materials and supplies				Total
	September 30, 2021		December 31, 2020		September 30, 2021		December 31, 2020		September 30, 2021		December 31, 2020		September 30, 2021		December 31, 2020
Sempra	$	169	$	118	$	17	$	7	$	185	$	183	$	371	$	308
SDG&E	—		—		—		—		112		104		112		104
SoCalGas	110		94		—		—		58		59		168		153

Capitalized Financing Costs Table

The table below summarizes capitalized interest and AFUDC.

CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Sempra	$	52	$	51	$	166	$	149
SDG&E	24		26		82		79
SoCalGas	18		14		49		39

Schedule of Finite-Lived Intangible Assets

Other Intangible Assets included on Sempra’s Condensed Consolidated Balance Sheets are as follows:

OTHER INTANGIBLE ASSETS
(Dollars in millions)
	Amortization period (years)	September 30, 2021		December 31, 2020
Renewable energy transmission and consumption permits	15 to 19	$	169	$	169
O&M agreement	23	66		66
PPA	14	190		—
Other	10 to indefinite	15		15
		440		250
Less accumulated amortization:
Renewable energy transmission and consumption permits		(38)		(32)
O&M agreement		(11)		(9)
PPA		(7)		—
Other		(8)		(7)
		(64)		(48)
		$	376	$	202

Net Periodic Benefit Cost Table

The following three tables provide the components of net periodic benefit cost.

NET PERIODIC BENEFIT COST – SEMPRA
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended September 30,
	2021		2020		2021		2020
Service cost	$	36	$	31	$	6	$	5
Interest cost	28		32		7		8
Expected return on assets	(44)		(41)		(14)		(14)
Amortization of:
Prior service cost (credit)	3		3		(1)		(1)
Actuarial loss (gain)	12		9		(3)		(2)
Settlement charges	—		13		—		—
Net periodic benefit cost (credit)	35		47		(5)		(4)
Regulatory adjustments	73		37		5		4
Total expense recognized	$	108	$	84	$	—	$	—
	Nine months ended September 30,
	2021		2020		2021		2020
Service cost	$	109	$	97	$	17	$	14
Interest cost	84		97		21		24
Expected return on assets	(130)		(126)		(44)		(41)
Amortization of:
Prior service cost (credit)	8		9		(2)		(2)
Actuarial loss (gain)	34		26		(7)		(7)
Settlement charges	7		22		—		—
Net periodic benefit cost (credit)	112		125		(15)		(12)
Regulatory adjustments	66		31		15		12
Total expense recognized	$	178	$	156	$	—	$	—

NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended September 30,
	2021		2020		2021		2020
Service cost	$	9	$	7	$	2	$	1
Interest cost	6		7		1		2
Expected return on assets	(11)		(12)		(2)		(3)
Amortization of:
Prior service cost	—		1		—		—
Actuarial loss (gain)	1		1		(1)		(1)
Net periodic benefit cost (credit)	5		4		—		(1)
Regulatory adjustments	21		22		—		1
Total expense recognized	$	26	$	26	$	—	$	—
	Nine months ended September 30,
	2021		2020		2021		2020
Service cost	$	26	$	23	$	4	$	3
Interest cost	18		22		4		5
Expected return on assets	(36)		(37)		(7)		(8)
Amortization of:
Prior service cost	—		2		—		—
Actuarial loss (gain)	2		3		(2)		(2)
Net periodic benefit cost (credit)	10		13		(1)		(2)
Regulatory adjustments	30		28		1		2
Total expense recognized	$	40	$	41	$	—	$	—

NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended September 30,
	2021		2020		2021		2020
Service cost	$	23	$	20	$	5	$	3
Interest cost	19		22		5		7
Expected return on assets	(27)		(27)		(12)		(11)
Amortization of:
Prior service cost (credit)	2		2		(1)		(1)
Actuarial loss (gain)	8		6		(2)		(1)
Net periodic benefit cost (credit)	25		23		(5)		(3)
Regulatory adjustments	52		15		5		3
Total expense recognized	$	77	$	38	$	—	$	—
	Nine months ended September 30,
	2021		2020		2021		2020
Service cost	$	73	$	64	$	13	$	10
Interest cost	59		66		16		19
Expected return on assets	(85)		(81)		(36)		(32)
Amortization of:
Prior service cost (credit)	6		6		(2)		(2)
Actuarial loss (gain)	27		19		(5)		(5)
Net periodic benefit cost (credit)	80		74		(14)		(10)
Regulatory adjustments	36		3		14		10
Total expense recognized	$	116	$	77	$	—	$	—

Earnings Per Share Computations Table

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

EARNINGS PER COMMON SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Numerator for continuing operations:
(Loss) income from continuing operations, net of income tax	$	(632)	$	428	$	751	$	1,823
Earnings attributable to noncontrolling interests	(5)		(22)		(48)		(191)
Preferred dividends	(11)		(48)		(52)		(121)
Preferred dividends of subsidiary	—		—		(1)		(1)
(Losses) earnings from continuing operations attributable to common shares	$	(648)	$	358	$	650	$	1,510
Numerator for discontinued operations:
(Loss) income from discontinued operations, net of income tax	$	—	$	(7)	$	—	$	1,850
Earnings attributable to noncontrolling interests	—		—		—		(10)
(Losses) earnings from discontinued operations attributable to common shares	$	—	$	(7)	$	—	$	1,840
Numerator for (losses) earnings:
(Losses) earnings attributable to common shares	$	(648)	$	351	$	650	$	3,350
Denominator:
Weighted-average common shares outstanding for basic EPS(1)	319,144		289,490		309,350		291,771
Dilutive effect of stock options and RSUs(2)(3)	—		1,092		797		1,164
Dilutive effect of mandatory convertible preferred stock	—		—		707		—
Weighted-average common shares outstanding for diluted EPS	319,144		290,582		310,854		292,935
Basic EPS:
(Losses) earnings from continuing operations	$	(2.03)	$	1.23	$	2.10	$	5.17
(Losses) earnings from discontinued operations	$	—	$	(0.02)	$	—	$	6.31
(Losses) earnings	$	(2.03)	$	1.21	$	2.10	$	11.48
Diluted EPS:
(Losses) earnings from continuing operations	$	(2.03)	$	1.23	$	2.09	$	5.15
(Losses) earnings from discontinued operations	$	—	$	(0.02)	$	—	$	6.28
(Losses) earnings	$	(2.03)	$	1.21	$	2.09	$	11.43

(1)    Includes 451 and 535 fully vested RSUs held in our Deferred Compensation Plan for the three months ended September 30, 2021 and 2020, respectively, and 453 and 536 of such RSUs for the nine months ended September 30, 2021 and 2020, 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)    In the three months ended September 30, 2021, the total weighted-average number of potentially dilutive stock options and RSUs was 699. However, these securities were not included in the computation of EPS because to do so would have decreased losses per share.

(3)    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, excluding amounts attributable to NCI.

CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1)
(Dollars in millions)
	Foreign currency translation adjustments		Financial instruments		Pension and other postretirement benefits		Total accumulated other comprehensive income (loss)
	Three months ended September 30, 2021 and 2020
Sempra:
Balance at June 30, 2021	$	(88)	$	(265)	$	(91)	$	(444)
OCI before reclassifications	—		15		(8)		7
Amounts reclassified from AOCI	—		16		3		19
Net OCI(2)	—		31		(5)		26
Balance at September 30, 2021	$	(88)	$	(234)	$	(96)	$	(418)
Balance at June 30, 2020	$	(83)	$	(361)	$	(98)	$	(542)
OCI before reclassifications	6		14		(7)		13
Amounts reclassified from AOCI	—		4		12		16
Net OCI(2)	6		18		5		29
Balance at September 30, 2020	$	(77)	$	(343)	$	(93)	$	(513)
SDG&E:
Balance at June 30, 2021					$	(10)	$	(10)
Amounts reclassified from AOCI					1		1
Net OCI					1		1
Balance at September 30, 2021					$	(9)	$	(9)
Balance as of June 30, 2020 and September 30, 2020					$	(12)	$	(12)
SoCalGas:
Balance at June 30, 2021			$	(13)	$	(17)	$	(30)
Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance at September 30, 2021			$	(13)	$	(16)	$	(29)
Balance as of June 30, 2020 and September 30, 2020			$	(13)	$	(9)	$	(22)

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

(2)    Total AOCI includes $(4) million and $3 million of foreign currency translation adjustments and $(2) million and $2 million of financial instruments associated with the IEnova cash tender offer in 2021 and purchases of NCI in 2020, respectively, which we discuss below in “Other Noncontrolling Interests – Sempra Mexico,” and which do 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)
	Nine months ended September 30, 2021 and 2020
Sempra(2):
Balance as of December 31, 2020	$	(64)	$	(331)	$	(105)	$	(500)
OCI before reclassifications	(24)		52		(3)		25
Amounts reclassified from AOCI	—		45		12		57
Net OCI(3)	(24)		97		9		82
Balance as of September 30, 2021	$	(88)	$	(234)	$	(96)	$	(418)
Balance as of December 31, 2019	$	(607)	$	(215)	$	(117)	$	(939)
OCI before reclassifications(4)	(115)		(153)		(5)		(273)
Amounts reclassified from AOCI(4)	645		25		29		699
Net OCI(3)	530		(128)		24		426
Balance as of September 30, 2020	$	(77)	$	(343)	$	(93)	$	(513)
SDG&E:
Balance as of December 31, 2020					$	(10)	$	(10)
Amounts reclassified from AOCI					1		1
Net OCI					1		1
Balance at September 30, 2021					$	(9)	$	(9)
Balance as of December 31, 2019					$	(16)	$	(16)
Amounts reclassified from AOCI(4)					4		4
Net OCI					4		4
Balance as of September 30, 2020					$	(12)	$	(12)
SoCalGas:
Balance as of December 31, 2020			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			—		2		2
Net OCI			—		2		2
Balance as of September 30, 2021			$	(13)	$	(16)	$	(29)
Balance as of December 31, 2019			$	(13)	$	(10)	$	(23)
Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance as of September 30, 2020			$	(13)	$	(9)	$	(22)

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

(2)    Includes discontinued operations in 2020.

(3)    Total AOCI includes $20 million and $3 million of foreign currency translation adjustments and $12 million and $2 million of financial instruments associated with the IEnova exchange and cash tender offers in 2021 and purchases of NCI in 2020, respectively, which we discuss below in “Other Noncontrolling Interests – Sempra Mexico,” and which do not impact the Condensed Consolidated Statement of Comprehensive Income (Loss).

(4)    Pension and Other Postretirement Benefits and Total AOCI include $3 million in transfers of liabilities from SDG&E to Sempra in 2020 related to the nonqualified pension plans.

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 September 30,
	2021		2020
Sempra:
Financial instruments:
Interest rate instruments	$	(1)	$	3	Interest Expense
Interest rate instruments	19		5		Equity Earnings(1)
Interest rate and foreign exchange instruments	5		(4)		Other (Expense) Income, Net
Total before income tax	23		4
	(7)		—		Income Tax Benefit (Expense)
Net of income tax	$	16	$	4
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	3	$	3	Other (Expense) Income, Net
Amortization of prior service cost	1		1		Other (Expense) Income, Net
Settlement charges	—		13		Other (Expense) Income, Net
Total before income tax	4		17
	(1)		(5)		Income Tax Benefit (Expense)
Net of income tax	$	3	$	12
Total reclassifications for the period, net of tax	$	19	$	16
SDG&E:
Pension and other postretirement benefits(2):
Amortization of prior service cost	$	1	$	—	Other Income (Expense), Net
Total reclassifications for the period, net of tax	$	1	$	—
SoCalGas:
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	1	$	—	Other (Expense) Income, Net
Total reclassifications for the period, net of tax	$	1	$	—

(1)    Equity earnings at Sempra Mexico 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
	Nine months ended September 30,
	2021		2020
Sempra:
Foreign currency translation adjustments	$	—	$	645	(Loss) Income from Discontinued Operations, Net of Income Tax
Financial instruments:
Interest rate instruments	$	—	$	6	Interest Expense
Interest rate instruments	57		8		Equity Earnings(1)
Foreign exchange instruments	1		(2)		Revenues: Energy-Related Businesses
	—		(1)		Other (Expense) Income, Net
Foreign exchange instruments	1		(2)		Equity Earnings(1)
Interest rate and foreign exchange instruments	—		1		Interest Expense
	4		33		Other (Expense) Income, Net
Total before income tax	63		43
	(16)		(12)		Income Tax Benefit (Expense)
Net of income tax	47		31
	(2)		(6)		Earnings Attributable to Noncontrolling Interests
	$	45	$	25
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	6	$	6	Other (Expense) Income, Net
Amortization of actuarial loss	—		6		(Loss) Income from Discontinued Operations, Net of Income Tax
Amortization of prior service cost	3		3		Other (Expense) Income, Net
Settlement charges	7		22		Other (Expense) Income, Net
Total before income tax	16		37
	—		(2)		(Loss) Income from Discontinued Operations, Net of Income Tax
	(4)		(9)		Income Tax Benefit (Expense)
Net of income tax	$	12	$	26
Total reclassifications for the period, net of tax	$	57	$	696
SDG&E:
Pension and other postretirement benefits(2):
Amortization of prior service cost	$	1	$	1	Other Income (Expense), Net
Total reclassifications for the period, net of tax	$	1	$	1
SoCalGas:
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	1	$	—	Other (Expense) Income, Net
Amortization of prior service cost	1		1		Other (Expense) Income, Net
Total reclassifications for the period, net of tax	$	2	$	1

(1)    Equity earnings at Sempra Mexico 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
	September 30, 2021		December 31, 2020		September 30, 2021		December 31, 2020
Sempra Mexico:
IEnova	0.1	%	29.8	%	$	2	$	1,487
ICM Ventures Holdings B.V.	—		17.5		—		7
Sempra LNG:
ECA LNG Phase 1	16.6		29.0		28		46
Parent and other:
PXiSE	20.0		20.0		—		1
Total Sempra					$	30	$	1,541

Transactions with Affiliates Table

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

AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	September 30, 2021		December 31, 2020
Sempra:
Total due from various unconsolidated affiliates – current	$	30	$	20
Sempra Mexico(1):
ESJ – Note due December 31, 2022, net of negligible allowance for credit losses at December 31, 2020(2)	$	—	$	85
IMG JV – Note due March 15, 2022, net of allowance for credit losses of $1 and $3 at September 30, 2021 and December 31, 2020, respectively(3)	684		695
Total due from unconsolidated affiliates – noncurrent	$	684	$	780
Sempra Mexico – TAG Pipelines Norte, S. de. R.L. de C.V. – Note due December 20, 2021(1)(4)	$	(42)	$	(41)
Various affiliates	—		(4)
Total due to unconsolidated affiliates – current	$	(42)	$	(45)
Sempra Mexico(1)(5):
TAG Pipelines Norte, S. de. R.L. de C.V.:
5.5% Note due January 9, 2024	$	(71)	$	(68)
5.5% Note due January 14, 2025	(21)		—
5.5% Note due July 16, 2025	(20)		—
TAG JV – 5.74% Note due December 17, 2029	(174)		(166)
Total due to unconsolidated affiliates – noncurrent	$	(286)	$	(234)
SDG&E:
Total due from various unconsolidated affiliates – current	$	1	$	—
Sempra	$	(45)	$	(38)
SoCalGas	(9)		(21)
Various affiliates	(7)		(5)
Total due to unconsolidated affiliates – current	$	(61)	$	(64)
Income taxes due from Sempra(6)	$	29	$	—
SoCalGas:
SDG&E	$	9	$	21
Various affiliates	2		1
Total due from unconsolidated affiliates – current	$	11	$	22
Sempra	$	(45)	$	(31)
Total due to unconsolidated affiliates – current	$	(45)	$	(31)
Income taxes due from (to) Sempra(6)	$	1	$	(37)

(1)    Amounts include principal balances plus accumulated interest outstanding.

(2)    U.S. dollar-denominated loan at a variable interest rate based on 1-month LIBOR plus 196 bps (2.11% at December 31, 2020). At December 31, 2020, $1 million of accrued interest receivable is included in Due from Unconsolidated Affiliates – Current. In March 2021, IEnova acquired the 50% equity interest in ESJ that it did not already own and ESJ became a wholly owned, consolidated subsidiary, resulting in the elimination of this note receivable.

(3)    Mexican peso-denominated revolving line of credit for up to 14.2 billion Mexican pesos or approximately $689 million U.S. dollar-equivalent at September 30, 2021, at a variable interest rate based on the 91-day Interbank Equilibrium Interest Rate plus 220 bps (7.02% at September 30, 2021), to finance construction of a natural gas marine pipeline. At both September 30, 2021 and December 31, 2020, $2 million of accrued interest receivable is included in Due from Unconsolidated Affiliates – Current. At September 30, 2021, we classified this revolving line of credit as noncurrent because we expect to extend the maturity date on a long-term basis prior to its stated maturity date.

(4)    U.S. dollar-denominated loan at a variable interest rate based on 6-month LIBOR plus 290 bps (3.06% at September 30, 2021).

(5)     U.S. dollar-denominated loans at fixed interest rates.

(6)    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.

The following table summarizes income statement information from unconsolidated affiliates.

INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Sempra:
Revenues	$	7	$	9	$	22	$	31
Cost of sales	—		9		11		35
Interest income	11		12		38		44
Interest expense	4		4		11		11
SDG&E:
Revenues	$	3	$	1	$	7	$	4
Cost of sales	20		17		75		56
SoCalGas:
Revenues	$	24	$	23	$	72	$	61
Cost of sales(1)	(2)		2		1		2

(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 September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Sempra:
Allowance for equity funds used during construction	$	31	$	34	$	103	$	96
Investment gains, net(1)	—		16		28		9
(Losses) gains on interest rate and foreign exchange instruments, net	(3)		19		(26)		(129)
Foreign currency transaction (losses) gains, net(2)	(17)		15		(10)		(95)
Non-service component of net periodic benefit cost	(66)		(48)		(52)		(45)
Fine related to Energy Efficiency Program inquiry	—		(6)		—		(6)
Interest on regulatory balancing accounts, net	2		—		5		13
Sundry, net	(2)		(1)		4		(6)
Total	$	(55)	$	29	$	52	$	(163)
SDG&E:
Allowance for equity funds used during construction	$	18	$	21	$	63	$	61
Non-service component of net periodic benefit cost	(15)		(18)		(10)		(15)
Fine related to Energy Efficiency Program inquiry	—		(6)		—		(6)
Interest on regulatory balancing accounts, net	2		—		5		8
Sundry, net	(1)		1		3		(1)
Total	$	4	$	(2)	$	61	$	47
SoCalGas:
Allowance for equity funds used during construction	$	13	$	11	$	36	$	29
Non-service component of net periodic benefit cost	(49)		(15)		(30)		(3)
Interest on regulatory balancing accounts, net	—		—		—		5
Sundry, net	(3)		(3)		(8)		(10)
Total	$	(39)	$	(7)	$	(2)	$	21

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

(2)    Includes losses of $18 million and $13 million in the three months and nine months ended September 30, 2021, respectively, and gains of $15 million and losses of $120 million in the three months and nine months ended September 30, 2020, respectively, from translation to U.S. dollars of a Mexican peso-denominated loan to IMG JV, 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 (BENEFIT) EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended September 30,						Nine months ended September 30,
	2021			2020			2021			2020
Sempra:
Income tax (benefit) expense from continuing operations	$	(342)		$	99		$	(45)		$	60
(Loss) income from continuing operations before income taxes and equity earnings	$	(1,365)		$	201		$	(316)		$	1,061
Equity earnings, before income tax(1)	137			117			457			158
Pretax (loss) income	$	(1,228)		$	318		$	141		$	1,219
Effective income tax rate	28		%	31		%	(32)		%	5		%
SDG&E:
Income tax expense	$	90		$	33		$	168		$	161
Income before income taxes	$	295		$	211		$	771		$	794
Effective income tax rate	31		%	16		%	22		%	20		%
SoCalGas:
Income tax (benefit) expense	$	(437)		$	(6)		$	(335)		$	95
(Loss) income before income taxes	$	(1,563)		$	(30)		$	(959)		$	521
Effective income tax rate	28		%	20		%	35		%	18		%

(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)

9 Months Ended

Sep. 30, 2021

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 Mexico		Sempra LNG		Consolidating adjustments and Parent and Other		Sempra
	Three months ended September 30, 2021
By major service line:
Utilities	$	1,369	$	966	$	17	$	—	$	(27)	$	2,325
Energy-related businesses	—		—		324		144		(145)		323
Revenues from contracts with customers	$	1,369	$	966	$	341	$	144	$	(172)	$	2,648
By market:
Gas	$	145	$	966	$	231	$	143	$	(165)	$	1,320
Electric	1,224		—		110		1		(7)		1,328
Revenues from contracts with customers	$	1,369	$	966	$	341	$	144	$	(172)	$	2,648
Revenues from contracts with customers	$	1,369	$	966	$	341	$	144	$	(172)	$	2,648
Utilities regulatory revenues	95		140		—		—		—		235
Other revenues	—		—		256		(25)		(101)		130
Total revenues	$	1,464	$	1,106	$	597	$	119	$	(273)	$	3,013
	Nine months ended September 30, 2021
By major service line:
Utilities	$	3,755	$	3,685	$	61	$	—	$	(79)	$	7,422
Energy-related businesses	—		—		859		260		(282)		837
Revenues from contracts with customers	$	3,755	$	3,685	$	920	$	260	$	(361)	$	8,259
By market:
Gas	$	580	$	3,685	$	635	$	257	$	(334)	$	4,823
Electric	3,175		—		285		3		(27)		3,436
Revenues from contracts with customers	$	3,755	$	3,685	$	920	$	260	$	(361)	$	8,259
Revenues from contracts with customers	$	3,755	$	3,685	$	920	$	260	$	(361)	$	8,259
Utilities regulatory revenues	364		53		—		—		—		417
Other revenues	—		—		448		107		(218)		337
Total revenues	$	4,119	$	3,738	$	1,368	$	367	$	(579)	$	9,013

DISAGGREGATED REVENUES (CONTINUED)
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Mexico		Sempra LNG		Consolidating adjustments and Parent and other		Sempra
	Three months ended September 30, 2020
By major service line:
Utilities	$	1,301	$	813	$	12	$	—	$	(25)	$	2,101
Energy-related businesses	—		—		244		35		(32)		247
Revenues from contracts with customers	$	1,301	$	813	$	256	$	35	$	(57)	$	2,348
By market:
Gas	$	126	$	813	$	159	$	33	$	(54)	$	1,077
Electric	1,175		—		97		2		(3)		1,271
Revenues from contracts with customers	$	1,301	$	813	$	256	$	35	$	(57)	$	2,348
Revenues from contracts with customers	$	1,301	$	813	$	256	$	35	$	(57)	$	2,348
Utilities regulatory revenues	171		29		—		—		—		200
Other revenues	—		—		95		28		(27)		96
Total revenues	$	1,472	$	842	$	351	$	63	$	(84)	$	2,644
	Nine months ended September 30, 2020
By major service line:
Utilities	$	3,610	$	3,261	$	42	$	—	$	(66)	$	6,847
Energy-related businesses	—		—		616		56		(40)		632
Revenues from contracts with customers	$	3,610	$	3,261	$	658	$	56	$	(106)	$	7,479
By market:
Gas	$	518	$	3,261	$	439	$	51	$	(98)	$	4,171
Electric	3,092		—		219		5		(8)		3,308
Revenues from contracts with customers	$	3,610	$	3,261	$	658	$	56	$	(106)	$	7,479
Revenues from contracts with customers	$	3,610	$	3,261	$	658	$	56	$	(106)	$	7,479
Utilities regulatory revenues	366		(14)		—		—		—		352
Other revenues	—		—		277		199		(108)		368
Total revenues	$	3,976	$	3,247	$	935	$	255	$	(214)	$	8,199

Schedule of Timing of Remaining Performance Obligations

For contracts greater than one year, at September 30, 2021, we expect to recognize revenue related to the fixed fee component of the consideration as shown below. SoCalGas did not have any such performance obligations at September 30, 2021.

REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra		SDG&E
2021 (excluding first nine months of 2021)	$	88	$	1
2022	368		4
2023	367		4
2024	367		4
2025	364		4
Thereafter	4,129		67
Total revenues to be recognized	$	5,683	$	84

(1)    Excludes intercompany transactions.

Schedule of Contract Liabilities

Activities within Sempra’s and SDG&E’s contract liabilities are presented below. There were no contract liabilities at SoCalGas in the nine months ended September 30, 2021 or 2020.

CONTRACT LIABILITIES
(Dollars in millions)
	2021		2020
Sempra:
Contract liabilities at January 1	$	(207)	$	(163)
Revenue from performance obligations satisfied during reporting period	36		3
Payments received in advance	(1)		—
Contract liabilities at September 30(1)	$	(172)	$	(160)
SDG&E:
Contract liabilities at January 1	$	(87)	$	(91)
Revenue from performance obligations satisfied during reporting period	3		3
Contract liabilities at September 30(1)	$	(84)	$	(88)

(1)     At September 30, 2021, includes $8 million and $4 million in Other Current Liabilities and $164 million and $80 million 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)
	September 30, 2021		December 31, 2020
Sempra:
Accounts receivable – trade, net	$	1,216	$	1,447
Accounts receivable – other, net	17		12
Due from unconsolidated affiliates – current(1)	2		3
Other long-term assets	115		—
Total	$	1,350	$	1,462
SDG&E:
Accounts receivable – trade, net	$	642	$	573
Accounts receivable – other, net	11		8
Due from unconsolidated affiliates – current(1)	3		2
Other long-term assets	47		—
Total	$	703	$	583
SoCalGas:
Accounts receivable – trade, net	$	462	$	786
Accounts receivable – other, net	6		4
Other long-term assets	68		—
Total	$	536	$	790

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

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REGULATORY MATTERS (Tables)

9 Months Ended

Sep. 30, 2021

Regulated Operations [Abstract]

Schedule of Regulatory Assets

We show the details of regulatory assets and liabilities in the following table.

REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	September 30, 2021		December 31, 2020
SDG&E:
Fixed-price contracts and other derivatives	$	(88)	$	(53)
Deferred income taxes recoverable in rates	72		22
Pension and other postretirement benefit plan obligations	19		50
Removal obligations	(2,228)		(2,121)
Environmental costs	55		56
Sunrise Powerlink fire mitigation	121		121
Regulatory balancing accounts(1)(2)
Commodity – electric	85		72
Gas transportation	23		35
Safety and reliability	60		67
Public purpose programs	(138)		(158)
2019 GRC retroactive impacts	14		56
Other balancing accounts	535		233
Other regulatory assets, net(2)	110		72
Total SDG&E	(1,360)		(1,548)
SoCalGas:
Deferred income taxes recoverable (refundable) in rates	9		(82)
Pension and other postretirement benefit plan obligations	342		417
Employee benefit costs	37		37
Removal obligations	(649)		(685)
Environmental costs	35		36
Regulatory balancing accounts(1)(2)
Commodity – gas, including transportation	(138)		(56)
Safety and reliability	299		335
Public purpose programs	(274)		(253)
2019 GRC retroactive impacts	51		202
Other balancing accounts	85		(58)
Other regulatory assets, net(2)	160		75
Total SoCalGas	(43)		(32)
Sempra Mexico:
Deferred income taxes recoverable in rates	80		80
Total Sempra	$	(1,323)	$	(1,500)

(1)    At September 30, 2021 and December 31, 2020, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $331 million and $139 million, respectively, and for SoCalGas was $472 million and $218 million, respectively.

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

Schedule of Regulatory Liabilities

We show the details of regulatory assets and liabilities in the following table.

REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	September 30, 2021		December 31, 2020
SDG&E:
Fixed-price contracts and other derivatives	$	(88)	$	(53)
Deferred income taxes recoverable in rates	72		22
Pension and other postretirement benefit plan obligations	19		50
Removal obligations	(2,228)		(2,121)
Environmental costs	55		56
Sunrise Powerlink fire mitigation	121		121
Regulatory balancing accounts(1)(2)
Commodity – electric	85		72
Gas transportation	23		35
Safety and reliability	60		67
Public purpose programs	(138)		(158)
2019 GRC retroactive impacts	14		56
Other balancing accounts	535		233
Other regulatory assets, net(2)	110		72
Total SDG&E	(1,360)		(1,548)
SoCalGas:
Deferred income taxes recoverable (refundable) in rates	9		(82)
Pension and other postretirement benefit plan obligations	342		417
Employee benefit costs	37		37
Removal obligations	(649)		(685)
Environmental costs	35		36
Regulatory balancing accounts(1)(2)
Commodity – gas, including transportation	(138)		(56)
Safety and reliability	299		335
Public purpose programs	(274)		(253)
2019 GRC retroactive impacts	51		202
Other balancing accounts	85		(58)
Other regulatory assets, net(2)	160		75
Total SoCalGas	(43)		(32)
Sempra Mexico:
Deferred income taxes recoverable in rates	80		80
Total Sempra	$	(1,323)	$	(1,500)

(1)    At September 30, 2021 and December 31, 2020, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $331 million and $139 million, respectively, and for SoCalGas was $472 million and $218 million, respectively.

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

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ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS (Tables)

9 Months Ended

Sep. 30, 2021

Business Combinations [Abstract]

Summarized Results from Discontinued Operations

Summarized results from discontinued operations were as follows:

DISCONTINUED OPERATIONS
(Dollars in millions)
	Three months ended September 30, 2020(1)		Nine months ended September 30, 2020(2)
Revenues	$	—	$	570
Cost of sales	—		(364)
(Loss) gain on sale of discontinued operations	(16)		2,899
Operating expenses	—		(66)
Interest and other	—		(3)
Income before income taxes	(16)		3,036
Income tax benefit (expense)	9		(1,186)
(Loss) income from discontinued operations, net of income tax	(7)		1,850
Earnings attributable to noncontrolling interests	—		(10)
(Losses) earnings from discontinued operations attributable to Sempra	$	(7)	$	1,840

(1)    Represents post-closing adjustments related to the sale of our equity interests in our Chilean businesses.    

(2)    Results include activity until the sale of our Peruvian businesses on April 24, 2020 and Chilean businesses on June 24, 2020.

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INVESTMENT IN UNCONSOLIDATED ENTITIES (Tables)

9 Months Ended

Sep. 30, 2021

Investments [Abstract]

Condensed Financial Statements

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

SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Operating revenues	$	1,286	$	1,232	$	3,572	$	3,394
Operating expenses	(866)		(819)		(2,531)		(2,387)
Income from operations	420		413		1,041		1,007
Interest expense	(104)		(102)		(308)		(305)
Income tax expense	(54)		(50)		(124)		(115)
Net income	255		255		587		557
Noncontrolling interest held by TTI	(51)		(50)		(118)		(111)
Earnings attributable to Sempra(1)	204		205		469		446

(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)

9 Months Ended

Sep. 30, 2021

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities

PRIMARY U.S. COMMITTED LINES OF CREDIT
(Dollars in millions)
	September 30, 2021
	Total facility		Commercial paper outstanding(1)(2)		Available unused credit
Sempra(3)	$	4,435	$	(2,112)	$	2,323
SDG&E(4)	1,500		—		1,500
SoCalGas(4)	750		—		750
Total	$	6,685	$	(2,112)	$	4,573

(1)    Because the commercial paper programs are supported by these lines, we reflect the amount of commercial paper outstanding as a reduction to the available unused credit.

(2)    Commercial paper outstanding is before reductions of a negligible amount of unamortized discount.

(3)    The facility also provides for issuance of $200 million of letters of credit on behalf of Sempra with the amount of borrowings otherwise available under the facility reduced by the amount of outstanding letters of credit. Subject to obtaining commitments from existing or new lenders and satisfaction of other specified conditions, Sempra has the right to increase the letter of credit commitment up to $500 million. No letters of credit were outstanding at September 30, 2021.

(4)    The facility also provides for issuance of $100 million of letters of credit on behalf of the borrowing utility with the amount of borrowings otherwise available under the facility reduced by the amount of outstanding letters of credit. Subject to obtaining commitments from existing or new lenders and satisfaction of other specified conditions, the borrowing utility has the right to increase the letter of credit commitment up to $250 million. No letters of credit were outstanding at September 30, 2021.

FOREIGN COMMITTED LINES OF CREDIT
(U.S. dollar equivalent in millions)
	September 30, 2021
Expiration date of facility	Total facility		Amounts outstanding		Available unused credit
February 2024	$	1,500	$	—	$	1,500
September 2023(1)	350		(294)		56
Total	$	1,850	$	(294)	$	1,556

(1)    In September 2021, IEnova amended this revolving credit facility to increase the amount available under the facility from $280 million to $350 million and extend the expiration of the facility from September 2021 to September 2023. Borrowings continue to bear interest at a per annum rate equal to 3-month LIBOR plus 54 bps.

FOREIGN UNCOMMITTED LINES OF CREDIT
(U.S. dollar equivalent in millions)
		September 30, 2021
Expiration date of facility	Borrowing denomination	Total facility		Amounts outstanding		Available unused credit
September 2022(1)	U.S. dollars	$	250	$	(250)	$	—
August 2023(2)	U.S. dollars or Mexican pesos	100		(37)		63
October 2023(3)	U.S. dollars	100		—		100
October 2023(4)	U.S. dollars or Mexican pesos	20		—		20
Total		$	470	$	(287)	$	183

(1)    IEnova’s one-year credit agreement under which borrowings bear interest at a per annum rate equal to 3-month LIBOR plus 10 bps.

(2)    ECA LNG Phase 1’s two-year credit agreement under which outstanding amounts were borrowed in Mexican pesos and bear interest at a variable rate based on the 28-day Interbank Equilibrium Interest Rate plus 105 bps and are before reductions from negligible unamortized discount. Borrowings made in U.S. dollars bear interest at a variable rate based on the 1-month or 3-month LIBOR plus 105 bps.

(3)    IEnova’s three-year credit agreement under which borrowings bear interest at a per annum rate equal to 6-month LIBOR plus 52 bps.

(4)    IEnova’s three-year credit agreement under which borrowings made in Mexican pesos bear interest at a variable rate based on the 28-day Interbank Equilibrium Interest Rate plus an applicable margin. Borrowings made in U.S. dollars bear interest at a variable rate based on 1-month LIBOR plus an applicable margin. The applicable margin is determined on the date of borrowing.

The weighted-average interest rates on the total short-term debt at September 30, 2021 and December 31, 2020 were as follows:

WEIGHTED-AVERAGE INTEREST RATES
	September 30, 2021		December 31, 2020
Sempra	0.39	%	0.83	%
SDG&E	0.76		—
SoCalGas	—		0.14

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DERIVATIVE FINANCIAL INSTRUMENTS (Tables)

9 Months Ended

Sep. 30, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Commodity Derivative Volumes Table

The following table summarizes net energy derivative volumes.

NET ENERGY DERIVATIVE VOLUMES
(Quantities in millions)
Commodity	Unit of measure	September 30, 2021	December 31, 2020
Sempra:
Natural gas	MMBtu	(14)	5
Electricity	MWh	1	1
Congestion revenue rights	MWh	48	43
SDG&E:
Natural gas	MMBtu	10	16
Electricity	MWh	1	1
Congestion revenue rights	MWh	48	43
SoCalGas:
Natural gas	MMBtu	—	1

Notional Amounts of Derivatives Table

The following table presents the net notional amounts of our interest rate derivatives, excluding JVs.

INTEREST RATE DERIVATIVES
(Dollars in millions)
	September 30, 2021			December 31, 2020
	Notional debt		Maturities	Notional debt		Maturities
Sempra:
Cash flow hedges	$	747	2021-2034	$	1,486	2021-2034

The following table presents the net notional amounts of our foreign currency derivatives, excluding JVs.

FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	September 30, 2021			December 31, 2020
	Notional amount		Maturities	Notional amount		Maturities
Sempra:
Cross-currency swaps	$	306	2021-2023	$	306	2021-2023
Other foreign currency derivatives	130		2021-2023	1,764		2021-2022

Derivative Instruments on the Condensed Consolidated Balance Sheets Table

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

DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	September 30, 2021
	Other current assets(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	$	—	$	6	$	(42)	$	(134)
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	252		19		(300)		(21)
Associated offsetting commodity contracts	(225)		(15)		225		15
Associated offsetting cash collateral	—		—		11		—
Commodity contracts subject to rate recovery	50		76		(52)		(3)
Associated offsetting commodity contracts	(4)		—		4		—
Net amounts presented on the balance sheet	73		86		(154)		(143)
Additional cash collateral for commodity contracts not subject to rate recovery	47		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	30		—		—		—
Total(2)	$	150	$	86	$	(154)	$	(143)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	47	$	76	$	(18)	$	(2)
Associated offsetting commodity contracts	(3)		—		3		—
Net amounts presented on the balance sheet	44		76		(15)		(2)
Additional cash collateral for commodity contracts subject to rate recovery	28		—		—		—
Total(2)	$	72	$	76	$	(15)	$	(2)
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	3	$	—	$	(34)	$	(1)
Associated offsetting commodity contracts	(1)		—		1		—
Net amounts presented on the balance sheet	2		—		(33)		(1)
Additional cash collateral for commodity contracts subject to rate recovery	2		—		—		—
Total	$	4	$	—	$	(33)	$	(1)

(1)    Included in Current Assets: Fixed-Price Contracts and Other Derivatives for SDG&E.

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

DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	December 31, 2020
	Other current assets(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	$	—	$	1	$	(26)	$	(160)
Derivatives not designated as hedging instruments:
Foreign exchange instruments	24		—		—		—
Commodity contracts not subject to rate recovery	82		17		(95)		(16)
Associated offsetting commodity contracts	(82)		(13)		82		13
Commodity contracts subject to rate recovery	35		95		(35)		(25)
Associated offsetting commodity contracts	(2)		—		2		—
Net amounts presented on the balance sheet	57		100		(72)		(188)
Additional cash collateral for commodity contracts not subject to rate recovery	21		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	30		—		—		—
Total(2)	$	108	$	100	$	(72)	$	(188)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	32	$	95	$	(28)	$	(25)
Associated offsetting commodity contracts	(1)		—		1		—
Net amounts presented on the balance sheet	31		95		(27)		(25)
Additional cash collateral for commodity contracts subject to rate recovery	24		—		—		—
Total(2)	$	55	$	95	$	(27)	$	(25)
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	3	$	—	$	(7)	$	—
Associated offsetting commodity contracts	(1)		—		1		—
Net amounts presented on the balance sheet	2		—		(6)		—
Additional cash collateral for commodity contracts subject to rate recovery	6		—		—		—
Total	$	8	$	—	$	(6)	$	—

(1)    Included in Current Assets: Fixed-Price Contracts and Other Derivatives for SDG&E.

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

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

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

CASH FLOW HEDGE IMPACTS
(Dollars in millions)
	Pretax gain (loss) recognized in OCI					Pretax gain (loss) reclassified from AOCI into earnings
	Three months ended September 30,					Three months ended September 30,
	2021		2020		Location	2021		2020
Sempra:
Interest rate instruments	$	7	$	8	Interest Expense	$	1	$	(3)
Interest rate instruments	3		25		Equity Earnings(1)	(19)		(5)
Foreign exchange instruments	5		(2)		Revenues: Energy- Related Businesses	—		—
Foreign exchange instruments	3		(1)		Equity Earnings(1)	—		—
Interest rate and foreign exchange instruments	(3)		6		Other (Expense) Income, Net	(5)		4
Total	$	15	$	36		$	(23)	$	(4)
	Nine months ended September 30,					Nine months ended September 30,
	2021		2020		Location	2021		2020
Sempra:
Interest rate instruments	$	27	$	(42)	Interest Expense	$	—	$	(6)
Interest rate instruments	54		(175)		Equity Earnings(1)	(57)		(8)
Foreign exchange instruments	7		14		Revenues: Energy- Related Businesses	(1)		2
					Other (Expense) Income, Net	—		1
Foreign exchange instruments	5		9		Equity Earnings(1)	(1)		2
Interest rate and foreign exchange instruments	(2)		(31)		Interest Expense	—		(1)
					Other (Expense) Income, Net	(4)		(33)
Total	$	91	$	(225)		$	(63)	$	(43)

(1)    Equity earnings at Sempra Mexico 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 September 30,				Nine months ended September 30,
	Location	2021		2020		2021		2020
Sempra:
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	$	(154)	$	(39)	$	(344)	$	25
Commodity contracts subject to rate recovery	Cost of Natural Gas	(26)		—		(24)		(6)
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	8		41		51		41
Foreign exchange instruments	Other (Expense) Income, Net	2		15		(22)		(97)
Total		$	(170)	$	17	$	(339)	$	(37)
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	8	$	41	$	51	$	41
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas	$	(26)	$	—	$	(24)	$	(6)

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FAIR VALUE MEASUREMENTS (Tables)

9 Months Ended

Sep. 30, 2021

Fair Value Disclosures [Abstract]

Recurring Fair Value Measures Table

RECURRING FAIR VALUE MEASURES – SEMPRA
(Dollars in millions)
	Fair value at September 30, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	350	$	6	$	—	$	356
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	40		12		—		52
Municipal bonds	—		320		—		320
Other securities	—		270		—		270
Total debt securities	40		602		—		642
Total nuclear decommissioning trusts(1)	390		608		—		998
Interest rate and foreign exchange instruments	—		6		—		6
Commodity contracts not subject to rate recovery	—		31		—		31
Effect of netting and allocation of collateral(2)	47		—		—		47
Commodity contracts subject to rate recovery	32		2		88		122
Effect of netting and allocation of collateral(2)	24		—		6		30
Support Agreement, net of related guarantee fees	—		—		7		7
Total	$	493	$	647	$	101	$	1,241
Liabilities:
Interest rate and foreign exchange instruments	$	—	$	176	$	—	$	176
Commodity contracts not subject to rate recovery	—		81		—		81
Effect of netting and allocation of collateral(2)	—		(11)		—		(11)
Commodity contracts subject to rate recovery	—		35		16		51
Support Agreement, net of related guarantee fees	—		—		2		2
Total	$	—	$	281	$	18	$	299
	Fair value at December 31, 2020
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	358	$	6	$	—	$	364
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	41		24		—		65
Municipal bonds	—		326		—		326
Other securities	—		270		—		270
Total debt securities	41		620		—		661
Total nuclear decommissioning trusts(1)	399		626		—		1,025
Interest rate and foreign exchange instruments	—		25		—		25
Commodity contracts not subject to rate recovery	—		4		—		4
Effect of netting and allocation of collateral(2)	21		—		—		21
Commodity contracts subject to rate recovery	6		1		121		128
Effect of netting and allocation of collateral(2)	19		5		6		30
Support Agreement, net of related guarantee fees	—		—		7		7
Total	$	445	$	661	$	134	$	1,240
Liabilities:
Interest rate and foreign exchange instruments	$	—	$	186	$	—	$	186
Commodity contracts not subject to rate recovery	—		16		—		16
Commodity contracts subject to rate recovery	—		6		52		58
Support Agreement, net of related guarantee fees	—		—		4		4
Total	$	—	$	208	$	56	$	264

(1)    Excludes cash, cash equivalents and 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 September 30, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	350	$	6	$	—	$	356
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	40		12		—		52
Municipal bonds	—		320		—		320
Other securities	—		270		—		270
Total debt securities	40		602		—		642
Total nuclear decommissioning trusts(1)	390		608		—		998
Commodity contracts subject to rate recovery	32		—		88		120
Effect of netting and allocation of collateral(2)	22		—		6		28
Total	$	444	$	608	$	94	$	1,146
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	1	$	16	$	17
Total	$	—	$	1	$	16	$	17
	Fair value at December 31, 2020
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	358	$	6	$	—	$	364
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	41		24		—		65
Municipal bonds	—		326		—		326
Other securities	—		270		—		270
Total debt securities	41		620		—		661
Total nuclear decommissioning trusts(1)	399		626		—		1,025
Commodity contracts subject to rate recovery	5		—		121		126
Effect of netting and allocation of collateral(2)	18		—		6		24
Total	$	422	$	626	$	127	$	1,175
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	—	$	52	$	52
Total	$	—	$	—	$	52	$	52

(1)    Excludes cash, cash equivalents and 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 September 30, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	—	$	2	$	—	$	2
Effect of netting and allocation of collateral(1)	2		—		—		2
Total	$	2	$	2	$	—	$	4
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	34	$	—	$	34
Total	$	—	$	34	$	—	$	34
	Fair value at December 31, 2020
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	1	$	1	$	—	$	2
Effect of netting and allocation of collateral(1)	1		5		—		6
Total	$	2	$	6	$	—	$	8
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	6	$	—	$	6
Total	$	—	$	6	$	—	$	6

(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 Table

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

LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)
	Three months ended September 30,
	2021		2020
Balance at July 1	$	80	$	17
Realized and unrealized losses	(35)		(4)
Allocated transmission instruments	1		1
Settlements	26		19
Balance at September 30	$	72	$	33
Change in unrealized gains (losses) relating to instruments still held at September 30	$	9	$	7
	Nine months ended September 30,
	2021		2020
Balance at January 1	$	69	$	28
Realized and unrealized losses	(29)		(18)
Allocated transmission instruments	(1)		2
Settlements	33		21
Balance at September 30	$	72	$	33
Change in unrealized gains (losses) relating to instruments still held at September 30	$	5	$	(1)

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

The table below sets forth a reconciliation 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 RECONCILIATION
(Dollars in millions)
	Three months ended September 30,
	2021		2020
Balance at July 1	$	4	$	—
Realized and unrealized gains(1)	3		7
Settlements	(2)		(1)
Balance at September 30(2)	$	5	$	6
Change in unrealized gains (losses) relating to instruments still held at September 30	$	3	$	6
	Nine months ended September 30,
	2021		2020
Balance at January 1	$	3	$	—
Realized and unrealized gains(1)	8		7
Settlements	(6)		(1)
Balance at September 30(2)	$	5	$	6
Change in unrealized gains (losses) relating to instruments still held at September 30	$	7	$	6

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

(2)    Includes $7 million in Other Current Assets offset by $2 million in Deferred Credits and Other at September 30, 2021 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.

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
2021	$	(1.81)	to	$	14.11	$	(0.12)
2020	(3.77)		to	6.03		(1.58)

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 September 30 were as follows:

LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS
Settlement year	Price per MWh					Weighted-average price per MWh
2021	$	24.05	to	$	130.40	$	57.36
2020		19.45	to		71.25		38.14

Fair Value of Financial Instruments Table

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)
	September 30, 2021
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
Sempra:
Long-term amounts due from unconsolidated affiliates(1)	$	687	$	—	$	697	$	—	$	697
Long-term amounts due to unconsolidated affiliates	328		—		347		—		347
Total long-term debt(2)	21,966		—		24,288		—		24,288
SDG&E:
Total long-term debt(3)	$	6,418	$	—	$	7,263	$	—	$	7,263
SoCalGas:
Total long-term debt(4)	$	4,759	$	—	$	5,373	$	—	$	5,373
	December 31, 2020
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
Sempra:
Long-term amounts due from unconsolidated affiliates(1)	$	786	$	—	$	817	$	—	$	817
Long-term amounts due to unconsolidated affiliates	275		—		266		—		266
Total long-term debt(2)	22,259		—		25,478		—		25,478
SDG&E:
Total long-term debt(3)	$	6,253	$	—	$	7,384	$	—	$	7,384
SoCalGas:
Total long-term debt(4)	$	4,759	$	—	$	5,655	$	—	$	5,655

(1)    Before allowances for credit losses of $1 million and $3 million at September 30, 2021 and December 31, 2020, respectively. Includes $2 million and $3 million in Due From Unconsolidated Affiliates – Current at September 30, 2021 and December 31, 2020, respectively.

(2)    Before reductions of unamortized discount and debt issuance costs of $266 million and $268 million at September 30, 2021 and December 31, 2020, respectively, and excluding finance lease obligations of $1,336 million and $1,330 million at September 30, 2021 and December 31, 2020, respectively.

(3)    Before reductions of unamortized discount and debt issuance costs of $62 million and $52 million at September 30, 2021 and December 31, 2020, respectively, and excluding finance lease obligations of $1,279 million and $1,276 million at September 30, 2021 and December 31, 2020, respectively.

(4)    Before reductions of unamortized discount and debt issuance costs of $37 million and $40 million at September 30, 2021 and December 31, 2020, respectively, and excluding finance lease obligations of $57 million and $54 million at September 30, 2021 and December 31, 2020, respectively.

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SAN ONOFRE NUCLEAR GENERATING STATION (Tables)

9 Months Ended

Sep. 30, 2021

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. 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
At September 30, 2021:
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	52	$	—	$	—	$	52
Municipal bonds(2)	307		14		(1)		320
Other securities(3)	261		10		(1)		270
Total debt securities	620		24		(2)		642
Equity securities	103		255		(2)		356
Cash and cash equivalents	7		—		—		7
Payables, net	(2)		—		—		(2)
Total	$	728	$	279	$	(4)	$	1,003
At December 31, 2020:
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	$	64	$	1	$	—	$	65
Municipal bonds	308		18		—		326
Other securities	253		17		—		270
Total debt securities	625		36		—		661
Equity securities	112		254		(2)		364
Cash and cash equivalents	3		—		—		3
Payables, net	(9)		—		—		(9)
Total	$	731	$	290	$	(2)	$	1,019

(1)    Maturity dates are 2021-2051.

(2)    Maturity dates are 2022-2056.

(3)    Maturity dates are 2021-2072.

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 NDT
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Proceeds from sales	$	187	$	294	$	729	$	1,091
Gross realized gains	9		9		48		108
Gross realized losses	(1)		(2)		(4)		(13)

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COMMITMENTS AND CONTINGENCIES (Tables)

9 Months Ended

Sep. 30, 2021

Commitments and Contingencies Disclosure [Abstract]

Schedule of Operating Lease Payments Received, Lease Income Table

LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Sales-type leases:
Income recognized at lease commencement	$	16	$	—	$	16	$	1
Interest income	2		—		2		1
Total revenues from sales-type leases(1)	$	18	$	—	$	18	$	2
Operating leases:
Fixed lease payments	$	80	$	48	$	192	$	145
Variable lease payments	2		1		3		1
Total revenues from operating leases(1)	$	82	$	49	$	195	$	146
Depreciation expense	$	13	$	10	$	35	$	29

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

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SEGMENT INFORMATION (Tables)

9 Months Ended

Sep. 30, 2021

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 and include certain nominal amounts from our South American businesses that did not qualify for treatment as discontinued operations.

SEGMENT INFORMATION
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
REVENUES
SDG&E	$	1,464	$	1,472	$	4,119	$	3,976
SoCalGas	1,106		842		3,738		3,247
Sempra Mexico	597		351		1,368		935
Sempra LNG	119		63		367		255
All other	2		—		4		1
Adjustments and eliminations	—		2		(1)		—
Intersegment revenues(1)	(275)		(86)		(582)		(215)
Total	$	3,013	$	2,644	$	9,013	$	8,199
INTEREST EXPENSE
SDG&E	$	104	$	103	$	307	$	307
SoCalGas	39		39		118		119
Sempra Mexico	43		31		122		95
Sempra LNG	4		8		10		39
All other	77		93		240		304
Intercompany eliminations	(8)		(10)		(21)		(46)
Total	$	259	$	264	$	776	$	818
INTEREST INCOME
SDG&E	$	—	$	1	$	1	$	2
SoCalGas	—		—		—		2
Sempra Mexico	12		14		36		47
Sempra LNG	6		25		23		65
All other	1		—		2		3
Intercompany eliminations	(3)		(13)		(12)		(43)
Total	$	16	$	27	$	50	$	76
DEPRECIATION AND AMORTIZATION
SDG&E	$	226	$	200	$	659	$	598
SoCalGas	180		165		533		486
Sempra Mexico	60		47		168		141
Sempra LNG	3		2		8		7
All other	2		4		8		10
Total	$	471	$	418	$	1,376	$	1,242
INCOME TAX EXPENSE (BENEFIT)
SDG&E	$	90	$	33	$	168	$	161
SoCalGas	(437)		(6)		(335)		95
Sempra Mexico	24		92		145		(161)
Sempra LNG	(11)		18		19		59
All other	(8)		(38)		(42)		(94)
Total	$	(342)	$	99	$	(45)	$	60
EQUITY EARNINGS (LOSSES)
Equity earnings (losses), before income tax:
Sempra Texas Utilities	$	—	$	1	$	3	$	1
Sempra LNG	137		116		404		257
All other	—		—		50		(100)
	137		117		457		158
Equity earnings, net of income tax:
Sempra Texas Utilities	207		208		480		457
Sempra Mexico	47		1		85		207
	254		209		565		664
Total	$	391	$	326	$	1,022	$	822

SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E	$	205	$	178	$	603	$	633
SoCalGas	(1,126)		(24)		(625)		425
Sempra Texas Utilities	206		209		479		458
Sempra Mexico	164		50		225		302
Sempra LNG	1		71		194		207
Discontinued operations	—		(7)		—		1,840
All other	(98)		(126)		(226)		(515)
Total	$	(648)	$	351	$	650	$	3,350
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E					$	1,560	$	1,323
SoCalGas					1,417		1,345
Sempra Mexico					260		443
Sempra LNG					362		196
All other					7		6
Total					$	3,606	$	3,313
					September 30, 2021		December 31, 2020
ASSETS
SDG&E					$	23,783	$	22,311
SoCalGas					19,919		18,460
Sempra Texas Utilities					12,580		12,542
Sempra Mexico					11,339		10,752
Sempra LNG					3,335		2,205
All other					1,094		1,209
Intersegment receivables					(1,578)		(856)
Total					$	70,472	$	66,623
EQUITY METHOD AND OTHER INVESTMENTS
Sempra Texas Utilities					$	12,580	$	12,542
Sempra Mexico					924		852
Sempra LNG					454		433
All other					—		1
Total					$	13,958	$	13,828

(1)    Revenues for reportable segments include intersegment revenues of $3 million, $24 million, $52 million and $196 million for the three months ended September 30, 2021; $7 million, $72 million, $114 million and $389 million for the nine months ended September 30, 2021; $1 million, $23 million, $18 million and $44 million for the three months ended September 30, 2020 and $4 million, $61 million, $69 million and $81 million for the nine months ended September 30, 2020 for SDG&E, SoCalGas, Sempra Mexico and Sempra LNG, respectively.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - PRINCIPLES OF CONSOLIDATION (Details)	9 Months Ended
	Sep. 30, 2021 segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of reportable segments	5

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020		Sep. 30, 2020	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Cash and cash equivalents	$ 873	$ 960	[1]
Restricted cash, current	31	22	[1]
Restricted cash, noncurrent	3	3	[1]
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$ 907	$ 985		$ 3,546	$ 217

[1] Derived from audited financial statements.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - CREDIT LOSSES (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Mar. 31, 2021
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	$ 138	$ 29
Provisions for expected credit losses	96	84
Write-offs	(28)	(11)
Ending balance	206	103
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	3	0
Reductions to expected credit losses	(2)	(3)
Ending balance	1	3
Allowance for credit losses	1	3
San Diego Gas and Electric Company [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	69	14
Provisions for expected credit losses	30	44
Write-offs	(16)	(6)
Ending balance	83	52
Southern California Gas Company [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	68	15
Provisions for expected credit losses	64	40
Write-offs	(12)	(5)
Ending balance	120	50
Cumulative Effect, Period of Adoption, Adjustment [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance		1
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance		$ 6
Allowance for credit losses
Accounts Receivable, Trade, Net [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Ending balance	146
Accounts Receivable, Trade, Net [Member] | San Diego Gas and Electric Company [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Ending balance	58
Accounts Receivable, Trade, Net [Member] | Southern California Gas Company [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Ending balance	85
Accounts receivable – other, net [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Ending balance	50
Accounts receivable – other, net [Member] | San Diego Gas and Electric Company [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Ending balance	21
Accounts receivable – other, net [Member] | Southern California Gas Company [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Ending balance	29
Other long-term assets [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Ending balance	10
Other long-term assets [Member] | San Diego Gas and Electric Company [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Ending balance	4
Other long-term assets [Member] | Southern California Gas Company [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Ending balance	6
Due from Unconsolidated Affiliates - Noncurrent [Member]
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Ending balance	1
Allowance for credit losses	1
Sempra LNG [Member]
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Maximum exposure under guarantor obligations			$ 4,000
Sempra LNG [Member] | Deferred Credits and Other [Member]
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Ending balance	7
Allowance for credit losses	$ 7

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - INVENTORIES (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Inventory [Line Items]
Natural gas	$ 169	$ 118
LNG	17	7
Materials and supplies	185	183
Inventory	371	308	[1]
San Diego Gas and Electric Company [Member]
Inventory [Line Items]
Natural gas	0	0
LNG	0	0
Materials and supplies	112	104
Inventory	112	104	[1]
Southern California Gas Company [Member]
Inventory [Line Items]
Natural gas	110	94
LNG	0	0
Materials and supplies	58	59
Inventory	$ 168	$ 153	[1]

[1] Derived from audited financial statements.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Capitalized Financing Costs Disclosure [Line Items]
Capitalized interest costs	$ 52	$ 51	$ 166	$ 149
San Diego Gas and Electric Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
Capitalized interest costs	24	26	82	79
Southern California Gas Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
Capitalized interest costs	$ 18	$ 14	$ 49	$ 39

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - OTHER INTANGIBLE ASSETS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Finite-Lived Intangible Assets [Line Items]
Gross intangible assets	$ 440		$ 440		$ 250
Accumulated amortization	(64)		(64)		(48)
Net intangible assets	376		376		202
Amortization expense	6	$ 3	16	$ 8
Amortization expense recorded against revenue	4		7
Future amortization expense per year			7
Expected amortization charged against revenue			3
Future amortization expense, per year, next four years			26
Expected amortization expense, recorded in revenue, next four years			13
Renewable energy transmission and consumption permit [Member]
Finite-Lived Intangible Assets [Line Items]
Gross intangible assets	169		169		169
Accumulated amortization	(38)		$ (38)		(32)
Renewable energy transmission and consumption permit [Member] | Minimum [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization period (years)			15 years
Renewable energy transmission and consumption permit [Member] | Maximum [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization period (years)			19 years
O&M agreement [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization period (years)			23 years
Gross intangible assets	66		$ 66		66
Accumulated amortization	(11)		$ (11)		(9)
PPA [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization period (years)			14 years
Gross intangible assets	190		$ 190		0
Accumulated amortization	(7)		(7)		0
Other [Member]
Finite-Lived Intangible Assets [Line Items]
Gross intangible assets	15		15		15
Accumulated amortization	(8)		$ (8)		$ (7)
Other [Member] | Minimum [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization period (years)			10 years
Sempra Mexico [Member] | PPA [Member]
Finite-Lived Intangible Assets [Line Items]
Gross intangible assets	$ 190		$ 190

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITIES (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Mar. 31, 2021	Dec. 31, 2020
Variable Interest Entities [Line Items]
Property plant and equipment, net	$ 42,758		$ 40,003	[1]
Finance lease obligations	1,336		1,330
Equity method investment	12,475		12,440	[1]
Assets	70,472		66,623	[1]
Sempra Texas Utilities [Member] | Oncor Holdings [Member]
Variable Interest Entities [Line Items]
Equity method investment	12,475		12,440
Sempra LNG [Member]
Variable Interest Entities [Line Items]
Maximum exposure under guarantor obligations		$ 4,000
Sempra LNG [Member] | Cameron LNG Holdings [Member]
Variable Interest Entities [Line Items]
Equity method investment	454		433
Sempra LNG [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Maximum exposure under guarantor obligations	979
San Diego Gas and Electric Company [Member]
Variable Interest Entities [Line Items]
Property plant and equipment, net	19,561		18,421	[1]
Finance lease obligations	1,279		1,276
Assets	23,783		22,311	[1]
San Diego Gas and Electric Company [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Property plant and equipment, net	1,223		1,237
Finance lease obligations	1,223		1,237
Sempra Energy [Member] | Variable Interest Entity, Primary Beneficiary [Member] | ECA LNGJV [Member]
Variable Interest Entities [Line Items]
Assets	522		207
Liabilities	$ 367		$ 49
Oncor Electric Delivery Company LLC. [Member] | Oncor Holdings [Member] | Sempra Texas Utilities [Member]
Variable Interest Entities [Line Items]
Ownership interest (as a percent)	80.25%
Sempra Texas Holdings Corp [Member] | Oncor Holdings [Member] | Sempra Texas Intermediate Holding Company LLC [Member]
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		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Settlement charges		$ 13	$ 7	$ 22
Amortization of:
Settlement charges		13	7	22
Pension benefits [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Settlement charges	$ 0	13	7	22
Defined Benefit Plan Disclosure [Line Items]
Service cost	36	31	109	97
Interest cost	28	32	84	97
Expected return on assets	(44)	(41)	(130)	(126)
Amortization of:
Prior service cost (credit)	3	3	8	9
Actuarial loss (gain)	12	9	34	26
Settlement charges	0	13	7	22
Net periodic benefit cost (credit)	35	47	112	125
Regulatory adjustments	73	37	66	31
Total expense recognized	108	84	178	156
Pension benefits [Member] | San Diego Gas and Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	9	7	26	23
Interest cost	6	7	18	22
Expected return on assets	(11)	(12)	(36)	(37)
Amortization of:
Prior service cost (credit)	0	1	0	2
Actuarial loss (gain)	1	1	2	3
Net periodic benefit cost (credit)	5	4	10	13
Regulatory adjustments	21	22	30	28
Total expense recognized	26	26	40	41
Pension benefits [Member] | Southern California Gas Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	23	20	73	64
Interest cost	19	22	59	66
Expected return on assets	(27)	(27)	(85)	(81)
Amortization of:
Prior service cost (credit)	2	2	6	6
Actuarial loss (gain)	8	6	27	19
Net periodic benefit cost (credit)	25	23	80	74
Regulatory adjustments	52	15	36	3
Total expense recognized	77	38	116	77
Other postretirement benefits [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Settlement charges	0	0	0	0
Defined Benefit Plan Disclosure [Line Items]
Service cost	6	5	17	14
Interest cost	7	8	21	24
Expected return on assets	(14)	(14)	(44)	(41)
Amortization of:
Prior service cost (credit)	(1)	(1)	(2)	(2)
Actuarial loss (gain)	(3)	(2)	(7)	(7)
Settlement charges	0	0	0	0
Net periodic benefit cost (credit)	(5)	(4)	(15)	(12)
Regulatory adjustments	5	4	15	12
Total expense recognized	0	0	0	0
Other postretirement benefits [Member] | San Diego Gas and Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	2	1	4	3
Interest cost	1	2	4	5
Expected return on assets	(2)	(3)	(7)	(8)
Amortization of:
Prior service cost (credit)	0	0	0	0
Actuarial loss (gain)	(1)	(1)	(2)	(2)
Net periodic benefit cost (credit)	0	(1)	(1)	(2)
Regulatory adjustments	0	1	1	2
Total expense recognized	0	0	0	0
Other postretirement benefits [Member] | Southern California Gas Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	5	3	13	10
Interest cost	5	7	16	19
Expected return on assets	(12)	(11)	(36)	(32)
Amortization of:
Prior service cost (credit)	(1)	(1)	(2)	(2)
Actuarial loss (gain)	(2)	(1)	(5)	(5)
Net periodic benefit cost (credit)	(5)	(3)	(14)	(10)
Regulatory adjustments	5	3	14	10
Total expense recognized	$ 0	$ 0	$ 0	$ 0

XML

GENERAL INFORMATION AND OTHER FINANCIAL DATA - RABBI TRUST (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Rabbi trust	$ 539	$ 512	[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	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
(Loss) income from continuing operations, net of income tax	$ (632)	$ 428	$ 751	$ 1,823
Earnings attributable to noncontrolling interests	(5)	(22)	(48)	(191)
Preferred dividends	(11)	(48)	(52)	(121)
Preferred dividends of subsidiary	0	0	(1)	(1)
Earnings from continuing operations attributable to common shares for diluted EPS	(648)	358	650	1,510
(Loss) income from discontinued operations, net of income tax	0	(7)	0	1,850
Earnings attributable to noncontrolling interests	0	0	0	(10)
(Losses) earnings from discontinued operations attributable to Sempra	0	(7)	0	1,840
(Losses) earnings attributable to common shares	$ (648)	$ 351	$ 650	$ 3,350
Weighted-average common shares outstanding for basic EPS	319,144,000	289,490,000	309,350,000	291,771,000
Dilutive effect of stock options and RSUs (in shares)	0	1,092,000	797,000	1,164,000
Dilutive effect of mandatory convertible preferred stock (in shares)	0	0	707,000	0
Weighted-average common shares outstanding for diluted EPS (in shares)	319,144,000	290,582,000	310,854,000	292,935,000
(Losses) earnings from continuing operations (in dollars per share)	$ (2.03)	$ 1.23	$ 2.10	$ 5.17
(Losses) earnings from discontinued operations (in dollars per share)	0	(0.02)	0	6.31
(Losses) earnings (in dollars per share)	(2.03)	1.21	2.10	11.48
(Losses) earnings from continuing operations (in dollars per share)	(2.03)	1.23	2.09	5.15
(Losses) earnings from discontinued operations (in dollars per share)	0	(0.02)	0	6.28
(Losses) earnings (in dollars per share)	$ (2.03)	$ 1.21	$ 2.09	$ 11.43
Vested RSUs included in basic WASO (in shares)	451,000	535,000	453,000	536,000
Performance-based RSUs [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)			323,889
Service-based RSUs [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)			143,980
Stock options, RSAs and RSUs [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Non-qualified stock options granted (in shares)			222,620
Stock Options and Restricted Stock Units
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)	699
Stock options, RSAs and RSUs [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)	147,840	142,100	240,654	204,426
Convertible Preferred Stock Series A [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)	639,733		3,037,812
Convertible Preferred Stock [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)		19,292,641		19,292,641

XML

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	[1]			$ 23,373
Ending balance		$ 24,554		24,554
Total accumulated other comprehensive income (loss) [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(444)	$ (542)	(500)	$ (939)
OCI before reclassifications		7	13	25	(273)
Amounts reclassified from AOCI		19	16	57	699
Net OCI		26	29	82	426
Ending balance		(418)	(513)	(418)	(513)
Foreign currency translation adjustments [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(88)	(83)	(64)	(607)
OCI before reclassifications		0	6	(24)	(115)
Amounts reclassified from AOCI		0	0	0	645
Net OCI		0	6	(24)	530
Ending balance		(88)	(77)	(88)	(77)
Foreign currency translation adjustments [Member] | IEnova [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
AOCI associated with noncontrolling interests		(4)	3	20	3
Financial instruments [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(265)	(361)	(331)	(215)
OCI before reclassifications		15	14	52	(153)
Amounts reclassified from AOCI		16	4	45	25
Net OCI		31	18	97	(128)
Ending balance		(234)	(343)	(234)	(343)
Financial instruments [Member] | IEnova [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
AOCI associated with noncontrolling interests		(2)	2	12	2
Pension and other postretirement benefits [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(91)	(98)	(105)	(117)
OCI before reclassifications		(8)	(7)	(3)	(5)
Amounts reclassified from AOCI		3	12	12	29
Net OCI		(5)	5	9	24
Ending balance		(96)	(93)	(96)	(93)
Pension and other postretirement benefits [Member] | San Diego Gas and Electric Company [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amounts reclassified from AOCI					3
San Diego Gas and Electric Company [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	[1]			7,730
Ending balance		8,334		8,334
San Diego Gas and Electric Company [Member] | Total accumulated other comprehensive income (loss) [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(10)	(12)	(10)	(16)
Amounts reclassified from AOCI		1		1	4
Net OCI		(1)		1	4
Ending balance		(9)	12	(9)	12
San Diego Gas and Electric Company [Member] | Pension and other postretirement benefits [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(10)	(12)	(10)	(16)
Amounts reclassified from AOCI		1		1	4
Net OCI		(1)		1	4
Ending balance		(9)	12	(9)	12
Southern California Gas Company [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	[1]			5,144
Ending balance		5,246		5,246
Southern California Gas Company [Member] | Total accumulated other comprehensive income (loss) [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(30)	(22)	(31)	(23)
Amounts reclassified from AOCI		1		2	1
Net OCI		(1)		(2)	1
Ending balance		(29)	(22)	(29)	(22)
Southern California Gas Company [Member] | Financial instruments [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(13)	(13)	(13)	(13)
Amounts reclassified from AOCI		0		0	0
Net OCI		0		0	0
Ending balance		(13)	(13)	(13)	(13)
Southern California Gas Company [Member] | Pension and other postretirement benefits [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(17)	(9)	(18)	(10)
Amounts reclassified from AOCI		1		2	1
Net OCI		(1)		(2)	1
Ending balance		$ (16)	$ (9)	$ (16)	$ (9)

[1] 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		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	$ (259)	$ (264)	$ (776)	$ (818)
Equity earnings	391	326	1,022	822
Energy-related businesses	453	343	1,174	1,000
Other Income (Expense), Net	55	(29)	(52)	163
(Loss) income from continuing operations before income taxes and equity earnings	(1,365)	201	(316)	1,061
(Losses) earnings from discontinued operations attributable to Sempra	0	(7)	0	1,840
Income tax benefit (expense)	342	(99)	45	(60)
Net (loss) income	(632)	421	751	3,673
Earnings attributable to noncontrolling interest	(5)	(22)	(48)	(201)
San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(104)	(103)	(307)	(307)
Other Income (Expense), Net	(4)	2	(61)	(47)
(Loss) income from continuing operations before income taxes and equity earnings	295	211	771	794
Income tax benefit (expense)	(90)	(33)	(168)	(161)
Net (loss) income			603	633
Southern California Gas Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(39)	(39)	(118)	(119)
Other Income (Expense), Net	39	7	2	(21)
(Loss) income from continuing operations before income taxes and equity earnings	(1,563)	(30)	(959)	521
Income tax benefit (expense)	437	6	335	(95)
Net (loss) income	(1,126)	(24)	(624)	426
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	19	16	57	696
Reclassification out of Accumulated Other Comprehensive Income [Member] | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	1	0	1	1
Reclassification out of Accumulated Other Comprehensive Income [Member] | Southern California Gas Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	1	0	2	1
Reclassification out of Accumulated Other Comprehensive Income [Member] | Foreign currency translation adjustments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
(Losses) earnings from discontinued operations attributable to Sempra			0	645
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
(Loss) income from continuing operations before income taxes and equity earnings	23	4	63	43
Income tax benefit (expense)	(7)	0	(16)	(12)
Net (loss) income			47	31
Earnings attributable to common shares	16	4	45	25
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest [Member] | Interest rate instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(1)	3	0	6
Equity earnings	19	5	57	8
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest [Member] | Foreign exchange instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Equity earnings			1	(2)
Energy-related businesses			1	(2)
Other Income (Expense), Net			0	(1)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest [Member] | Interest rate and foreign exchange instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense			0	1
Other Income (Expense), Net	5	(4)	4	33
Reclassification out of Accumulated Other Comprehensive Income [Member] | Gains (Losses) on Cash Flow hedges Attributable to Noncontrolling Interests [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to noncontrolling interest			(2)	(6)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Gain (Loss) on Pension and Other Postretirement Benefits [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income (Expense), Net	3	3	6	6
(Losses) earnings from discontinued operations attributable to Sempra			0	6
Reclassification out of Accumulated Other Comprehensive Income [Member] | Gain (Loss) on Pension and Other Postretirement Benefits [Member] | Southern California Gas Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income (Expense), Net	1	0	1	0
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plans Adjustment, Net Prior Service Attributable to Parent [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income (Expense), Net	1	1	3	3
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plans Adjustment, Net Prior Service Attributable to Parent [Member] | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income (Expense), Net	1	0	1	1
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plans Adjustment, Net Prior Service Attributable to Parent [Member] | Southern California Gas Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income (Expense), Net			1	1
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plans Adjustment, Net Settlements Attributable to Parent [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income (Expense), Net	0	13	7	22
Reclassification out of Accumulated Other Comprehensive Income [Member] | Pension and Other Postretirement Benefits [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
(Loss) income from continuing operations before income taxes and equity earnings	4	17	16	37
(Losses) earnings from discontinued operations attributable to Sempra			0	(2)
Income tax benefit (expense)	(1)	(5)	(4)	(9)
Net (loss) income	$ 3	$ 12	$ 12	$ 26

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - SHAREHOLDER'S EQUITY AND NONCONTROLLING INTEREST (Details) $ / shares in Units, $ / shares in Units, $ in Billions							1 Months Ended						3 Months Ended			9 Months Ended
	Nov. 01, 2021 USD ($)	Oct. 01, 2021 USD ($)	Apr. 04, 2021 USD ($)	Aug. 04, 2020 $ / shares shares	Jul. 01, 2020 USD ($)	Jun. 19, 2020 USD ($) $ / shares shares	Oct. 31, 2021 USD ($)	Sep. 30, 2021 USD ($) class $ / shares shares	Sep. 30, 2021 MXN ($) class $ / shares shares	Jul. 31, 2021 USD ($)	May 31, 2021 USD ($) shares	Mar. 31, 2020 USD ($)	Sep. 30, 2021 USD ($) class shares	Sep. 30, 2020 USD ($)	Mar. 31, 2020 USD ($)	Sep. 30, 2021 USD ($) class shares	Sep. 30, 2020 USD ($) shares	Jul. 15, 2021 shares	Jul. 06, 2021	Apr. 30, 2021	Jan. 15, 2021 shares	Jul. 06, 2020 USD ($) shares	Mar. 30, 2020	Dec. 31, 2019	Sep. 11, 2007 USD ($) shares
Subsidiary, Sale of Stock [Line Items]
Shares issued (in shares) | shares											12,306,777
Repurchases of common stock													$ 1,000,000	$ 501,000,000		$ 39,000,000	$ 565,000,000
Equitization of long-term debt for deficit held by NCI																	22,000,000
Income Tax Expense (Benefit)													$ (342,000,000)	$ 99,000,000		$ (45,000,000)	$ 60,000,000
Limited Partnership distributions (as a percent)			85.00%
Number of authorized classes of units | class								2	2				2			2
Limited Partnership Agreement, Ownership Percentage								80.00%	80.00%				80.00%			80.00%
Common Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Stock repurchase program, authorized amount																						$ 2,000,000,000			$ 2,000,000,000
Stock repurchase program, authorized number of shares (in shares) | shares								0	0				0			0						25,000,000			40,000,000
Accelerated share repurchase program, prepaid amount					$ 500,000,000
Share repurchase program, number of shares repurchased (in shares) | shares				4,089,375
Common stock repurchased, average price (in dollars per share) | $ / shares				$ 122.27
Series B Preferred Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Shares converted | shares																		5,750,000
Convertible Preferred Stock Series B [Member]
Subsidiary, Sale of Stock [Line Items]
Shares converted | shares																		4,256,720
Preferred stock, conversion ratio																		0.7403
Series A Preferred Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Shares converted | shares																					17,250,000
Convertible Preferred Stock Series A [Member]
Subsidiary, Sale of Stock [Line Items]
Shares converted | shares																					13,781,025
Preferred stock, conversion ratio																					0.7989
Series C Preferred Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Preferred stock, shares issued (in shares) | shares						900,000
Preferred stock, redemption price per share (in dollars per share) | $ / shares						$ 1,000
Proceeds from issuance of preferred stock						$ 889,000,000
Preferred stock, discount						$ 11,000,000
Debt Instrument, Interest Rate, Stated Percentage						4.875%
Forecast [Member]
Subsidiary, Sale of Stock [Line Items]
Direct and indirect net debt at closing		$ 8,370,000,000
Subsequent Event [Member] | KKR [Member]
Subsidiary, Sale of Stock [Line Items]
Disbursements to be paid	$ 300,000,000
Repayment of disbursements, rate (as a percent)	5.00%
Infraestructura Energética Nova [Member]
Subsidiary, Sale of Stock [Line Items]
Common stock acquired (in shares) | shares								51,014,545	51,014,545		381,015,194
Common stock exchange ratio											0.0323
Value of shares acquired								$ 202,000,000	$ 4.0
Common Shares Repurchased, Share Price | (per share)								$ 3.95	$ 78.97
Increase in stockholders' equity								$ 84,000,000
Infraestructura Energética Nova [Member] | Subsequent Event [Member]
Subsidiary, Sale of Stock [Line Items]
Income Tax Expense (Benefit)							$ 72,000,000
Sempra Energy [Member] | Series B Preferred Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Percentage of common shares held (as a percent)																			1.00%
LA Storage [Member] | Liberty Gas Storage, LLC [Member]
Subsidiary, Sale of Stock [Line Items]
Ownership percentage												100.00%			100.00%
IEnova [Member]
Subsidiary, Sale of Stock [Line Items]
Purchase price of equity interests								14,000,000			$ 1,361,000,000
Transaction costs								$ 1,000,000			$ 12,000,000
Ownership interest (as a percent)								99.90%	99.90%		96.40%		99.90%			99.90%				70.20%
Noncontrolling Interest, Remaining Shares Of Noncontrolling Interest | shares								1,212,981	1,212,981				1,212,981			1,212,981
IEnova [Member] | Subsequent Event [Member]
Subsidiary, Sale of Stock [Line Items]
Ownership interest (as a percent)		99.90%
Sempra Global | KKR [Member]
Subsidiary, Sale of Stock [Line Items]
Purchase price of equity interests			$ 3,370,000,000
Sempra Global | Subsequent Event [Member] | KKR [Member]
Subsidiary, Sale of Stock [Line Items]
Noncontrolling Interest, Payment For Reimbursement of Expenses		$ 149,000,000
Sale of Noncontrolling Interest, Downward Price Adjustment		$ 1,000,000
Sempra Global | KKR [Member]
Subsidiary, Sale of Stock [Line Items]
Ownership percentage			20.00%
Liberty Gas Storage, LLC [Member] | Sempra LNG [Member]
Subsidiary, Sale of Stock [Line Items]
Payment to acquire remaining interest												$ 7,000,000
Equitization of long-term debt for deficit held by NCI												22,000,000
Increase from equity of noncontrolling interest												$ 2,000,000
Sempra Mexico [Member] | ICM Ventures Holdings B.V. [Member]
Subsidiary, Sale of Stock [Line Items]
Additional ownership percentage																			17.50%
Sempra Mexico [Member] | Infraestructura Energética Nova [Member]
Subsidiary, Sale of Stock [Line Items]
Common stock repurchased (in shares) | shares																	57,547,381
Repurchases of common stock																	$ 167,000,000
Sempra Mexico [Member] | ICM Ventures Holdings B.V. [Member]
Subsidiary, Sale of Stock [Line Items]
Ownership interest (as a percent)												82.50%			82.50%									53.70%
Payment to acquire remaining interest										$ 7,000,000					$ 9,000,000
Sempra Mexico [Member] | IEnova [Member]
Subsidiary, Sale of Stock [Line Items]
Ownership interest (as a percent)														69.20%			69.20%							66.60%
Sempra LNG [Member] | Liberty Gas Storage, LLC [Member]
Subsidiary, Sale of Stock [Line Items]
Ownership percentage																							24.60%
Sempra LNG [Member] | Liberty Gas Storage, LLC [Member] | Liberty Gas Storage, LLC [Member]
Subsidiary, Sale of Stock [Line Items]
Ownership percentage												100.00%			100.00%

XML

GENERAL INFORMATION AND OTHER FINANCIAL DATA - OTHER NONCONTROLLING INTERESTS (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 30	$ 1,541	[1]
IEnova [Member] | Sempra Mexico [Member]
Noncontrolling Interest [Line Items]
Ownership percentage	0.10%	29.80%
Other noncontrolling interests	$ 2	$ 1,487
IEnova subsidiaries [Member] | Sempra Mexico [Member]
Noncontrolling Interest [Line Items]
Ownership percentage	0.00%	17.50%
Other noncontrolling interests	$ 0	$ 7
ECA LNG Proposed Liquefaction Project [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Ownership percentage	16.60%	29.00%
Other noncontrolling interests	$ 28	$ 46
PXISE Energy Solutions LLC [Member] | Parent and Other [Member]
Noncontrolling Interest [Line Items]
Ownership percentage	20.00%	20.00%
Other noncontrolling interests	$ 0	$ 1

[1] Derived from audited financial statements.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - DUE TO DUE FROM AFFILIATES (Details)	9 Months Ended	12 Months Ended
	Sep. 30, 2021 USD ($)	Dec. 31, 2020 USD ($)		Sep. 30, 2021 MXN ($)	Mar. 31, 2021
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	$ 30,000,000	$ 20,000,000	[1]
Due from unconsolidated affiliates - noncurrent	684,000,000	780,000,000	[1]
Due to unconsolidated affiliates, current	(42,000,000)	(45,000,000)	[1]
Due to unconsolidated affiliates - noncurrent	(286,000,000)	$ (234,000,000)	[1]
Maximum borrowing capacity	$ 6,685,000,000
ESJ joint venture [Member] | ESJ [Member]
Related Party Transaction [Line Items]
Additional ownership percentage					50.00%
ESJ joint venture [Member] | LIBOR [Member]
Related Party Transaction [Line Items]
Spread on variable rate (as a percent)		1.96%
Interest rate on due from affiliate, noncurrent		2.11%
TAG Pipeline Norte [Member]
Related Party Transaction [Line Items]
Interest rate on due from affiliate, noncurrent	3.06%
TAG Pipeline Norte [Member] | LIBOR [Member]
Related Party Transaction [Line Items]
Spread on variable rate (as a percent)	2.90%
Various Affiliates [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current	$ 0	$ (4,000,000)
San Diego Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	1,000,000	0
Due to unconsolidated affiliates, current	(61,000,000)	(64,000,000)	[1]
Maximum borrowing capacity	1,500,000,000
San Diego Gas and Electric Company [Member] | Due to/from Sempra Energy [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current	(45,000,000)	(38,000,000)
Income taxes due (to) from Sempra Energy	29,000,000	0
San Diego Gas and Electric Company [Member] | Due to/from SoCalGas [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current	(9,000,000)	(21,000,000)
San Diego Gas and Electric Company [Member] | Due to/from Other affiliates [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current	(7,000,000)	(5,000,000)
Southern California Gas Company [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	11,000,000	22,000,000	[1]
Due to unconsolidated affiliates, current	(45,000,000)	(31,000,000)	[2]
Maximum borrowing capacity	750,000,000
Southern California Gas Company [Member] | Due to/from Sempra Energy [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current	(45,000,000)	(31,000,000)
Income taxes due (to) from Sempra Energy	1,000,000	(37,000,000)
Southern California Gas Company [Member] | Due to/from Other affiliates [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	2,000,000	1,000,000
Southern California Gas Company [Member] | Due to/from SDG&E
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	9,000,000	21,000,000
Sempra Mexico [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - noncurrent	(286,000,000)	(234,000,000)
Sempra Mexico [Member] | ESJ joint venture [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	0	85,000,000
Accrued interest receivable		1,000,000
Sempra Mexico [Member] | IMG [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	684,000,000	695,000,000
Due from affiliates, allowance for credit loss	1,000,000	3,000,000
Accrued interest receivable	2,000,000	2,000,000
Maximum borrowing capacity	$ 689,000,000			$ 14,200,000,000
Sempra Mexico [Member] | IMG [Member] | Interbank Equilibrium Rate [Member]
Related Party Transaction [Line Items]
Spread on variable rate (as a percent)	2.20%
Interest rate on due from affiliate, noncurrent	7.02%
Sempra Mexico [Member] | TAG Pipeline Norte [Member]
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%			5.50%
Sempra Mexico [Member] | TAG JV Notes [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - noncurrent	$ (174,000,000)	(166,000,000)
Stated rate of debt (as a percent)	5.74%			5.74%
Other Long term Debt Currently Through December 2021 [Member] | Sempra Mexico [Member] | TAG Pipeline Norte [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current	$ (42,000,000)	(41,000,000)
Due to unconsolidated affiliates - noncurrent	(71,000,000)	(68,000,000)
Other Long term Debt Currently Through January 2024 [Member] | Sempra Mexico [Member] | TAG Pipeline Norte [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - noncurrent	(21,000,000)	0
Five Point Five Percent Notes Due 2029 | Sempra Mexico [Member] | TAG Pipeline Norte [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - noncurrent	$ (20,000,000)	$ 0
Stated rate of debt (as a percent)	5.50%			5.50%

[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		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Related Party Transaction [Line Items]
Revenue from related parties	$ 7	$ 9	$ 22	$ 31
Costs of sales to related parties	0	9	11	35
Interest income	11	12	38	44
Interest expense	4	4	11	11
San Diego Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Revenue from related parties	3	1	7	4
Costs of sales to related parties	20	17	75	56
Southern California Gas Company [Member]
Related Party Transaction [Line Items]
Revenue from related parties	24	23	72	61
Costs of sales to related parties	$ (2)	$ 2	$ 1	$ 2

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - OTHER (EXPENSE) INCOME, NET (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Other Income [Line Items]
Allowance for equity funds used during construction	$ 31	$ 34	$ 103	$ 96
Investment gains	0	16	28	9
(Losses) gains on interest rate and foreign exchange instruments, net	(3)	19	(26)	(129)
Foreign currency transaction (losses) gains, net(2)	(17)	15	(10)	(95)
Non-service component of net periodic benefit cost	(66)	(48)	(52)	(45)
Fine related to Energy Efficiency Program inquiry	0	(6)	0	(6)
Interest on regulatory balancing accounts, net	2	0	5	13
Sundry, net	(2)	(1)	4	(6)
Total	(55)	29	52	(163)
San Diego Gas and Electric Company [Member]
Other Income [Line Items]
Allowance for equity funds used during construction	18	21	63	61
Non-service component of net periodic benefit cost	(15)	(18)	(10)	(15)
Fine related to Energy Efficiency Program inquiry	0	(6)	0	(6)
Interest on regulatory balancing accounts, net	2	0	5	8
Sundry, net	(1)	1	3	(1)
Total	4	(2)	61	47
Southern California Gas Company [Member]
Other Income [Line Items]
Allowance for equity funds used during construction	13	11	36	29
Non-service component of net periodic benefit cost	(49)	(15)	(30)	(3)
Interest on regulatory balancing accounts, net	0	0	0	5
Sundry, net	(3)	(3)	(8)	(10)
Total	(39)	(7)	(2)	21
Sempra Mexico [Member] | IMG [Member]
Other Income [Line Items]
Foreign currency transaction (losses) gains, net(2)	$ (18)	$ 15	$ (13)	$ (120)

XML

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INCOME TAXES (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax (benefit) expense from continuing operations	$ (342)	$ 99	$ (45)	$ 60
(Loss) income from continuing operations before income taxes and equity earnings	(1,365)	201	(316)	1,061
Equity earnings (losses), before income tax:	137	117	457	158
Pretax (loss) income	$ (1,228)	$ 318	$ 141	$ 1,219
Effective income tax rate (as a percent)	28.00%	31.00%	(32.00%)	5.00%
Income tax benefit related to the increase in outside basis differences				$ 7
San Diego Gas and Electric Company [Member]
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax (benefit) expense from continuing operations	$ 90	$ 33	$ 168	161
(Loss) income from continuing operations before income taxes and equity earnings	$ 295	$ 211	$ 771	$ 794
Effective income tax rate (as a percent)	31.00%	16.00%	22.00%	20.00%
Southern California Gas Company [Member]
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax (benefit) expense from continuing operations	$ (437)	$ (6)	$ (335)	$ 95
(Loss) income from continuing operations before income taxes and equity earnings	$ (1,563)	$ (30)	$ (959)	$ 521
Effective income tax rate (as a percent)	28.00%	20.00%	35.00%	18.00%

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REVENUES - DISAGGREGATION OF REVENUE (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 2,648	$ 2,348	$ 8,259	$ 7,479
Utilities regulatory revenues	235	200	417	352
Other revenues	130	96	337	368
Total revenues	3,013	2,644	9,013	8,199
Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,325	2,101	7,422	6,847
Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	323	247	837	632
Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,320	1,077	4,823	4,171
Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,328	1,271	3,436	3,308
Operating Segments [Member] | San Diego Gas and Electric Company [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,369	1,301	3,755	3,610
Utilities regulatory revenues	95	171	364	366
Other revenues	0	0	0	0
Total revenues	1,464	1,472	4,119	3,976
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,369	1,301	3,755	3,610
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	145	126	580	518
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,224	1,175	3,175	3,092
Operating Segments [Member] | Southern California Gas Company [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	966	813	3,685	3,261
Utilities regulatory revenues	140	29	53	(14)
Other revenues	0	0	0	0
Total revenues	1,106	842	3,738	3,247
Operating Segments [Member] | Southern California Gas Company [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	966	813	3,685	3,261
Operating Segments [Member] | Southern California Gas Company [Member] | Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments [Member] | Southern California Gas Company [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	966	813	3,685	3,261
Operating Segments [Member] | Southern California Gas Company [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments [Member] | Sempra Mexico [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	341	256	920	658
Utilities regulatory revenues	0	0	0	0
Other revenues	256	95	448	277
Total revenues	597	351	1,368	935
Operating Segments [Member] | Sempra Mexico [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	17	12	61	42
Operating Segments [Member] | Sempra Mexico [Member] | Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	324	244	859	616
Operating Segments [Member] | Sempra Mexico [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	231	159	635	439
Operating Segments [Member] | Sempra Mexico [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	110	97	285	219
Operating Segments [Member] | Sempra LNG [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	144	35	260	56
Utilities regulatory revenues	0	0	0	0
Other revenues	(25)	28	107	199
Total revenues	119	63	367	255
Operating Segments [Member] | Sempra LNG [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments [Member] | Sempra LNG [Member] | Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	144	35	260	56
Operating Segments [Member] | Sempra LNG [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	143	33	257	51
Operating Segments [Member] | Sempra LNG [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1	2	3	5
Consolidation, Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(172)	(57)	(361)	(106)
Utilities regulatory revenues	0	0	0	0
Other revenues	(101)	(27)	(218)	(108)
Total revenues	(273)	(84)	(579)	(214)
Consolidation, Eliminations [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(27)	(25)	(79)	(66)
Consolidation, Eliminations [Member] | Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(145)	(32)	(282)	(40)
Consolidation, Eliminations [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(165)	(54)	(334)	(98)
Consolidation, Eliminations [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ (7)	$ (3)	$ (27)	$ (8)

XML

REVENUES - PERFORMANCE OBLIGATIONS (Details) $ in Millions	Sep. 30, 2021 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 5,683
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 88
Revenues to be recognized, period of recognition	3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 368
Revenues to be recognized, period of recognition	1 year
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	$ 367
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	$ 367
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	$ 364
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	$ 4,129
Revenues to be recognized, period of recognition
San Diego Gas and Electric Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 84
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 1
Revenues to be recognized, period of recognition	3 months
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
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 [Member] | 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 [Member] | 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 [Member] | 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 [Member] | 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	$ 67
Revenues to be recognized, period of recognition

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REVENUES - CONTRACT LIABILITIES (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Contract with Customer, Liability [Roll Forward]
Contract liabilities, opening balance	$ (207)	$ (163)
Revenue from performance obligations satisfied during reporting period	36	3
Payments received in advance	(1)	0
Contract liabilities, closing balance	(172)	(160)
Other Current Liabilities [Member]
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(8)
Deferred Credits and Other [Member]
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(164)
San Diego Gas and Electric Company [Member]
Contract with Customer, Liability [Roll Forward]
Contract liabilities, opening balance	(87)	(91)
Revenue from performance obligations satisfied during reporting period	3	3
Contract liabilities, closing balance	(84)	$ (88)
San Diego Gas and Electric Company [Member] | Other Current Liabilities [Member]
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(4)
San Diego Gas and Electric Company [Member] | Deferred Credits and Other [Member]
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	$ (80)

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REVENUES - RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 1,350	$ 1,462
Accounts receivable – trade, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1,216	1,447
Accounts receivable – other, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	17	12
Due from unconsolidated affiliates – current [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	2	3
Other long-term assets [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	115	0
San Diego Gas and Electric Company [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	703	583
San Diego Gas and Electric Company [Member] | Accounts receivable – trade, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	642	573
San Diego Gas and Electric Company [Member] | Accounts receivable – other, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	11	8
San Diego Gas and Electric Company [Member] | Due from unconsolidated affiliates – current [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	3	2
San Diego Gas and Electric Company [Member] | Other long-term assets [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	47	0
Southern California Gas Company [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	536	790
Southern California Gas Company [Member] | Accounts receivable – trade, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	462	786
Southern California Gas Company [Member] | Accounts receivable – other, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	6	4
Southern California Gas Company [Member] | Other long-term assets [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 68	$ 0

XML

REGULATORY MATTERS - REGULATORY ACCOUNTS (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Net Regulatory Assets (Liabilities) Sempra Energy Consolidated [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ (1,323)	$ (1,500)
San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	331	139
San Diego Gas and Electric Company [Member] | Fixed-price contracts and other derivatives [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(88)	(53)
San Diego Gas and Electric Company [Member] | Deferred income taxes (refundable) recoverable in rates [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	72	22
San Diego Gas and Electric Company [Member] | Pension and other postretirement benefit plan obligations [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	19	50
San Diego Gas and Electric Company [Member] | Removal obligations [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(2,228)	(2,121)
San Diego Gas and Electric Company [Member] | Environmental costs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	55	56
San Diego Gas and Electric Company [Member] | Sunrise Powerlink fire mitigation [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	121	121
San Diego Gas and Electric Company [Member] | Regulatory Balancing Accounts, Commodity – electric [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	85	72
San Diego Gas and Electric Company [Member] | Regulatory Balancing Accounts, Gas transportation [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	23	35
San Diego Gas and Electric Company [Member] | Regulatory Balancing Accounts, Safety and reliability [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	60	67
San Diego Gas and Electric Company [Member] | Regulatory Balancing Accounts, Public purpose programs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(138)	(158)
San Diego Gas and Electric Company [Member] | GRC retroactive impacts [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	14	56
San Diego Gas and Electric Company [Member] | Regulatory Balancing Accounts, Other balancing accounts [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	535	233
San Diego Gas and Electric Company [Member] | Other regulatory assets [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	110	72
San Diego Gas and Electric Company [Member] | Net Regulatory Assets (Liabilities) SDGE [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(1,360)	(1,548)
Southern California Gas Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	472	218
Southern California Gas Company [Member] | Deferred income taxes (refundable) recoverable in rates [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	9	(82)
Southern California Gas Company [Member] | Pension and other postretirement benefit plan obligations [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	342	417
Southern California Gas Company [Member] | Employee benefit costs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	37	37
Southern California Gas Company [Member] | Removal obligations [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(649)	(685)
Southern California Gas Company [Member] | Environmental costs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	35	36
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Commodity - gas including transportation [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(138)	(56)
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Safety and reliability [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	299	335
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Public purpose programs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(274)	(253)
Southern California Gas Company [Member] | GRC retroactive impacts [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	51	202
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Other balancing accounts [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	85	(58)
Southern California Gas Company [Member] | Other regulatory assets [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	160	75
Southern California Gas Company [Member] | Net Regulatory Assets (Liabilities) SoCalGas [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(43)	(32)
Sempra Mexico [Member] | Deferred income taxes (refundable) recoverable in rates [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ 80	$ 80

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REGULATORY MATTERS - GENERAL RATE CASE (Details) - General Rate Case [Member] - USD ($) $ in Millions	1 Months Ended
	May 31, 2021	Apr. 30, 2020
San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
Tracked income tax expense liability		$ 86
Southern California Gas Company [Member]
General Rate Case [Line Items]
Tracked income tax expense liability		$ 89
2019 GRC FD - 2022 Requirement [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 87
Percent increase	3.92%
2019 GRC FD - 2022 Requirement [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 142
Percent increase	4.53%
2019 GRC FD - 2023 Requirement [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 86
Percent increase	3.70%
2019 GRC FD - 2023 Requirement [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 130
Percent increase	3.97%

XML

REGULATORY MATTERS - COST OF CAPITAL & FERC (Details) - USD ($) $ in Millions	1 Months Ended		3 Months Ended			9 Months Ended		12 Months Ended
	Mar. 31, 2020	Oct. 31, 2019	Sep. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2021	Dec. 31, 2019	Jan. 01, 2022	Aug. 31, 2021
California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
CCM Benchmark Rate, Variable Rate									1.00%
San Diego Gas and Electric Company [Member]
Public Utilities, General Disclosures [Line Items]
FERC requirement to maintain common equity ratio, at or above (percent)		10.60%
Base ROE		10.10%
Additional Bps		0.50%
Additional FERC revenues				$ 12
San Diego Gas and Electric Company [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
CCM Benchmark Rate									4.498%
Authorized Capital Structure, Common Equity Ratio									52.00%		54.00%
Authorized Capital Structure, Authorized ROE									10.20%		10.55%
Authorized Capital Structure, Cost of Debt									4.59%		3.84%
Authorized Capital Structure, Proposed Return on Base Rate									7.55%		7.46%
Percentage below CCM benchmark rate								1.17%
San Diego Gas and Electric Company [Member] | California Public Utilities Commission [Member] | Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Authorized Capital Structure, Authorized ROE										9.62%
San Diego Gas and Electric Company [Member] | California Public Utilities Commission [Member] | Energy Efficiency Program Inquiry [Member]
Public Utilities, General Disclosures [Line Items]
Equity losses on investment			$ 36			$ 51
Litigation fines					$ 6		$ 6
Loss contingency, loss in period, after tax			$ 29			$ 44
San Diego Gas and Electric Company [Member] | Federal Energy Regulatory Commission [Member]
Public Utilities, General Disclosures [Line Items]
Additional FERC revenues				$ 17
San Diego Gas and Electric Company [Member] | Common Equity [Member] | Federal Energy Regulatory Commission [Member]
Public Utilities, General Disclosures [Line Items]
Approved return on equity, percentage	10.05%
Southern California Gas Company [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
CCM Benchmark Rate									4.029%

XML

ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - ACQUISITION ACTIVITY (Details) $ in Millions	Mar. 19, 2021 USD ($) MW	Mar. 18, 2021	Dec. 31, 2020
Saavi Energia [Member] | ESJ [Member]
Business Acquisition [Line Items]
Ownership percentage	50.00%
IEnova [Member] | Saavi Energia Asset Acquisition [Member] | Sempra Mexico [Member]
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
IEnova [Member] | ESJ [Member] | Sempra Mexico [Member]
Business Acquisition [Line Items]
Ownership percentage		50.00%	50.00%

XML

ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - DISCONTINUED OPERATIONS (Details) - USD ($) $ in Millions	1 Months Ended		3 Months Ended		9 Months Ended
	Jun. 30, 2020	Apr. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
(Loss) income from discontinued operations, net of income tax			$ 0	$ (7)	$ 0	$ 1,850
Earnings attributable to noncontrolling interests			0	0	0	(10)
(Losses) earnings from discontinued operations attributable to Sempra			$ 0	(7)	$ 0	1,840
Discontinued Operations, Held-for-sale [Member] | Sempra South American Utilities [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
(Loss) gain on sale of discontinued operations				(16)		2,899
Revenues				0		570
Cost of sales				0		(364)
Operating expenses				0		(66)
Interest and other				0		(3)
Income before income taxes				(16)		3,036
Income tax benefit (expense)				9		(1,186)
(Loss) income from discontinued operations, net of income tax				(7)		1,850
(Losses) earnings from discontinued operations attributable to Sempra				$ (7)		$ 1,840
Cumulative foreign translation adjustments	$ 645
Luz Del Sur [Member] | Discontinued Operations, Held-for-sale [Member] | Sempra South American Utilities [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest (as a percent)		83.60%
Consideration to be received		$ 3,549
Pretax gain on sale		2,271
(Loss) gain on sale of discontinued operations		$ 1,499
Chilquinta Energia [Member] | Discontinued Operations, Held-for-sale [Member] | Sempra South American Utilities [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest (as a percent)	100.00%
Consideration to be received	$ 2,216
Pretax gain on sale	628
(Loss) gain on sale of discontinued operations	$ 248
Eletrans | Discontinued Operations, Held-for-sale [Member] | Sempra South American Utilities [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest (as a percent)	50.00%

XML

INVESTMENTS IN UNCONSOLIDATED ENTITIES - NARRATIVE (Details)	1 Months Ended	3 Months Ended		9 Months Ended
	Jul. 31, 2020 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2020 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2020 USD ($)	Jul. 31, 2021 bank	Mar. 31, 2021 USD ($)	Mar. 19, 2021	Mar. 18, 2021	Dec. 31, 2020
Schedule of Equity Method Investments [Line Items]
Distributions from investments				$ 365,000,000	$ 761,000,000
Charge to equity earnings		$ (391,000,000)	$ (326,000,000)	(1,022,000,000)	(822,000,000)
Cameron LNG [Member] | Other Long Term Debt, Due July 2030
Schedule of Equity Method Investments [Line Items]
Maximum exposure under guarantor obligations							$ 4,000,000,000
R B S Sempra Commodities [Member]
Schedule of Equity Method Investments [Line Items]
Charge to equity earnings				50,000,000	100,000,000
Sempra Texas Utilities [Member] | Oncor Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Contribution		151,000,000	209,000,000	151,000,000	209,000,000
Sempra LNG [Member]
Schedule of Equity Method Investments [Line Items]
Maximum exposure under guarantor obligations							$ 4,000,000,000
Sempra LNG [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Schedule of Equity Method Investments [Line Items]
Maximum exposure under guarantor obligations		979,000,000		979,000,000
Guarantees, carrying value		5,000,000		5,000,000
Corporate Joint Venture [Member] | Sempra LNG [Member] | Cameron LNG [Member]
Schedule of Equity Method Investments [Line Items]
Contribution			$ 54,000,000		54,000,000
Proceeds from dividends received				$ 496,000,000	209,000,000
Distributions from investments					803,000,000
Proceeds from related party debt	$ 1,500,000,000
Liability cap (as a percent)				130.00%
Liability cap, amount		$ 979,000,000		$ 979,000,000
Corporate Joint Venture [Member] | Sempra LNG [Member] | Cameron LNG [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Schedule of Equity Method Investments [Line Items]
Distributions from investments	753,000,000
Proceeds from related party debt	$ 753,000,000
Number of banks | bank						8
Oncor Holdings [Member] | Sempra Texas Utilities [Member]
Schedule of Equity Method Investments [Line Items]
Proceeds from dividends received				239,000,000	220,000,000
Distributions from investments				$ 361,000,000
ESJ [Member] | IEnova [Member] | Sempra Mexico [Member]
Schedule of Equity Method Investments [Line Items]
Acquired percentage interest								50.00%
Oncor Holdings [Member] | Sempra Texas Holdings Corp [Member] | Sempra Texas Intermediate Holding Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity				100.00%
Oncor Electric Delivery Company LLC. [Member] | Oncor Holdings [Member] | Sempra Texas Utilities [Member]
Schedule of Equity Method Investments [Line Items]
Acquired percentage interest		80.25%		80.25%
Cameron LNG [Member] | Sempra LNG [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity				50.20%
ESJ [Member] | Sempra Mexico [Member]
Schedule of Equity Method Investments [Line Items]
Proceeds from dividends received				$ 4,000,000	$ 8,000,000
ESJ [Member] | IEnova [Member] | Sempra Mexico [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage									50.00%	50.00%
ESJ [Member] | ESJ [Member] | IEnova [Member] | Sempra Mexico [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage										50.00%
Deferred Credits and Other [Member] | Sempra LNG [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value		$ 2,000,000		2,000,000
Other current assets [Member] | Sempra LNG [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value		7,000,000		7,000,000
Promissory Note for SDSRA Distribution [Member] | Corporate Joint Venture [Member] | Sempra LNG [Member] | Cameron LNG [Member]
Schedule of Equity Method Investments [Line Items]
Proceeds from dividends received				165,000,000
Promissory Note for SDSRA Distribution [Member] | Other Current Liabilities [Member] | Corporate Joint Venture [Member] | Sempra LNG [Member] | Cameron LNG [Member]
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value		22,000,000		22,000,000
Promissory Note for SDSRA Distribution [Member] | Deferred Credits and Other [Member] | Corporate Joint Venture [Member] | Sempra LNG [Member] | Cameron LNG [Member]
Schedule of Equity Method Investments [Line Items]
Senior note, liability		$ 22,000,000		$ 22,000,000

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INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARIZED FINANCIAL INFORMATION (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Schedule of Equity Method Investments [Line Items]
Operating revenues	$ 2,560	$ 2,301	$ 7,839	$ 7,199
Other (expense) income, net	(55)	29	52	(163)
Net income (loss)	(632)	421	751	3,673
Equity Method Investment, Nonconsolidated Investee or Group of Investees [Member] | Oncor Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Operating revenues	1,286	1,232	3,572	3,394
Operating expenses	(866)	(819)	(2,531)	(2,387)
Operating income	420	413	1,041	1,007
Interest expense	(104)	(102)	(308)	(305)
Income tax expense	(54)	(50)	(124)	(115)
Net income (loss)	255	255	587	557
Noncontrolling interest held by TTI	(51)	(50)	(118)	(111)
Earnings attributable to Sempra Energy	$ 204	$ 205	$ 469	$ 446

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DEBT AND CREDIT FACILITIES - LINES OF CREDIT (Details) - USD ($)	1 Months Ended			9 Months Ended
	Sep. 30, 2021	Jul. 31, 2021	May 31, 2021	Sep. 30, 2021	Nov. 01, 2021	Jun. 30, 2021
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 6,685,000,000			$ 6,685,000,000
Capacity for issuance of letters of credit	$ 200,000,000			$ 200,000,000
Maximum ratio of indebtedness to total capitalization	65.00%			65.00%
Standby letters of credit outstanding	$ 697,000,000			$ 697,000,000
Sempra U.S. Businesses [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	6,700,000,000			6,700,000,000
Available unused credit	4,573,000,000			4,573,000,000
Sempra Energy [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	4,435,000,000		$ 3,200,000,000	4,435,000,000
Term of debt instrument			5 years
Available unused credit	2,323,000,000			2,323,000,000
Option to request	500,000,000			500,000,000
Sempra Energy [Member] | Subsequent Event [Member]
Line of Credit Facility [Line Items]
Debt amount					$ 2,350,000,000
San Diego Gas and Electric Company [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,500,000,000			1,500,000,000
Available unused credit	1,500,000,000			1,500,000,000
Capacity for issuance of letters of credit	100,000,000			100,000,000
Option to request	$ 250,000,000			$ 250,000,000
Maximum ratio of indebtedness to total capitalization	65.00%			65.00%
San Diego Gas and Electric Company [Member] | Term Loan Due 2022 | Secured Debt
Line of Credit Facility [Line Items]
Debt amount						$ 375,000,000
Proceeds from debt issuance		$ 375,000,000
Spread on variable rate (as a percent)		0.625%
Southern California Gas Company [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 750,000,000			$ 750,000,000
Available unused credit	750,000,000			750,000,000
Capacity for issuance of letters of credit	100,000,000			100,000,000
Option to request	$ 250,000,000			$ 250,000,000
Maximum ratio of indebtedness to total capitalization	65.00%			65.00%
Commercial Paper
Line of Credit Facility [Line Items]
Amount outstanding	$ (2,112,000,000)			$ (2,112,000,000)
Commercial Paper | Sempra Energy [Member]
Line of Credit Facility [Line Items]
Amount outstanding	(2,112,000,000)			(2,112,000,000)
Commercial Paper | San Diego Gas and Electric Company [Member]
Line of Credit Facility [Line Items]
Amount outstanding	0			0
Commercial Paper | Southern California Gas Company [Member]
Line of Credit Facility [Line Items]
Amount outstanding	0			0
Foreign Line of Credit [Member] | Sempra Mexico [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,850,000,000			1,850,000,000
Amount outstanding	(294,000,000)			(294,000,000)
Available unused credit	1,556,000,000			1,556,000,000
Foreign Unsecured Line of Credit | Sempra Mexico [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	470,000,000			470,000,000
Amount outstanding	(287,000,000)			(287,000,000)
Available unused credit	183,000,000			183,000,000
Foreign Committed Lines of Credit, Due February 2024 [Member] | Foreign Line of Credit [Member] | Sempra Mexico [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,500,000,000			1,500,000,000
Amount outstanding	0			0
Available unused credit	1,500,000,000			1,500,000,000
Foreign Committed Lines of Credit, Due September 2023 [Member] | Foreign Line of Credit [Member] | Sempra Mexico [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	350,000,000			350,000,000
Amount outstanding	(294,000,000)			(294,000,000)
Available unused credit	56,000,000			56,000,000
Foreign Committed Lines of Credit, Due September 2023 [Member] | Foreign Line of Credit [Member] | IEnova [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 350,000,000			$ 350,000,000		$ 280,000,000
Spread on variable rate (as a percent)	0.54%
Foreign Uncommitted Revolving Credit Facility September 2022 | IEnova [Member] | LIBOR [Member]
Line of Credit Facility [Line Items]
Spread on variable rate (as a percent)				0.10%
Foreign Uncommitted Revolving Credit Facility September 2022 | Foreign Line of Credit [Member] | Sempra Mexico [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 250,000,000			$ 250,000,000
Amount outstanding	(250,000,000)			(250,000,000)
Available unused credit	0			0
Foreign Uncommitted Revolving Credit Facility Due August 2023 | Foreign Line of Credit [Member] | Sempra LNG [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	100,000,000			100,000,000
Amount outstanding	(37,000,000)			(37,000,000)
Available unused credit	63,000,000			$ 63,000,000
Foreign Uncommitted Revolving Credit Facility Due August 2023 | Foreign Unsecured Line of Credit | Sempra LNG [Member] | LIBOR [Member]
Line of Credit Facility [Line Items]
Spread on variable rate (as a percent)				1.05%
Foreign Uncommitted Revolving Credit Facility Due October 2023 | IEnova [Member] | LIBOR [Member]
Line of Credit Facility [Line Items]
Spread on variable rate (as a percent)				0.52%
Foreign Uncommitted Revolving Credit Facility Due October 2023 | Foreign Line of Credit [Member] | Sempra Mexico [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	100,000,000			$ 100,000,000
Amount outstanding	0			0
Available unused credit	100,000,000			100,000,000
Foreign Uncommitted Revolving Credit Facility Due October 2023-2 | Foreign Line of Credit [Member] | Sempra Mexico [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	20,000,000			20,000,000
Amount outstanding	0			0
Available unused credit	$ 20,000,000			$ 20,000,000

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DEBT AND CREDIT FACILITIES - WEIGHTED-AVERAGE INTEREST RATES AND INTEREST RATE SWAPS (Details)	Sep. 30, 2021	Dec. 31, 2020
Sempra Energy Consolidated [Member]
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	0.39%	0.83%
San Diego Gas and Electric Company [Member]
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	0.76%	0.00%
Southern California Gas Company [Member]
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	0.00%	0.14%

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DEBT AND CREDIT FACILITIES - LONG-TERM DEBT (Details)					1 Months Ended			9 Months Ended
	Nov. 01, 2021 USD ($)	Oct. 13, 2021 USD ($)	Oct. 08, 2021 USD ($)	Mar. 19, 2021 USD ($)	Aug. 31, 2021 USD ($)	May 31, 2021 USD ($)	Dec. 31, 2020 USD ($) bank	Sep. 30, 2021 USD ($)
Debt Instrument [Line Items]
Maximum borrowing capacity								$ 6,685,000,000
San Diego Gas and Electric Company [Member]
Debt Instrument [Line Items]
Maximum borrowing capacity								$ 1,500,000,000
San Diego Gas and Electric Company [Member] | Green First Mortgage Bonds Due 2051
Debt Instrument [Line Items]
Debt amount					$ 750,000,000
Proceeds from debt issuance					737,000,000
Unamortized debt issuance costs					$ 13,000,000
Stated rate of debt (as a percent)					2.95%
Sempra Mexico [Member] | Variable Rate Loan Payable Maturing 2033 | ESJ [Member]
Debt Instrument [Line Items]
Loans payable acquired in acquisition				$ 177,000,000
Unamortized debt issuance costs				$ 6,000,000
Percentage of loan bearing fixed rate				90.00%
Stated rate of debt (as a percent)				6.13%
Percentage of loan bearing variable rate				10.00%
Sempra Mexico [Member] | Variable Rate Loan Payable Maturing 2033 | ESJ [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Write off of unamortized debt issuance costs			$ 16,000,000
Write off of unamortized debt issuance costs, after tax and NCI			10,000,000
Repayments of Debt			$ 175,000,000
Sempra Mexico [Member] | Variable Rate Loan Payable Maturing 2033 | ESJ [Member] | LIBOR [Member]
Debt Instrument [Line Items]
Spread on variable rate (as a percent)				2.63%				2.80%
Basis spread, increase every four years (as a percent)				0.25%
Sempra Mexico [Member] | Variable Rate Loan Payable Maturing 2033 | Ventika [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Write off of unamortized debt issuance costs		$ 34,000,000
Write off of unamortized debt issuance costs, after tax and NCI		20,000,000
Repayments of Debt		$ 375,000,000
Sempra LNG [Member] | Loan Agreement To Finance Natural Gas Liquefaction Export Facility
Debt Instrument [Line Items]
Stated rate of debt (as a percent)							2.82%	2.84%
Term of debt instrument							5 years
Maximum borrowing capacity							$ 1,600,000,000
Long-term Debt							$ 17,000,000	$ 291,000,000
Number of banks | bank							9
Sempra Energy [Member]
Debt Instrument [Line Items]
Term of debt instrument						5 years
Maximum borrowing capacity						$ 3,200,000,000		$ 4,435,000,000
Sempra Energy [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Debt amount	$ 2,350,000,000
Write off of unamortized debt issuance costs	128,000,000
Write off of unamortized debt issuance costs, after tax and NCI	$ 93,000,000

XML

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE COMMODITY VOLUMES (Details)	9 Months Ended	12 Months Ended
	Sep. 30, 2021 MWh MMBTU	Dec. 31, 2020 MMBTU MWh
Natural Gas Derivative [Member] | Short
Derivative [Line Items]
Derivative, nonmonetary notional amount | MMBTU	(14)
Natural Gas Derivative [Member] | Long
Derivative [Line Items]
Derivative, nonmonetary notional amount | MMBTU		(5)
Electric Energy Derivative [Member] | Long
Derivative [Line Items]
Derivative, nonmonetary notional amount | MWh	(1)	(1)
Congestion Revenue Rights Derivative [Member] | Long
Derivative [Line Items]
Derivative, nonmonetary notional amount | MWh	(48)	(43)
SDG&E [Member] | Natural Gas Derivative [Member] | Long
Derivative [Line Items]
Derivative, nonmonetary notional amount | MMBTU	(10)	(16)
SDG&E [Member] | Electric Energy Derivative [Member] | Long
Derivative [Line Items]
Derivative, nonmonetary notional amount | MWh	(1)	(1)
SDG&E [Member] | Congestion Revenue Rights Derivative [Member] | Long
Derivative [Line Items]
Derivative, nonmonetary notional amount | MWh	(48)	(43)
SoCalGas [Member] | Natural Gas Derivative [Member] | Long
Derivative [Line Items]
Derivative, nonmonetary notional amount | MMBTU	0	(1)

XML

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE NOTIONALS (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Interest rate and foreign exchange instruments [Member]
Derivative [Line Items]
Notional amount of derivative	$ 306	$ 306
Foreign Exchange [Member]
Derivative [Line Items]
Notional amount of derivative	130	1,764
Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Notional amount of derivative	$ 747	$ 1,486

XML

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS ON THE CONDENSED BALANCE SHEET (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Other current assets [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	$ 73	$ 57
Additional cash collateral for commodity contracts not subject to rate recovery	47	21
Additional cash collateral for commodity contracts subject to rate recovery	30	30
Total	150	108
Other long-term assets [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	86	100
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	86	100
Other Current Liabilities [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(154)	(72)
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	(154)	(72)
Deferred credits and other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(143)	(188)
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	(143)	(188)
Designated as Hedging Instrument [Member] | Other current assets [Member]
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	0	0
Designated as Hedging Instrument [Member] | Other long-term assets [Member]
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	6	1
Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	(42)	(26)
Designated as Hedging Instrument [Member] | Deferred credits and other [Member]
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	(134)	(160)
Not Designated as Hedging Instrument [Member] | Other current assets [Member]
Derivatives not designated as hedging instruments:
Foreign exchange instruments		24
Commodity contracts not subject to rate recovery	252	82
Associated offsetting commodity contracts	(225)	(82)
Associated offsetting cash collateral	0
Commodity contracts subject to rate recovery	50	35
Associated offsetting commodity contracts	(4)	(2)
Not Designated as Hedging Instrument [Member] | Other long-term assets [Member]
Derivatives not designated as hedging instruments:
Foreign exchange instruments		0
Commodity contracts not subject to rate recovery	19	17
Associated offsetting commodity contracts	(15)	(13)
Associated offsetting cash collateral	0
Commodity contracts subject to rate recovery	76	95
Associated offsetting commodity contracts	0	0
Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives not designated as hedging instruments:
Foreign exchange instruments		0
Commodity contracts not subject to rate recovery	(300)	(95)
Associated offsetting commodity contracts	225	82
Associated offsetting cash collateral	11
Commodity contracts subject to rate recovery	(52)	(35)
Associated offsetting commodity contracts	4	2
Not Designated as Hedging Instrument [Member] | Deferred credits and other [Member]
Derivatives not designated as hedging instruments:
Foreign exchange instruments		0
Commodity contracts not subject to rate recovery	(21)	(16)
Associated offsetting commodity contracts	15	13
Associated offsetting cash collateral	0
Commodity contracts subject to rate recovery	(3)	(25)
Associated offsetting commodity contracts	0	0
San Diego Gas and Electric Company [Member] | Other current assets [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	44	31
Additional cash collateral for commodity contracts subject to rate recovery	28	24
Total	72	55
San Diego Gas and Electric Company [Member] | Other long-term assets [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	76	95
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	76	95
San Diego Gas and Electric Company [Member] | Other Current Liabilities [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(15)	(27)
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(15)	(27)
San Diego Gas and Electric Company [Member] | Deferred credits and other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(2)	(25)
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(2)	(25)
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Other current assets [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	47	32
Associated offsetting commodity contracts	(3)	(1)
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Other long-term assets [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	76	95
Associated offsetting commodity contracts	0	0
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(18)	(28)
Associated offsetting commodity contracts	3	1
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Deferred credits and other [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(2)	(25)
Associated offsetting commodity contracts	0	0
Southern California Gas Company [Member] | Other current assets [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	2	2
Additional cash collateral for commodity contracts subject to rate recovery	2	6
Total	4	8
Southern California Gas Company [Member] | Other long-term assets [Member]
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 [Member] | Other Current Liabilities [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(33)	(6)
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(33)	(6)
Southern California Gas Company [Member] | Deferred credits and other [Member]
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 [Member] | Not Designated as Hedging Instrument [Member] | Other current assets [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	3	3
Associated offsetting commodity contracts	(1)	(1)
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Other long-term assets [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	0	0
Associated offsetting commodity contracts	0	0
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(34)	(7)
Associated offsetting commodity contracts	1	1
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Deferred credits and other [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(1)	0
Associated offsetting commodity contracts	$ 0	$ 0

XML

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE IMPACT ON INCOME (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Derivative [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings	$ 29	$ 25	$ 118	$ (135)
Pretax (loss) gain on derivatives recognized in earnings	(3)	19	(26)	(129)
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member]
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	15	36	91	(225)
Pretax gain (loss) reclassified from AOCI into earnings	(23)	(4)	(63)	(43)
Designated as Hedging Instrument [Member] | Interest Expense [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	7	8	27	(42)
Pretax gain (loss) reclassified from AOCI into earnings	1	(3)	0	(6)
Designated as Hedging Instrument [Member] | Interest Expense [Member] | Cash Flow Hedging [Member] | Interest rate and foreign exchange instruments [Member]
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	(3)	6	(2)	(31)
Pretax gain (loss) reclassified from AOCI into earnings			0	(1)
Designated as Hedging Instrument [Member] | Equity Earnings [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	3	25	54	(175)
Pretax gain (loss) reclassified from AOCI into earnings	(19)	(5)	(57)	(8)
Designated as Hedging Instrument [Member] | Equity Earnings [Member] | Cash Flow Hedging [Member] | Foreign Exchange Instruments [Member]
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	3	(1)	5	9
Pretax gain (loss) reclassified from AOCI into earnings	0	0	(1)	2
Designated as Hedging Instrument [Member] | Revenues: Energy-Related Businesses [Member] | Cash Flow Hedging [Member] | Foreign Exchange Instruments [Member]
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	5	(2)	7	14
Pretax gain (loss) reclassified from AOCI into earnings	0	0	(1)	2
Designated as Hedging Instrument [Member] | Other Income (Expense), Net [Member] | Cash Flow Hedging [Member] | Foreign Exchange Instruments [Member]
Derivative [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings			0	1
Designated as Hedging Instrument [Member] | Other Income (Expense), Net [Member] | Cash Flow Hedging [Member] | Interest rate and foreign exchange instruments [Member]
Derivative [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings	(5)	4	(4)	(33)
Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	(170)	17	(339)	(37)
Not Designated as Hedging Instrument [Member] | Revenues: Energy-Related Businesses [Member] | Commodity Contracts not subject to rate recovery [Member]
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	(154)	(39)	(344)	25
Not Designated as Hedging Instrument [Member] | Other Income (Expense), Net [Member] | Foreign Exchange Instruments [Member]
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	2	15	(22)	(97)
Not Designated as Hedging Instrument [Member] | Cost of Electric Fuel and Purchased Power [Member] | Commodity Contracts Subject To Rate Recovery [Member]
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	8	41	51	41
Not Designated as Hedging Instrument [Member] | Cost of Natural Gas [Member] | Commodity Contracts Subject To Rate Recovery [Member]
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	(26)	0	(24)	(6)
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Cost of Electric Fuel and Purchased Power [Member] | Commodity Contracts Subject To Rate Recovery [Member]
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	8	41	51	41
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Cost of Natural Gas [Member] | Commodity Contracts Subject To Rate Recovery [Member]
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	$ (26)	$ 0	$ (24)	$ (6)

XML

DERIVATIVE FINANCIAL INSTRUMENTS - CASH FLOW HEDGES NARRATIVE (Details) $ in Millions	9 Months Ended
	Sep. 30, 2021 USD ($)
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified	$ (104)
Term of interest rate cash flow hedge	13 years
Southern California Gas Company [Member]
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified	$ (1)
Equity Method Investee [Member]
Derivative [Line Items]
Term of interest rate cash flow hedge	18 years

XML

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS WITH CONTINGENT FEATURES (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Derivative [Line Items]
Derivative fair value	$ 63	$ 16
Collateral	63
Southern California Gas Company [Member]
Derivative [Line Items]
Derivative fair value	34	$ 6
Collateral	$ 34

XML

FAIR VALUE MEASUREMENTS - RECURRING FAIR VALUE MEASURES (Details) - Recurring [Member] - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	$ 356	$ 364
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	52	65
Nuclear decommissioning trusts - Municipal bonds	320	326
Nuclear decommissioning trusts - Other securities	270	270
Nuclear decommissioning trusts - Total debt securities	642	661
Total nuclear decommissioning trusts	998	1,025
Support Agreement, net of related guarantee fees	7	7
Total Assets Measured at Fair Value	1,241	1,240
Support Agreement, net of related guarantee fees	2	4
Total Liabilities Measured at Fair Value	299	264
Interest rate and foreign exchange instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	6	25
Derivative liabilities	176	186
Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	31	4
Effect of netting and allocation of collateral	47	21
Derivative liabilities	81	16
Effect of netting and allocation of collateral	(11)
Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	122	128
Effect of netting and allocation of collateral	30	30
Derivative liabilities	51	58
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	350	358
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	40	41
Nuclear decommissioning trusts - Municipal bonds	0	0
Nuclear decommissioning trusts - Other securities	0	0
Nuclear decommissioning trusts - Total debt securities	40	41
Total nuclear decommissioning trusts	390	399
Support Agreement, net of related guarantee fees	0	0
Total Assets Measured at Fair Value	493	445
Support Agreement, net of related guarantee fees	0	0
Total Liabilities Measured at Fair Value	0	0
Level 1 [Member] | Interest rate and foreign exchange instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	0	0
Level 1 [Member] | Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Effect of netting and allocation of collateral	47	21
Derivative liabilities	0	0
Effect of netting and allocation of collateral	0
Level 1 [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	32	6
Effect of netting and allocation of collateral	24	19
Derivative liabilities	0	0
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	6	6
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	12	24
Nuclear decommissioning trusts - Municipal bonds	320	326
Nuclear decommissioning trusts - Other securities	270	270
Nuclear decommissioning trusts - Total debt securities	602	620
Total nuclear decommissioning trusts	608	626
Support Agreement, net of related guarantee fees	0	0
Total Assets Measured at Fair Value	647	661
Support Agreement, net of related guarantee fees	0	0
Total Liabilities Measured at Fair Value	281	208
Level 2 [Member] | Interest rate and foreign exchange instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	6	25
Derivative liabilities	176	186
Level 2 [Member] | Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	31	4
Effect of netting and allocation of collateral	0	0
Derivative liabilities	81	16
Effect of netting and allocation of collateral	(11)
Level 2 [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	2	1
Effect of netting and allocation of collateral	0	5
Derivative liabilities	35	6
Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	0	0
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	0	0
Nuclear decommissioning trusts - Municipal bonds	0	0
Nuclear decommissioning trusts - Other securities	0	0
Nuclear decommissioning trusts - Total debt securities	0	0
Total nuclear decommissioning trusts	0	0
Support Agreement, net of related guarantee fees	7	7
Total Assets Measured at Fair Value	101	134
Support Agreement, net of related guarantee fees	2	4
Total Liabilities Measured at Fair Value	18	56
Level 3 [Member] | Interest rate and foreign exchange instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	0	0
Level 3 [Member] | Commodity contracts not subject to rate recovery [Member]
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
Effect of netting and allocation of collateral	0
Level 3 [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	88	121
Effect of netting and allocation of collateral	6	6
Derivative liabilities	16	52
San Diego Gas and Electric Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	356	364
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	52	65
Nuclear decommissioning trusts - Municipal bonds	320	326
Nuclear decommissioning trusts - Other securities	270	270
Nuclear decommissioning trusts - Total debt securities	642	661
Total nuclear decommissioning trusts	998	1,025
Total Assets Measured at Fair Value	1,146	1,175
Total Liabilities Measured at Fair Value	17	52
San Diego Gas and Electric Company [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	120	126
Effect of netting and allocation of collateral	28	24
Derivative liabilities	17	52
San Diego Gas and Electric Company [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	350	358
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	40	41
Nuclear decommissioning trusts - Municipal bonds	0	0
Nuclear decommissioning trusts - Other securities	0	0
Nuclear decommissioning trusts - Total debt securities	40	41
Total nuclear decommissioning trusts	390	399
Total Assets Measured at Fair Value	444	422
Total Liabilities Measured at Fair Value	0	0
San Diego Gas and Electric Company [Member] | Level 1 [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	32	5
Effect of netting and allocation of collateral	22	18
Derivative liabilities	0	0
San Diego Gas and Electric Company [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	6	6
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	12	24
Nuclear decommissioning trusts - Municipal bonds	320	326
Nuclear decommissioning trusts - Other securities	270	270
Nuclear decommissioning trusts - Total debt securities	602	620
Total nuclear decommissioning trusts	608	626
Total Assets Measured at Fair Value	608	626
Total Liabilities Measured at Fair Value	1	0
San Diego Gas and Electric Company [Member] | Level 2 [Member] | Commodity contracts subject to rate recovery [Member]
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	1	0
San Diego Gas and Electric Company [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	0	0
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	0	0
Nuclear decommissioning trusts - Municipal bonds	0	0
Nuclear decommissioning trusts - Other securities	0	0
Nuclear decommissioning trusts - Total debt securities	0	0
Total nuclear decommissioning trusts	0	0
Total Assets Measured at Fair Value	94	127
Total Liabilities Measured at Fair Value	16	52
San Diego Gas and Electric Company [Member] | Level 3 [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	88	121
Effect of netting and allocation of collateral	6	6
Derivative liabilities	16	52
Southern California Gas Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total Assets Measured at Fair Value	4	8
Total Liabilities Measured at Fair Value	34	6
Southern California Gas Company [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	2	2
Effect of netting and allocation of collateral	2	6
Derivative liabilities	34	6
Southern California Gas Company [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total Assets Measured at Fair Value	2	2
Total Liabilities Measured at Fair Value	0	0
Southern California Gas Company [Member] | Level 1 [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	1
Effect of netting and allocation of collateral	2	1
Derivative liabilities	0	0
Southern California Gas Company [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total Assets Measured at Fair Value	2	6
Total Liabilities Measured at Fair Value	34	6
Southern California Gas Company [Member] | Level 2 [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	2	1
Effect of netting and allocation of collateral	0	5
Derivative liabilities	34	6
Southern California Gas Company [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total Assets Measured at Fair Value	0	0
Total Liabilities Measured at Fair Value	0	0
Southern California Gas Company [Member] | Level 3 [Member] | Commodity contracts subject to rate recovery [Member]
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		9 Months Ended
	Sep. 30, 2021 USD ($) $ / MWh	Sep. 30, 2020 USD ($) $ / MWh	Sep. 30, 2021 USD ($) $ / MWh	Sep. 30, 2020 USD ($) $ / MWh
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	$ 80	$ 17	$ 69	$ 28
Realized and unrealized losses	(35)	(4)	(29)	(18)
Allocated transmission instruments	1	1	(1)	2
Settlements	26	19	33	21
Ending balance	72	33	72	33
Fair Value, Net Derivative Asset (Liability), Recurring Basis, Still Held, Unrealized Gain (Loss)	9	7	5	(1)
Sempra LNG [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	4	0	3	0
Realized and unrealized gains	3	7	8	7
Settlements	(2)	(1)	(6)	(1)
Ending balance	5	6	5	6
Change in unrealized gains (losses) relating to instruments still held at the end of the period	3	6	7	6
Sempra LNG [Member] | Other current assets [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	7		7
Sempra LNG [Member] | Deferred Credits and Other [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability Value	2		2
San Diego Gas and Electric Company [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	80	17	69	28
Realized and unrealized losses	(35)	(4)	(29)	(18)
Allocated transmission instruments	1	1	(1)	2
Settlements	26	19	33	21
Ending balance	72	33	72	33
Fair Value, Net Derivative Asset (Liability), Recurring Basis, Still Held, Unrealized Gain (Loss)	$ 9	$ 7	$ 5	$ (1)
Level 3 [Member] | San Diego Gas and Electric Company [Member] | Minimum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) | $ / MWh			(1.81)	(3.77)
Market electricity forward price inputs ( in dollars per MWH) | $ / MWh	24.05	19.45	24.05	19.45
Level 3 [Member] | San Diego Gas and Electric Company [Member] | Maximum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) | $ / MWh			14.11	6.03
Market electricity forward price inputs ( in dollars per MWH) | $ / MWh	130.40	71.25	130.40	71.25
Level 3 [Member] | San Diego Gas and Electric Company [Member] | Weighted Average [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) | $ / MWh			(0.12)	(1.58)
Market electricity forward price inputs ( in dollars per MWH) | $ / MWh	57.36	38.14	57.36	38.14

XML

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates, allowance for credit losses	$ 1	$ 3
Unamortized discount and debt issuance costs	266	268
Finance lease obligations	1,336	1,330
Due from Unconsolidated Affiliates - Current
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates, allowance for credit losses	2	3
Carrying amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates	687	786
Long-term amounts due to unconsolidated affiliate	328	275
Total long-term debt	21,966	22,259
Fair value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates	697	817
Long-term amounts due to unconsolidated affiliate	347	266
Total long-term debt	24,288	25,478
Fair value [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates	0	0
Long-term amounts due to unconsolidated affiliate	0	0
Total long-term debt	0	0
Fair value [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates	697	817
Long-term amounts due to unconsolidated affiliate	347	266
Total long-term debt	24,288	25,478
Fair value [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates	0	0
Long-term amounts due to unconsolidated affiliate	0	0
Total long-term debt	0	0
San Diego Gas and Electric Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount and debt issuance costs	62	52
Finance lease obligations	1,279	1,276
San Diego Gas and Electric Company [Member] | Carrying amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	6,418	6,253
San Diego Gas and Electric Company [Member] | Fair value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,263	7,384
San Diego Gas and Electric Company [Member] | Fair value [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
San Diego Gas and Electric Company [Member] | Fair value [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,263	7,384
San Diego Gas and Electric Company [Member] | Fair value [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
Southern California Gas Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount and debt issuance costs	37	40
Finance lease obligations	57	54
Southern California Gas Company [Member] | Carrying amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	4,759	4,759
Southern California Gas Company [Member] | Fair value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	5,373	5,655
Southern California Gas Company [Member] | Fair value [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
Southern California Gas Company [Member] | Fair value [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	5,373	5,655
Southern California Gas Company [Member] | Fair value [Member] | Level 3 [Member]
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 [Member] - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Dec. 31, 2020
Jointly Owned Utility Plant Interests [Line Items]
Anticipated term of dismantlement work	10 years
Percent of dismantlement work expense (as a percent)	20.00%
ARO related to decommissioning costs	$ 551
Cost study estimate decommissioning escalated	$ 886
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%
SONGS 2 and 3 Decommissioning [Member]
Jointly Owned Utility Plant Interests [Line Items]
Nuclear decommissioning trust authorized withdrawal amount		$ 89

XML

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR DECOMMISSIONING TRUSTS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Debt Securities, Available-for-sale [Line Items]
Cost	$ 728		$ 728		$ 731
Gross unrealized gains	279		279		290
Gross unrealized losses	(4)		(4)		(2)
Estimated fair value	1,003		1,003		1,019
Proceeds from sales	187	$ 294	729	$ 1,091
Gross realized gains	9	9	48	108
Gross realized losses	(1)	$ (2)	(4)	$ (13)
Total debt securities [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	620		620		625
Gross unrealized gains	24		24		36
Gross unrealized losses	(2)		(2)		0
Estimated fair value	642		642		661
U.S. government corporations and agencies [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	52		52		64
Gross unrealized gains	0		0		1
Gross unrealized losses	0		0		0
Estimated fair value	52		52		65
Municipal bonds [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	307		307		308
Gross unrealized gains	14		14		18
Gross unrealized losses	(1)		(1)		0
Estimated fair value	320		320		326
Other securities [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	261		261		253
Gross unrealized gains	10		10		17
Gross unrealized losses	(1)		(1)		0
Estimated fair value	270		270		270
Equity securities [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	103		103		112
Gross unrealized gains	255		255		254
Gross unrealized losses	(2)		(2)		(2)
Estimated fair value	356		356		364
Cash and cash equivalents [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	7		7		3
Gross unrealized gains	0		0		0
Gross unrealized losses	0		0		0
Estimated fair value	7		7		3
Receivables (payables), net [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	(2)		(2)		(9)
Gross unrealized gains	0		0		0
Gross unrealized losses	0		0		0
Estimated fair value	$ (2)		$ (2)		$ (9)

XML

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR INSURANCE (Details) - San Diego Gas and Electric Company [Member] $ in Millions	Sep. 30, 2021 USD ($)
Schedule Of Nuclear Insurance [Line Items]
Maximum nuclear liability insurance coverage	$ 450.0
Maximum secondary financial protection	110.0
Maximum nuclear liability loss coverage per incident	560.0
Nuclear property damage insurance	130.0
Federal nuclear property damage insurance, minimum required	50.0
Maximum premium assessment under nuclear property damage insurance	4.3
Maximum nuclear property insurance terrorism coverage	$ 3,240.0

XML

COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details)			1 Months Ended			4 Months Ended	9 Months Ended
	Nov. 02, 2021 USD ($)	Nov. 01, 2021 lawsuit plaintiff	Sep. 30, 2021 USD ($) lawsuit	Nov. 30, 2019 violation	Jan. 31, 2017 lawsuit	Jan. 31, 2019 plaintiff	Sep. 30, 2021 USD ($) lawsuit	Sep. 30, 2020 USD ($)	Sep. 27, 2021 USD ($)	Sep. 26, 2021 USD ($)	Mar. 31, 2020 USD ($)
Loss Contingencies [Line Items]
Liability for legal proceedings			$ 2,076,000,000				$ 2,076,000,000
Number of alleged violations | violation				324
Guaymas-El Oro Segment, Sonora Pipeline [Member]
Loss Contingencies [Line Items]
Net book value of pipeline			436,000,000				436,000,000
Consolidated Class Action Complaints [Member]
Loss Contingencies [Line Items]
Number of lawsuits filed | lawsuit					2
Property Class Action [Member]
Loss Contingencies [Line Items]
Number of lawsuits filed | lawsuit					1
Southern California Gas Company [Member]
Loss Contingencies [Line Items]
Liability for legal proceedings			1,998,000,000				1,998,000,000
Insurance settlements receivable			1,279,000,000				1,279,000,000
Equity contribution from Sempra Energy			800,000,000				800,000,000	$ 0
Southern California Gas Company [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Liability for legal proceedings			1,973,000,000				1,973,000,000
Estimate of costs			3,199,000,000				3,199,000,000
Net book value of Aliso Canyon facility			863,000,000				863,000,000
Reserve for Aliso Canyon costs			1,976,000,000				1,976,000,000
Loss contingency accrual											$ 277,000,000
Receivable related to natural gas leak			$ 414,000,000				414,000,000
Insurance proceeds							$ 865,000,000
Southern California Gas Company [Member] | Shareholder Derivative Complaint [Member]
Loss Contingencies [Line Items]
Number of lawsuits | lawsuit			4				4
Southern California Gas Company [Member] | Complaints Filed by Firefighters [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Number of plaintiffs | plaintiff						51
Southern California Gas Company [Member] | Individual Plaintiff Litigation | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Percentage of plaintiffs represented										80.00%
Estimate of costs										$ 1,800,000,000
Acceptance rate of plaintiffs (as a percent)										97.00%
Southern California Gas Company [Member] | Property Class Action [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Estimate of costs										$ 40,000,000
Southern California Gas Company [Member] | Business Class Action | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Estimate of costs									$ 100,000
Sempra Mexico [Member] | Regulatory Actions by the Mexican Government
Loss Contingencies [Line Items]
Other intangible assets, net			$ 14,000,000				$ 14,000,000
Subsequent Event [Member] | Southern California Gas Company [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Number of lawsuits | lawsuit		416
Number of plaintiffs | plaintiff		36,000
Subsequent Event [Member] | Southern California Gas Company [Member] | Proposition 65 Claims
Loss Contingencies [Line Items]
Payments for losses	$ 2,000,000
Insurance Receivable [Member] | Southern California Gas Company [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Loss contingency accrual											177,000,000
Aliso Canyon Litigation and Regulatory Matters | Southern California Gas Company [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Loss contingency accrual			1,570,000,000				1,570,000,000	27,000,000			100,000,000
Loss contingency accrual, after tax			$ 1,130,000,000				$ 1,130,000,000	$ 22,000,000			$ 72,000,000

XML

COMMITMENTS AND CONTINGENCIES - OTHER LITIGATION (Details) claim in Thousands, £ in Millions, $ in Millions	1 Months Ended		3 Months Ended		9 Months Ended
	Oct. 31, 2020 GBP (£)	Mar. 31, 2020 GBP (£)	Jun. 30, 2021 USD ($)	Mar. 31, 2020 USD ($)	Sep. 30, 2021 USD ($)	Nov. 01, 2021 claim lawsuit	Oct. 01, 2014 USD ($)	Oct. 01, 2014 GBP (£)
R B S Sempra Commodities [Member] | HMRC VAT Claim [Member]
Loss Contingencies [Line Items]
VAT tax claim paid upon appeal							$ 138	£ 86
Plaintiffs [Member] | HMRC VAT Claim [Member]
Loss Contingencies [Line Items]
Damages awarded		£ 45			$ 61
Cost and interest assessed	£ 21				$ 28
Energy Future Holdings Corp. [Member] | Subsequent Event [Member]
Loss Contingencies [Line Items]
Number of lawsuits | lawsuit						3
Number of proof of claims | claim						28
R B S Sempra Commodities [Member]
Loss Contingencies [Line Items]
Equity losses on investment | $			$ 50	$ 100

XML

COMMITMENTS AND CONTINGENCIES - LEASE INFORMATION (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		9 Months Ended
	Jul. 31, 2021	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Lessee, Lease, Description [Line Items]
Reduction in carrying value	$ 44
Net investment in sales-type lease	60
Selling profit	$ 16
Income recognized at lease commencement		$ 16	$ 0	$ 16	$ 1
Interest income		2	0	2	1
Total revenues from sales-type leases(1)		18	0	18	2
Fixed lease payments		80	48	192	145
Variable lease payments		2	1	3	1
Total revenues from operating leases(1)		82	49	195	146
Depreciation expense		$ 13	$ 10	35	$ 29
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Lease not yet commenced, 2021				1
Lease not yet commenced, 2022				10
Lease not yet commenced, 2023				10
Lease not yet commenced, 2024				10
Lease not yet commenced, 2025				10
Lease not yet commenced, thereafter				$ 103

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COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS (Details) - USD ($) $ in Millions		9 Months Ended
	Jun. 08, 2021	Sep. 30, 2021
Sempra LNG [Member] | Liquefied Natural Gas Contracts [Member]
Loss Contingencies [Line Items]
Change in 2021		$ (277)
Change in 2022		496
Change in 2023		279
Change in 2024		197
Change in 2025		153
Change thereafter		499
San Diego Gas and Electric Company [Member]
Loss Contingencies [Line Items]
Potential monetary sanctions threshold, actual amount		17
San Diego Gas and Electric Company [Member] | Natural Gas and Electric Franchise
Loss Contingencies [Line Items]
Principle payments	$ 110
Other Commitments, Interest Payments	$ 13
Other Commitments, Payments		11
Other Commitment, to be Paid, Year One		14
Other Commitment, to be Paid, Year Two		14
Other Commitment, to be Paid, Year Three		14
Other Commitment, to be Paid, Year Four		14
Other Commitment, to be Paid, Year Five		15
Other Commitment, to be Paid, after Year Five		55
Sempra Energy [Member]
Loss Contingencies [Line Items]
Potential monetary sanctions threshold, actual amount		46
Southern California Gas Company [Member]
Loss Contingencies [Line Items]
Potential monetary sanctions threshold, actual amount		$ 15

XML

SEGMENT INFORMATION (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021 USD ($)	Sep. 30, 2020 USD ($)	Sep. 30, 2021 USD ($) segment	Sep. 30, 2020 USD ($)	Dec. 31, 2020 USD ($)
Segment Reporting Information [Line Items]
Number of reportable segments | segment			5
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 3,013	$ 2,644	$ 9,013	$ 8,199
INTEREST EXPENSE	259	264	776	818
INTEREST INCOME	16	27	50	76
DEPRECIATION AND AMORTIZATION	471	418	1,376	1,242
Income Tax Expense (Benefit)	(342)	99	(45)	60
Equity earnings (losses), before income tax:	137	117	457	158
Equity earnings, net of income tax:	254	209	565	664
Equity earnings	391	326	1,022	822
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	(648)	351	650	3,350
Discontinued operations	0	(7)	0	1,840
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			3,606	3,313
ASSETS	70,472		70,472		$ 66,623	[1]
EQUITY METHOD AND OTHER INVESTMENTS	13,958		13,958		13,828
Operating Segments [Member] | SDG&E [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	1,464	1,472	4,119	3,976
INTEREST EXPENSE	104	103	307	307
INTEREST INCOME	0	1	1	2
DEPRECIATION AND AMORTIZATION	226	200	659	598
Income Tax Expense (Benefit)	90	33	168	161
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	205	178	603	633
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			1,560	1,323
ASSETS	23,783		23,783		22,311
Operating Segments [Member] | SoCalGas [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	1,106	842	3,738	3,247
INTEREST EXPENSE	39	39	118	119
INTEREST INCOME	0	0	0	2
DEPRECIATION AND AMORTIZATION	180	165	533	486
Income Tax Expense (Benefit)	(437)	(6)	(335)	95
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	(1,126)	(24)	(625)	425
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			1,417	1,345
ASSETS	19,919		19,919		18,460
Operating Segments [Member] | Sempra Texas Utilities [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Equity earnings (losses), before income tax:	0	1	3	1
Equity earnings, net of income tax:	207	208	480	457
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	206	209	479	458
Segment Reporting Information, Additional Information [Abstract]
ASSETS	12,580		12,580		12,542
EQUITY METHOD AND OTHER INVESTMENTS	12,580		12,580		12,542
Operating Segments [Member] | Sempra Mexico [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	597	351	1,368	935
INTEREST EXPENSE	43	31	122	95
INTEREST INCOME	12	14	36	47
DEPRECIATION AND AMORTIZATION	60	47	168	141
Income Tax Expense (Benefit)	24	92	145	(161)
Equity earnings, net of income tax:	47	1	85	207
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	164	50	225	302
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			260	443
ASSETS	11,339		11,339		10,752
EQUITY METHOD AND OTHER INVESTMENTS	924		924		852
Operating Segments [Member] | Sempra LNG [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	119	63	367	255
INTEREST EXPENSE	4	8	10	39
INTEREST INCOME	6	25	23	65
DEPRECIATION AND AMORTIZATION	3	2	8	7
Income Tax Expense (Benefit)	(11)	18	19	59
Equity earnings (losses), before income tax:	137	116	404	257
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	1	71	194	207
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			362	196
ASSETS	3,335		3,335		2,205
EQUITY METHOD AND OTHER INVESTMENTS	454		454		433
Corporate, Non-Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	2	0	4	1
INTEREST EXPENSE	77	93	240	304
INTEREST INCOME	1	0	2	3
DEPRECIATION AND AMORTIZATION	2	4	8	10
Income Tax Expense (Benefit)	(8)	(38)	(42)	(94)
Equity earnings (losses), before income tax:	0	0	50	(100)
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	(98)	(126)	(226)	(515)
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			7	6
ASSETS	1,094		1,094		1,209
EQUITY METHOD AND OTHER INVESTMENTS	0		0		1
Segment Reconciling Items [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	0	2	(1)	0
Discontinued operations	0	(7)	0	1,840
Intersegment eliminations [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(275)	(86)	(582)	(215)
INTEREST EXPENSE	(8)	(10)	(21)	(46)
INTEREST INCOME	(3)	(13)	(12)	(43)
Segment Reporting Information, Additional Information [Abstract]
ASSETS	(1,578)		(1,578)		$ (856)
Intersegment eliminations [Member] | SDG&E [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	3	1	7	4
Intersegment eliminations [Member] | SoCalGas [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	24	23	72	61
Intersegment eliminations [Member] | Sempra Mexico [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	52	18	114	69
Intersegment eliminations [Member] | Sempra LNG [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 196	$ 44	$ 389	$ 81
Oncor Electric Delivery Company LLC Additional Acquisition [Member] | Sempra Texas Utilities [Member]
Segment Reporting Information [Line Items]
Acquired percentage interest	80.25%		80.25%
Sharyland Holdings, LP [Member] | Sempra Texas Utilities [Member]
Segment Reporting Information [Line Items]
Acquired percentage interest	50.00%		50.00%

[1] Derived from audited financial statements.

XML

Label	Element	Value
Accounting Standards Update [Extensible Enumeration]	us-gaap_AccountingStandardsUpdateExtensibleList	Accounting Standards Update 2016-13 [Member]