10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION Washington, D.C.  20549
FORM 10-Q
(Mark One)
[X]	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the quarterly period ended		March 31, 2019
	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 Registrants as Specified in their Charters, Address and Telephone Number	State of Incorporation		I.R.S. Employer Identification Nos.	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	NYSE
Sempra Energy 6% Mandatory Convertible Preferred Stock, Series A,	SRE.PRA	NYSE
$100 liquidation preference
Sempra Energy 6.75% Mandatory Convertible Preferred Stock, Series B,	SRE.PRB	NYSE
$100 liquidation preference

1

Indicate by check mark whether the registrants (1) have 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 registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.
	Yes	X	No

Indicate by check mark whether the registrants have 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 registrants were required to submit such files).
	Yes	X	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.

	Large accelerated filer	Accelerated filer	Non-accelerated filer	Smaller reporting company	Emerging growth company
Sempra Energy	[  X  ]	[      ]	[       ]	[      ]	[      ]
San Diego Gas & Electric Company	[       ]	[      ]	[  X  ]	[      ]	[      ]
Southern California Gas Company	[       ]	[      ]	[  X  ]	[      ]	[      ]

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	X
San Diego Gas & Electric Company	Yes	No	X
Southern California Gas Company	Yes	No	X
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 May 2, 2019:

Sempra Energy	274,388,245 shares
San Diego Gas & Electric Company	Wholly owned by Enova Corporation, which is wholly owned by Sempra Energy
Southern California Gas Company	Wholly owned by Pacific Enterprises, which is wholly owned by Sempra Energy

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SEMPRA ENERGY FORM 10-Q SAN DIEGO GAS & ELECTRIC COMPANY FORM 10-Q SOUTHERN CALIFORNIA GAS COMPANY FORM 10-Q TABLE OF CONTENTS
		Page
Glossary		4
Information Regarding Forward-Looking Statements		7
PART I – FINANCIAL INFORMATION
Item 1.	Financial Statements	9
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	82
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	108
Item 4.	Controls and Procedures	109
PART II – OTHER INFORMATION
Item 1.	Legal Proceedings	110
Item 1A.	Risk Factors	110
Item 6.	Exhibits	110
Signatures		113

This combined Form 10-Q is separately filed by Sempra Energy, San Diego Gas & Electric Company and Southern California Gas Company. Information contained herein relating to any individual company is filed by such company on its own behalf. Each company makes representations only as to itself and makes no other representation whatsoever as to any other company.

You should read this report in its entirety as it pertains to each respective reporting company. 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 company, except for the Notes to Condensed Consolidated Financial Statements. The Notes to Condensed Consolidated Financial Statements for all of the reporting companies are combined. All Items other than Part I – Item 1 are combined for the reporting companies.

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

GLOSSARY
2016 GRC FD	final decision in the California Utilities’ 2016 General Rate Case
AB	Assembly Bill
AFUDC	allowance for funds used during construction
Annual Report	Annual Report on Form 10-K for the year ended December 31, 2018
AOCI	accumulated other comprehensive income (loss)
ARO	asset retirement obligation
ASC	Accounting Standards Codification
Asset Exchange Agreement	agreement and plan of merger among Oncor, SDTS and SU
ASU	Accounting Standards Update
Bay Gas	Bay Gas Storage Company, Ltd.
Bcf	billion cubic feet
bps	basis points
Cal PA	California Public Advocates Office
California Utilities	San Diego Gas & Electric Company and Southern California Gas Company, collectively
Cameron LNG JV	Cameron LNG Holdings, LLC
CARB	California Air Resources Board
CEC	California Energy Commission
CEQA	California Environmental Quality Act
CFE	Comisión Federal de Electricidad (Federal Electricity Commission in Mexico)
Chilquinta Energía	Chilquinta Energía S.A. and its subsidiaries
CPUC	California Public Utilities Commission
CRR	congestion revenue right
DOE	U.S. Department of Energy
DOGGR	California Department of Conservation’s Division of Oil, Gas, and Geothermal Resources
DPH	Los Angeles County Department of Public Health
ECA	Energía Costa Azul
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.)
EFIH	Energy Future Intermediate Holding Company LLC (renamed Sempra Texas Intermediate Holding Company LLC)
EPA	U.S. Environmental Protection Agency
EPC	engineering, procurement and construction
EPS	earnings per common share
ETR	effective income tax rate
EV	electric vehicle
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
FTA	Free Trade Agreement
GCIM	Gas Cost Incentive Mechanism
GHG	greenhouse gas
GRC	General Rate Case
HLBV	hypothetical liquidation at book value
HMRC	United Kingdom’s Revenue and Customs Department
IEnova	Infraestructura Energética Nova, S.A.B. de C.V.
IMG	Infraestructura Marina del Golfo
InfraREIT	InfraREIT, Inc.
InfraREIT Merger Agreement	agreement and plan of merger among Oncor, 1912 Merger Sub LLC (a wholly owned subsidiary of Oncor), Oncor T&D Partners, LP (a wholly owned indirect subsidiary of Oncor), InfraREIT and InfraREIT Partners
InfraREIT Partners	InfraREIT Partners, LP
IRS	Internal Revenue Service
ISFSI	independent spent fuel storage installation
ISO	Independent System Operator
JP Morgan	J.P. Morgan Chase & Co.
JV	joint venture
LA Superior Court	Los Angeles County Superior Court
Leak	the leak at the SoCalGas Aliso Canyon natural gas storage facility injection-and-withdrawal well, SS25, discovered by SoCalGas on October 23, 2015
LNG	liquefied natural gas

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GLOSSARY (CONTINUED)
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
Merger	The merger of EFH with an indirect subsidiary of Sempra Energy, with EFH continuing as the surviving company and as an indirect, wholly owned subsidiary of Sempra Energy
Merger Agreement	Agreement and Plan of Merger dated August 21, 2017, as supplemented by a Waiver Agreement dated October 3, 2017 and an amendment dated February 15, 2018, between Sempra Energy, EFH, EFIH and an indirect subsidiary of Sempra Energy
Merger Consideration	Pursuant to the Merger Agreement, Sempra Energy paid consideration of $9.45 billion in cash
Mississippi Hub	Mississippi Hub, LLC
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
NOL	net operating loss
OCI	other comprehensive income (loss)
OII	Order Instituting Investigation
OIR	Order Instituting a Rulemaking
O&M	operation and maintenance expense
OMEC	Otay Mesa Energy Center
OMEC LLC	Otay Mesa Energy Center LLC
OMI	Oncor Management Investment LLC
Oncor	Oncor Electric Delivery Company LLC
Oncor Holdings	Oncor Electric Delivery Holdings Company LLC
Otay Mesa VIE	OMEC LLC VIE
PHMSA	Pipeline and Hazardous Materials Safety Administration
PPA	power purchase agreement
PP&E	property, plant and equipment
PSEP	Pipeline Safety Enhancement Plan
PUCT	Public Utility Commission of Texas
RBS	The Royal Bank of Scotland plc
RBS SEE	RBS Sempra Energy Europe
RBS Sempra Commodities	RBS Sempra Commodities LLP
ROE	return on equity
ROU	right-of-use
RSU	restricted stock unit
SB	California Senate Bill
SCAQMD	South Coast Air Quality Management District
SDCA	U.S. District Court for the Southern District of California
SDG&E	San Diego Gas & Electric Company
SDTS	Sharyland Distribution & Transmission Services, L.L.C. (a subsidiary of InfraREIT)
SEC	U.S. Securities and Exchange Commission
Securities Purchase Agreement	securities purchase agreement among SU, SU Investment Partners, L.P., Sempra Texas Utilities Holdings I, LLC (a wholly owned subsidiary of Sempra Energy) and Sempra Energy
SEDATU	Secretaría de Desarrollo Agrario, Territorial y Urbano (Mexican agency in charge of agriculture, land and urban development)
Sempra Global	holding company for most of Sempra Energy’s subsidiaries not subject to California or Texas utility regulation
series A preferred stock	6% mandatory convertible preferred stock, series A
series B preferred stock	6.75% mandatory convertible preferred stock, series B
SoCalGas	Southern California Gas Company
SONGS	San Onofre Nuclear Generating Station
S&P	Standard & Poor’s
SU	Sharyland Utilities, LP
TAG	TAG Pipelines Norte, S. de R.L. de C.V.

5

GLOSSARY (CONTINUED)
TCJA	Tax Cuts and Jobs Act of 2017
TdM	Termoeléctrica de Mexicali
Tecnored	Tecnored S.A.
Tecsur	Tecsur S.A.
TTI	Texas Transmission Investment LLC
TURN	The Utility Reform Network
U.S. GAAP	accounting principles generally accepted in the United States of America
VAT	value-added tax
VIE	variable interest entity

6

INFORMATION REGARDING FORWARD-LOOKING STATEMENTS

We make statements in this report that are not historical fact and 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 of performance. Future results may differ materially from those expressed in the 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.

In this report, when we use words such as “believes,” “expects,” “anticipates,” “plans,” “estimates,” “projects,” “forecasts,” “contemplates,” “assumes,” “depends,” “should,” “could,” “would,” “will,” “confident,” “may,” “can,” “potential,” “possible,” “proposed,” “target,” “pursue,” “outlook,” “maintain,” or similar expressions, or when we discuss our guidance, strategy, plans, goals, vision, mission, opportunities, projections, initiatives, objectives or intentions, we are making forward-looking statements.

Factors, among others, that could cause our actual results and future actions to differ materially from those described in any forward-looking statements include risks and uncertainties relating to:

▪ the greater degree and prevalence of wildfires in California in recent years and the risk that we may be found liable for damages regardless of fault, such as where inverse condemnation applies, and risk that we may not be able to recover any such costs in rates from customers in California;

▪ actions and the timing of actions, including decisions, new regulations and issuances of authorizations by the CPUC, DOE, DOGGR, DPH, EPA, FERC, PHMSA, PUCT, states, cities and counties, and other regulatory and governmental bodies in the U.S. and other countries in which we operate;

▪ the success of business development efforts, construction projects, major acquisitions, divestitures and internal structural changes, including risks in (i) obtaining or maintaining authorizations; (ii) completing construction projects on schedule and budget; (iii) obtaining the consent of partners; (iv) counterparties’ ability to fulfill contractual commitments; (v) winning competitively bid infrastructure projects; (vi) disruption caused by the announcement of contemplated acquisitions and/or divestitures or internal structural changes; (vii) the ability to complete contemplated acquisitions and/or divestitures; and (viii) the ability to realize anticipated benefits from any of these efforts once completed;

▪ the resolution of civil and criminal litigation and regulatory investigations and proceedings;

▪ actions by credit rating agencies to downgrade our credit ratings or those of our subsidiaries or to place those ratings on negative outlook and our ability to borrow at favorable interest rates;

▪ deviations from regulatory precedent or practice that result in a reallocation of benefits or burdens among shareholders and ratepayers; denial of approvals of proposed settlements; delays in, or denial of, regulatory agency authorizations to recover costs in rates from customers or regulatory agency approval for projects required to enhance safety and reliability; and moves to reduce or eliminate reliance on natural gas;

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

▪ risks posed by actions of third parties who control the operations of our investments;

▪ weather conditions, natural disasters, accidents, equipment failures, computer system outages, explosions, terrorist attacks and other events that disrupt our operations, damage our facilities and systems, cause the release of harmful materials, cause fires and subject us to third-party liability for property damage or personal injuries, fines and penalties, some of which may not be covered by insurance (including costs in excess of applicable policy limits), 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;

▪ cybersecurity threats to the energy grid, storage and pipeline infrastructure, the information and systems used to operate our businesses and the confidentiality of our proprietary information and the personal information of our customers and employees;

▪ actions of activist shareholders, which could impact the market price of our securities and disrupt our operations as a result of, among other things, requiring significant time by management and our board of directors;

▪ changes in capital markets, energy markets and economic conditions, including the availability of credit; and volatility in currency exchange, interest and inflation rates and commodity prices and our ability to effectively hedge the risk of such volatility;

▪ the impact of federal or state tax reform and our ability to mitigate adverse impacts;

7

▪ changes in foreign and domestic trade policies and laws, including border tariffs and revisions to or replacement of international trade agreements, such as the North American Free Trade Agreement or the United States-Mexico-Canada Agreement (subject to congressional approval), that may increase our costs or impair our ability to resolve trade disputes;

▪ expropriation of assets by foreign governments and title and other property disputes;

▪ the impact at SDG&E on competitive customer rates and reliability of electric transmission and distribution systems due to the growth in distributed and local power generation and from possible departing retail load resulting from customers transferring to Direct Access and Community Choice Aggregation or other forms of distributed and local power generation and the potential risk of nonrecovery for stranded assets and contractual obligations;

▪ Oncor’s ability to eliminate or reduce its quarterly dividends due to regulatory capital requirements and other regulatory and governance commitments, including the determination by a majority of Oncor’s independent directors or a minority member director to retain such amounts to meet future requirements; and

▪ 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 business as described herein, in our most recent Annual Report and in other reports that 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 March 31,
	2019			2018
	(unaudited)
REVENUES
Utilities	$	2,515		$	2,190
Energy-related businesses	383			346
Total revenues	2,898			2,536
EXPENSES AND OTHER INCOME
Utilities:
Cost of natural gas	(531		)	(348		)
Cost of electric fuel and purchased power	(256		)	(271		)
Energy-related businesses cost of sales	(108		)	(69		)
Operation and maintenance	(832		)	(741		)
Depreciation and amortization	(383		)	(372		)
Franchise fees and other taxes	(130		)	(117		)
Other income, net	82			152
Interest income	21			29
Interest expense	(260		)	(206		)
Income from continuing operations before income taxes and equity earnings (losses) of unconsolidated entities	501			593
Income tax expense	(42		)	(242		)
Equity earnings (losses)	101			(21		)
Income from continuing operations, net of income tax	560			330
(Loss) income from discontinued operations, net of income tax	(42		)	28
Net income	518			358
(Earnings) losses attributable to noncontrolling interests	(41		)	17
Mandatory convertible preferred stock dividends	(36		)	(28		)
Earnings attributable to common shares	$	441		$	347
Basic earnings (losses) per common share:
Earnings from continuing operations attributable to common shares	$	1.79		$	1.26
(Losses) earnings from discontinued operations attributable to common shares	$	(0.19	)	$	0.08
Earnings attributable to common shares	$	1.60		$	1.34
Weighted-average common shares outstanding	274,674			257,932
Diluted earnings (losses) per common share:
Earnings from continuing operations attributable to common shares	$	1.78		$	1.25
(Losses) earnings from discontinued operations attributable to common shares	$	(0.19	)	$	0.08
Earnings attributable to common shares	$	1.59		$	1.33
Weighted-average common shares outstanding	277,228			259,490

See Notes to Condensed Consolidated Financial Statements.

9

SEMPRA ENERGY
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
	Sempra Energy shareholders’ equity
	Pretax amount			Income tax (expense) benefit			Net-of-tax amount			Noncontrolling interests (after-tax)			Total
	(unaudited)
	Three months ended March 31, 2019 and 2018
2019:
Net income	$	670		$	(193	)	$	477		$	41		$	518
Other comprehensive income (loss):
Foreign currency translation adjustments	32			—			32			4			36
Financial instruments	(68		)	22			(46		)	(4		)	(50		)
Pension and other postretirement benefits	4			(1		)	3			—			3
Total other comprehensive loss	(32		)	21			(11		)	—			(11		)
Comprehensive income	$	638		$	(172	)	$	466		$	41		$	507
2018:
Net income (loss)	$	664		$	(289	)	$	375		$	(17	)	$	358
Other comprehensive income (loss):
Foreign currency translation adjustments	24			—			24			5			29
Financial instruments	88			(30		)	58			10			68
Pension and other postretirement benefits	3			(1		)	2			—			2
Total other comprehensive income	115			(31		)	84			15			99
Comprehensive income (loss)	$	779		$	(320	)	$	459		$	(2	)	$	457

See Notes to Condensed Consolidated Financial Statements.

10

SEMPRA ENERGY
CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	March 31, 2019			December 31, 2018(1)
	(unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	78		$	102
Restricted cash	41			35
Accounts receivable – trade, net	1,222			1,215
Accounts receivable – other, net	320			320
Due from unconsolidated affiliates	50			37
Income taxes receivable	121			60
Inventories	189			258
Regulatory assets	87			138
Greenhouse gas allowances	61			59
Assets held for sale	374			713
Assets held for sale in discontinued operations	457			459
Other	262			249
Total current assets	3,262			3,645
Other assets:
Restricted cash	21			21
Due from unconsolidated affiliates	668			644
Regulatory assets	1,838			1,589
Nuclear decommissioning trusts	1,037			974
Investment in Oncor Holdings	9,748			9,652
Other investments	2,290			2,320
Goodwill	1,602			1,602
Other intangible assets	222			224
Dedicated assets in support of certain benefit plans	413			416
Insurance receivable for Aliso Canyon costs	477			461
Deferred income taxes	139			141
Greenhouse gas allowances	353			289
Right-of-use assets – operating leases	612			—
Assets held for sale in discontinued operations	3,388			3,259
Sundry	850			962
Total other assets	23,658			22,554
Property, plant and equipment:
Property, plant and equipment	47,105			46,615
Less accumulated depreciation and amortization	(12,407		)	(12,176		)
Property, plant and equipment, net ($287 and $295 at March 31, 2019 and December 31, 2018, respectively, related to Otay Mesa VIE)	34,698			34,439
Total assets	$	61,618		$	60,638

⁽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)
	March 31, 2019			December 31, 2018(1)
	(unaudited)
LIABILITIES AND EQUITY
Current liabilities:
Short-term debt	$	2,523		$	2,024
Accounts payable – trade	989			1,160
Accounts payable – other	166			138
Due to unconsolidated affiliates	10			10
Dividends and interest payable	496			480
Accrued compensation and benefits	264			440
Regulatory liabilities	523			105
Current portion of long-term debt and finance leases ($36 and $28 at March 31, 2019 and December 31, 2018, respectively, related to Otay Mesa VIE)	2,152			1,644
Reserve for Aliso Canyon costs	60			160
Greenhouse gas obligations	61			59
Liabilities held for sale in discontinued operations	375			368
Other	993			935
Total current liabilities	8,612			7,523
Long-term debt and finance leases ($182 and $190 at March 31, 2019 and December 31, 2018, respectively, related to Otay Mesa VIE)	19,738			20,903
Deferred credits and other liabilities:
Due to unconsolidated affiliates	38			37
Pension and other postretirement benefit plan obligations, net of plan assets	1,155			1,143
Deferred income taxes	2,622			2,321
Deferred investment tax credits	23			24
Regulatory liabilities	3,996			4,016
Asset retirement obligations	2,795			2,786
Greenhouse gas obligations	174			131
Liabilities held for sale in discontinued operations	1,046			1,013
Deferred credits and other	1,949			1,493
Total deferred credits and other liabilities	13,798			12,964
Commitments and contingencies (Note 11)
Equity:
Preferred stock (50 million shares authorized):
6% mandatory convertible preferred stock, series A (17.25 million shares issued and outstanding)	1,693			1,693
6.75% mandatory convertible preferred stock, series B (5.75 million shares issued and outstanding)	565			565
Common stock (750 million shares authorized; 274 million shares outstanding;        no par value)	5,568			5,540
Retained earnings	10,337			10,104
Accumulated other comprehensive income (loss)	(817		)	(764		)
Total Sempra Energy shareholders’ equity	17,346			17,138
Preferred stock of subsidiary	20			20
Other noncontrolling interests	2,104			2,090
Total equity	19,470			19,248
Total liabilities and equity	$	61,618		$	60,638

⁽¹⁾  Derived from audited financial statements.

See Notes to Condensed Consolidated Financial Statements.

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SEMPRA ENERGY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in millions)
	Three months ended March 31,
	2019			2018
	(unaudited)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	518		$	358
Loss (income) from discontinued operations, net of income tax	42			(28		)
Income from continuing operations, net of income tax	560			330
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	383			372
Deferred income taxes and investment tax credits	24			202
Equity (earnings) losses	(101		)	21
Share-based compensation expense	21			15
Fixed-price contracts and other derivatives	(27		)	(35		)
Other	13			7
Intercompany activities with discontinued operations, net	31			—
Net change in other working capital components	169			101
Insurance receivable for Aliso Canyon costs	(16		)	(29		)
Changes in other noncurrent assets and liabilities, net	(199		)	(94		)
Net cash provided by continuing operations	858			890
Net cash provided by discontinued operations	93			76
Net cash provided by operating activities	951			966
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(783		)	(979		)
Expenditures for investments and acquisitions, net of cash and cash equivalents acquired	(94		)	(9,617		)
Proceeds from sale of assets	327			—
Purchases of nuclear decommissioning trust assets	(225		)	(210		)
Proceeds from sales of nuclear decommissioning trust assets	225			210
Advances to unconsolidated affiliates	—			(81		)
Repayments of advances to unconsolidated affiliates	3			1
Intercompany activities with discontinued operations, net	—			(3		)
Other	7			35
Net cash used in continuing operations	(540		)	(10,644		)
Net cash used in discontinued operations	(70		)	(58		)
Net cash used in investing activities	(610		)	(10,702		)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(232		)	(194		)
Preferred dividends paid	(36		)	—
Issuances of mandatory convertible preferred stock, net of $32 in offering costs	—			1,693
Issuances of common stock, net of $24 in offering costs in 2018	11			1,278
Repurchases of common stock	(14		)	(19		)
Issuances of debt (maturities greater than 90 days)	304			5,949
Payments on debt (maturities greater than 90 days) and finance leases	(837		)	(154		)
Increase in short-term debt, net	497			1,149
Purchases of and distributions to noncontrolling interests	(27		)	(3		)
Intercompany activities with discontinued operations, net	(2		)	67
Other	—			(82		)
Net cash (used in) provided by continuing operations	(336		)	9,684
Net cash used in discontinued operations	(45		)	(6		)
Net cash (used in) provided by financing activities	(381		)	9,678

See Notes to Condensed Consolidated Financial Statements.

13

SEMPRA ENERGY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (CONTINUED)
(Dollars in millions)
	Three months ended March 31,
	2019			2018
	(unaudited)
Effect of exchange rate changes in continuing operations	—			1
Effect of exchange rate changes in discontinued operations	1			—
Effect of exchange rate changes on cash, cash equivalents and restricted cash	1			1
Decrease in cash, cash equivalents and restricted cash, including discontinued operations	(39		)	(57		)
Cash, cash equivalents and restricted cash, including discontinued operations, January 1	246			364
Cash, cash equivalents and restricted cash, including discontinued operations, March 31	$	207		$	307
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	$	257		$	108
Income tax payments, net of refunds	16			18
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Acquisition:
Assets acquired	$	—		$	9,670
Liabilities assumed	—			(104		)
Cash paid	$	—		$	9,566
Accrued capital expenditures	$	388		$	316
Accrued Merger-related transaction and financing costs	—			6
Increase in finance lease obligations for investment in property, plant and equipment	7			5
Preferred dividends declared but not paid	36			28
Common dividends issued in stock	13			13
Common dividends declared but not paid	265			236

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 March 31, 2019
Balance at December 31, 2018	$	2,258	$	5,540		$	10,104		$	(764	)	$	17,138		$	2,110		$	19,248
Cumulative-effect adjustments from
change in accounting principles						57			(42		)	15						15
Net income						477						477			41			518
Other comprehensive loss									(11		)	(11		)				(11		)
Share-based compensation expense			21									21						21
Dividends declared:
Series A preferred stock ($1.50/share)						(26		)				(26		)				(26		)
Series B preferred stock ($1.69/share)						(10		)				(10		)				(10		)
Common stock ($0.97/share)						(265		)				(265		)				(265		)
Issuances of common stock			24									24						24
Repurchases of common stock			(14		)							(14		)				(14		)
Other noncontrolling interest activities:
Distributions															(4		)	(4		)
Purchases			(3		)							(3		)	(23		)	(26		)
Balance at March 31, 2019	$	2,258	$	5,568		$	10,337		$	(817	)	$	17,346		$	2,124		$	19,470
	Three months ended March 31, 2018
Balance at December 31, 2017	$	—	$	3,149		$	10,147		$	(626	)	$	12,670		$	2,470		$	15,140
Cumulative-effect adjustments from
change in accounting principles						2			(3		)	(1		)				(1		)
Net income (loss)						375						375			(17		)	358
Other comprehensive income									84			84			15			99
Share-based compensation expense			15									15						15
Dividends declared:
Series A preferred stock ($1.60/share)						(28		)				(28		)				(28		)
Common stock ($0.90/share)						(236		)				(236		)				(236		)
Issuance of series A preferred stock	1,693											1,693						1,693
Issuances of common stock			1,291									1,291						1,291
Repurchases of common stock			(19		)							(19		)				(19		)
Other noncontrolling interest activities:
Distributions															(7		)	(7		)
Balance at March 31, 2018	$	1,693	$	4,436		$	10,260		$	(545	)	$	15,844		$	2,461		$	18,305
See Notes to Condensed Consolidated Financial Statements.

15

SAN DIEGO GAS & ELECTRIC COMPANY
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
	Three months ended March 31,
	2019			2018
	(unaudited)
Operating revenues
Electric	$	940		$	884
Natural gas	205			171
Total operating revenues	1,145			1,055
Operating expenses
Cost of electric fuel and purchased power	258			274
Cost of natural gas	79			50
Operation and maintenance	286			248
Depreciation and amortization	186			166
Franchise fees and other taxes	74			69
Total operating expenses	883			807
Operating income	262			248
Other income, net	22			28
Interest income	1			1
Interest expense	(103		)	(52		)
Income before income taxes	182			225
Income tax expense	(5		)	(56		)
Net income	177			169
(Earnings) losses attributable to noncontrolling interest	(1		)	1
Earnings attributable to common shares	$	176		$	170

See Notes to Condensed Consolidated Financial Statements.

16

SAN DIEGO GAS & ELECTRIC COMPANY
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
	SDG&E shareholder’s equity
	Pretax amount		Income tax expense			Net-of-tax amount		Noncontrolling interest (after-tax)			Total
	(unaudited)
	Three months ended March 31, 2019 and 2018
2019:
Net income	$	181	$	(5	)	$	176	$	1		$	177
Other comprehensive income (loss):
Financial instruments	—		—			—		1			1
Total other comprehensive income	—		—			—		1			1
Comprehensive income	$	181	$	(5	)	$	176	$	2		$	178
2018:
Net income (loss)	$	226	$	(56	)	$	170	$	(1	)	$	169
Other comprehensive income (loss):
Financial instruments	—		—			—		4			4
Total other comprehensive income	—		—			—		4			4
Comprehensive income	$	226	$	(56	)	$	170	$	3		$	173

See Notes to Condensed Consolidated Financial Statements.

17

SAN DIEGO GAS & ELECTRIC COMPANY
CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	March 31, 2019			December 31, 2018(1)
	(unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	10		$	8
Restricted cash	21			11
Accounts receivable – trade, net	390			368
Accounts receivable – other, net	96			106
Inventories	99			102
Prepaid expenses	53			74
Regulatory assets	71			123
Fixed-price contracts and other derivatives	66			82
Greenhouse gas allowances	15			15
Other	26			5
Total current assets	847			894
Other assets:
Restricted cash	18			18
Regulatory assets	467			454
Nuclear decommissioning trusts	1,037			974
Greenhouse gas allowances	169			155
Right-of-use assets – operating leases	135			—
Sundry	421			420
Total other assets	2,247			2,021
Property, plant and equipment:
Property, plant and equipment	21,950			21,662
Less accumulated depreciation and amortization	(5,486		)	(5,352		)
Property, plant and equipment, net ($287 and $295 at March 31, 2019 and December 31, 2018, respectively, related to VIE)	16,464			16,310
Total assets	$	19,558		$	19,225

⁽¹⁾  Derived from audited financial statements.

See Notes to Condensed Consolidated Financial Statements.

18

SAN DIEGO GAS & ELECTRIC COMPANY
CONDENSED CONSOLIDATED BALANCE SHEETS (CONTINUED)
(Dollars in millions)
	March 31, 2019			December 31, 2018(1)
	(unaudited)
LIABILITIES AND EQUITY
Current liabilities:
Short-term debt	$	238		$	291
Accounts payable	360			439
Due to unconsolidated affiliates	63			61
Accrued compensation and benefits	52			117
Accrued franchise fees	60			64
Regulatory liabilities	47			53
Current portion of long-term debt and finance leases ($36 and $28 at March 31, 2019 and      December 31, 2018, respectively, related to VIE)	89			81
Customer deposits	70			70
Greenhouse gas obligations	15			15
Asset retirement obligations	93			96
Other	280			141
Total current liabilities	1,367			1,428
Long-term debt and finance leases ($182 and $190 at March 31, 2019 and December 31, 2018, respectively, related to VIE)	6,113			6,138
Deferred credits and other liabilities:
Pension and other postretirement benefit plan obligations, net of plan assets	217			212
Deferred income taxes	1,653			1,616
Deferred investment tax credits	15			16
Regulatory liabilities	2,470			2,404
Asset retirement obligations	777			778
Greenhouse gas obligations	43			30
Deferred credits and other	610			488
Total deferred credits and other liabilities	5,785			5,544
Commitments and contingencies (Note 11)
Equity:
Preferred stock (45 million shares authorized; none issued)	—			—
Common stock (255 million shares authorized; 117 million shares outstanding; no par value)	1,338			1,338
Retained earnings	4,865			4,687
Accumulated other comprehensive income (loss)	(12		)	(10		)
Total SDG&E shareholder’s equity	6,191			6,015
Noncontrolling interest	102			100
Total equity	6,293			6,115
Total liabilities and equity	$	19,558		$	19,225

⁽¹⁾  Derived from audited financial statements.

See Notes to Condensed Consolidated Financial Statements.

19

SAN DIEGO GAS & ELECTRIC COMPANY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in millions)
	Three months ended March 31,
	2019			2018
	(unaudited)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	177		$	169
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	186			166
Deferred income taxes and investment tax credits	(28		)	(11		)
Other	1			3
Net change in other working capital components	96			102
Changes in other noncurrent assets and liabilities, net	11			(25		)
Net cash provided by operating activities	443			404
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(356		)	(475		)
Purchases of nuclear decommissioning trust assets	(225		)	(210		)
Proceeds from sales of nuclear decommissioning trust assets	225			210
Net cash used in investing activities	(356		)	(475		)
CASH FLOWS FROM FINANCING ACTIVITIES
Payments on debt (maturities greater than 90 days) and finance leases	(22		)	(20		)
(Decrease) increase in short-term debt, net	(53		)	87
Net cash (used in) provided by financing activities	(75		)	67
Increase (decrease) in cash, cash equivalents and restricted cash	12			(4		)
Cash, cash equivalents and restricted cash, January 1	37			29
Cash, cash equivalents and restricted cash, March 31	$	49		$	25
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	$	86		$	39
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	$	100		$	97
Increase in finance lease obligations for investment in property, plant and equipment	4			—

See Notes to Condensed Consolidated Financial Statements.

20

SAN DIEGO GAS & ELECTRIC COMPANY
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
(Dollars in millions)
	Common stock		Retained earnings		Accumulated other comprehensive income (loss)			SDG&E shareholder's equity		Noncontrolling interest			Total equity
	(unaudited)
	Three months ended March 31, 2019
Balance at December 31, 2018	$	1,338	$	4,687	$	(10	)	$	6,015	$	100		$	6,115
Cumulative-effect adjustment from
change in accounting principle			2		(2		)	—					—
Net income			176					176		1			177
Other comprehensive income										1			1
Balance at March 31, 2019	$	1,338	$	4,865	$	(12	)	$	6,191	$	102		$	6,293
	Three months ended March 31, 2018
Balance at December 31, 2017	$	1,338	$	4,268	$	(8	)	$	5,598	$	28		$	5,626
Net income (loss)			170					170		(1		)	169
Other comprehensive income										4			4
Distributions to noncontrolling interest										(1		)	(1		)
Balance at March 31, 2018	$	1,338	$	4,438	$	(8	)	$	5,768	$	30		$	5,798

See Notes to Condensed Consolidated Financial Statements.

21

SOUTHERN CALIFORNIA GAS COMPANY
CONDENSED STATEMENTS OF OPERATIONS
(Dollars in millions)
	Three months ended March 31,
	2019			2018
	(unaudited)
Operating revenues	$	1,361		$	1,126
Operating expenses
Cost of natural gas	455			289
Operation and maintenance	410			384
Depreciation and amortization	147			135
Franchise fees and other taxes	48			40
Total operating expenses	1,060			848
Operating income	301			278
Other income, net	16			33
Interest expense	(34		)	(27		)
Income before income taxes	283			284
Income tax expense	(19		)	(59		)
Net Income/Earnings attributable to common shares	$	264		$	225

See Notes to Condensed Financial Statements.

22

SOUTHERN CALIFORNIA GAS COMPANY
CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
	Pretax amount		Income tax expense			Net-of-tax amount
	(unaudited)
	Three months ended March 31, 2019 and 2018
2019:
Net income/Comprehensive income	$	283	$	(19	)	$	264
2018:
Net income/Comprehensive income	$	284	$	(59	)	$	225

See Notes to Condensed Financial Statements.

23

SOUTHERN CALIFORNIA GAS COMPANY
CONDENSED BALANCE SHEETS
(Dollars in millions)
	March 31, 2019			December 31, 2018(1)
	(unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	3		$	18
Accounts receivable – trade, net	674			634
Accounts receivable – other, net	91			97
Due from unconsolidated affiliates	15			7
Inventories	58			134
Regulatory assets	11			12
Greenhouse gas allowances	39			37
Other	39			31
Total current assets	930			970
Other assets:
Regulatory assets	1,286			1,051
Insurance receivable for Aliso Canyon costs	477			461
Greenhouse gas allowances	164			116
Right-of-use assets – operating leases	110			—
Sundry	356			352
Total other assets	2,393			1,980
Property, plant and equipment:
Property, plant and equipment	18,347			18,138
Less accumulated depreciation and amortization	(5,766		)	(5,699		)
Property, plant and equipment, net	12,581			12,439
Total assets	$	15,904		$	15,389

⁽¹⁾  Derived from audited financial statements.

See Notes to Condensed Financial Statements.

24

SOUTHERN CALIFORNIA GAS COMPANY
CONDENSED BALANCE SHEETS (CONTINUED)
(Dollars in millions)
	March 31, 2019			December 31, 2018(1)
	(unaudited)
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities:
Short-term debt	$	190		$	256
Accounts payable – trade	427			556
Accounts payable – other	98			93
Due to unconsolidated affiliates	42			34
Accrued compensation and benefits	101			159
Regulatory liabilities	476			52
Current portion of long-term debt and finance leases	3			3
Customer deposits	71			101
Reserve for Aliso Canyon costs	60			160
Greenhouse gas obligations	39			37
Asset retirement obligations	90			90
Other	333			217
Total current liabilities	1,930			1,758
Long-term debt and finance leases	3,429			3,427
Deferred credits and other liabilities:
Pension obligation, net of plan assets	773			760
Deferred income taxes	1,204			1,177
Deferred investment tax credits	8			8
Regulatory liabilities	1,526			1,612
Asset retirement obligations	1,982			1,973
Greenhouse gas obligations	110			86
Deferred credits and other	422			330
Total deferred credits and other liabilities	6,025			5,946
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)	866			866
Retained earnings	3,656			3,390
Accumulated other comprehensive income (loss)	(24		)	(20		)
Total shareholders’ equity	4,520			4,258
Total liabilities and shareholders’ equity	$	15,904		$	15,389

⁽¹⁾  Derived from audited financial statements.

See Notes to Condensed Financial Statements.

25

SOUTHERN CALIFORNIA GAS COMPANY
CONDENSED STATEMENTS OF CASH FLOWS
(Dollars in millions)
	Three months ended March 31,
	2019			2018
	(unaudited)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	264		$	225
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	147			135
Deferred income taxes and investment tax credits	(65		)	47
Other	5			21
Net change in other working capital components	287			76
Insurance receivable for Aliso Canyon costs	(16		)	(29		)
Changes in other noncurrent assets and liabilities, net	(246		)	(56		)
Net cash provided by operating activities	376			419
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(324		)	(403		)
Other	—			3
Net cash used in investing activities	(324		)	(400		)
CASH FLOWS FROM FINANCING ACTIVITIES
Decrease in short-term debt, net	(66		)	(16		)
Payments on finance leases	(1		)	—
Net cash used in financing activities	(67		)	(16		)
(Decrease) increase in cash and cash equivalents	(15		)	3
Cash and cash equivalents, January 1	18			8
Cash and cash equivalents, March 31	$	3		$	11
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	$	26		$	18
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	$	163		$	159
Increase in finance lease obligations for investment in property, plant and equipment	3			5

See Notes to Condensed Financial Statements.

26

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 March 31, 2019
Balance at December 31, 2018	$	22	$	866	$	3,390	$	(20	)	$	4,258
Cumulative-effect adjustment from
change in accounting principle					2		(4		)	(2		)
Net income					264					264
Preferred stock dividends declared ($0.38/share)					—					—
Balance at March 31, 2019	$	22	$	866	$	3,656	$	(24	)	$	4,520
	Three months ended March 31, 2018
Balance at December 31, 2017	$	22	$	866	$	3,040	$	(21	)	$	3,907
Net income					225					225
Preferred stock dividends declared ($0.38/share)					—					—
Balance at March 31, 2018	$	22	$	866	$	3,265	$	(21	)	$	4,132

See Notes to Condensed Financial Statements.

27

SEMPRA ENERGY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

NOTE 1. GENERAL INFORMATION AND OTHER FINANCIAL DATA

PRINCIPLES OF CONSOLIDATION

Sempra Energy

Sempra Energy’s Condensed Consolidated Financial Statements include the accounts of Sempra Energy, a California-based Fortune 500 energy-services holding company, and its consolidated subsidiaries and VIEs. Sempra Global is the holding company for most of our subsidiaries that are not subject to California or Texas utility regulation. Sempra Energy’s businesses are managed within six separate reportable segments, which we discuss in Note 12. In the first quarter of 2019, our Sempra LNG & Midstream segment was renamed “Sempra LNG.” This segment name change had no impact on our historical position, results of operations, cash flow or segment level results previously reported. 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 Condensed Consolidated Financial Statements include its accounts and the accounts of a VIE of which SDG&E is the primary beneficiary, as we discuss below in “Variable Interest Entities.” SDG&E’s common stock is wholly owned by Enova Corporation, which is a wholly owned subsidiary of Sempra Energy.

SoCalGas

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

In this report, we refer to SDG&E and SoCalGas collectively as the California Utilities.

BASIS OF PRESENTATION

This is a combined report of Sempra Energy, SDG&E and SoCalGas. We provide separate information for SDG&E and SoCalGas as required. References in this report to “we,” “our” and “Sempra Energy Consolidated” are to Sempra Energy and its consolidated entities, unless otherwise indicated by the context. We have eliminated intercompany accounts and transactions within the consolidated financial statements of each reporting entity.

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 Energy and its subsidiaries and VIEs;

▪ the Condensed Consolidated Financial Statements and related Notes of SDG&E and its VIE; and

▪ the Condensed Financial Statements and related Notes of SoCalGas.

We have prepared the Condensed Consolidated Financial Statements in conformity with U.S. GAAP and in accordance with the interim-period-reporting requirements of Form 10-Q. Results of operations for interim periods are not necessarily indicative of results for the entire year. We evaluated events and transactions that occurred after March 31, 2019 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. These adjustments are only of a normal, recurring nature.

All December 31, 2018 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2018 Consolidated Financial Statements in the Annual Report, which for Sempra Energy has been retrospectively adjusted for discontinued operations, as we discuss below. 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.

28

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 reporting purposes.

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

Discontinued Operations

On January 25, 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, as the planned sale represents a strategic shift that will have a major effect on our operations and financial results. Throughout this report, the financial information for all periods presented has been adjusted to reflect the presentation of these businesses as discontinued operations, which we discuss further in Note 5. 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 the effects of regulation and revenue recognition at our utilities in Notes 1 and 3 of the Notes to Consolidated Financial Statements in the Annual Report.

Our Sempra Texas Utility segment is comprised of our equity method investment in Oncor Holdings, which owns 80.25 percent of Oncor, as we discuss in Notes 5 and 6. Oncor is a regulated electric transmission and distribution utility and prepares its financial statements in accordance with the provisions of U.S. GAAP governing rate-regulated operations.

Our Sempra Mexico segment includes the operating companies of our subsidiary, IEnova. Certain business activities at IEnova are regulated by the Comisión Reguladora de Energía (Energy Regulatory Commission in Mexico) 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 the Condensed Consolidated Balance Sheets to the sum of such amounts reported on the 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)
	March 31,		December 31,
	2019		2018
Sempra Energy Consolidated:
Cash and cash equivalents	$	78	$	102
Restricted cash, current	41		35
Restricted cash, noncurrent	21		21
Cash, cash equivalents and restricted cash in discontinued operations	67		88
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	207	$	246
SDG&E:
Cash and cash equivalents	$	10	$	8
Restricted cash, current	21		11
Restricted cash, noncurrent	18		18
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	49	$	37

29

INVENTORIES

The following table presents the components of inventories by segment.

INVENTORY BALANCES
(Dollars in millions)
	Natural gas				LNG				Materials and supplies				Total
	March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018
SDG&E	$	—	$	—	$	—	$	—	$	99	$	102	$	99	$	102
SoCalGas	12		92		—		—		46		42		58		134
Sempra Mexico	—		—		7		4		16		15		23		19
Sempra LNG	9		3		—		—		—		—		9		3
Sempra Energy Consolidated	$	21	$	95	$	7	$	4	$	161	$	159	$	189	$	258

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 on 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 March 31,
	2019		2018
Sempra Energy Consolidated	$	47	$	49
SDG&E	17		24
SoCalGas	11		13

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 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 thereby Sempra Energy, is the primary beneficiary.

Tolling Agreements

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

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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 we consider 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 we determine that SDG&E is the primary beneficiary, SDG&E and Sempra Energy consolidate the entity that owns the facility as a VIE.

Otay Mesa VIE

SDG&E has a tolling agreement to purchase power generated at OMEC, a 605-MW generating facility. Under the terms of a related agreement, OMEC LLC can require SDG&E to purchase the power plant (referred to as the put option) on or before October 3, 2019 for $280 million, subject to adjustments, or upon earlier termination of the PPA.

The facility owner, OMEC LLC, is a VIE, which we refer to as Otay Mesa VIE, of which SDG&E is the primary beneficiary. SDG&E has no OMEC LLC voting rights, holds no equity in OMEC LLC and does not operate OMEC. In addition to the risks absorbed under the tolling agreement, SDG&E absorbs separately through the put option a significant portion of the risk that the value of Otay Mesa VIE could decline. Accordingly, SDG&E and Sempra Energy consolidate Otay Mesa VIE. Otay Mesa VIE’s equity of $102 million at March 31, 2019 and $100 million at December 31, 2018 is included on the Condensed Consolidated Balance Sheets in Other Noncontrolling Interests for Sempra Energy and in Noncontrolling Interest for SDG&E.

In October 2018, SDG&E and OMEC LLC signed a resource adequacy capacity agreement for a term that would commence at the expiration of the current tolling agreement in October 2019 and end in August 2024. The capacity agreement was approved by OMEC LLC’s lenders and the CPUC in December 2018 and February 2019, respectively. However, given certain pending requests for rehearing of the CPUC’s decisions related to OMEC, on March 28, 2019, OMEC LLC exercised the put option requiring SDG&E to purchase the power plant by October 3, 2019. The outcome of these rehearing requests could impact the effectiveness of the resource adequacy capacity agreement and whether the OMEC facility is purchased by SDG&E.

OMEC LLC has a loan outstanding of $220 million at March 31, 2019, which we describe in Note 7 of the Notes to Consolidated Financial Statements in the Annual Report. SDG&E is not a party to the loan agreement and does not have any additional implicit or explicit financial responsibility to OMEC LLC, nor is SDG&E required to assume OMEC LLC’s loan under the put option.

The Condensed Consolidated Statements of Operations of Sempra Energy and SDG&E include the following amounts associated with Otay Mesa VIE. The amounts are net of eliminations of transactions between SDG&E and Otay Mesa VIE. The captions in the table below correspond to SDG&E’s Condensed Consolidated Statements of Operations.

AMOUNTS ASSOCIATED WITH OTAY MESA VIE
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Operating expenses
Cost of electric fuel and purchased power	$	(16	)	$	(16	)
Operation and maintenance	4			4
Depreciation and amortization	7			8
Total operating expenses	(5		)	(4		)
Operating income	5			4
Interest expense	(4		)	(5		)
Income (losses) before income taxes/Net income (loss)	1			(1		)
(Earnings) losses attributable to noncontrolling interest	(1		)	1
Earnings attributable to common shares	$	—		$	—

SDG&E has determined that no contracts, other than the one relating to Otay Mesa VIE described above, resulted in SDG&E being the primary beneficiary of a VIE at March 31, 2019. In addition to the tolling agreements described above, 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 that most significantly impact the economic performance of the other VIEs. In addition, SDG&E is not exposed to losses or gains as a result of these other VIEs, because all such variability would be recovered in rates. 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 Energy. We

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provide additional information about PPAs with power plant facilities that are VIEs of which SDG&E is not the primary beneficiary in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report.

We provide additional information regarding Otay Mesa VIE in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

Sempra Texas Utility

On March 9, 2018, we completed the acquisition of an indirect, 100-percent interest in Oncor Holdings, a VIE that owns an 80.25-percent interest in Oncor. Sempra Energy is not the primary beneficiary of the 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 for additional information about our equity method investment in Oncor Holdings and restrictions on our ability to influence its activities. Our current maximum exposure to loss from our interest in Oncor Holdings does not exceed the carrying value of our investment, which was $9,748 million at March 31, 2019 and $9,652 million at December 31, 2018. Our maximum exposure will fluctuate over time, including as a result of our commitment to contribute an estimated $1,025 million in capital (excluding Sempra Energy’s share of approximately $40 million for a management agreement termination fee, as well as other customary transaction costs incurred by InfraREIT that would be borne by Oncor as part of the acquisition) to partially fund Oncor’s pending acquisition of InfraREIT, which we discuss in Note 5.

Sempra Renewables

Certain of Sempra Renewables’ wind and solar power generation projects were held by limited liability companies whose members were Sempra Renewables and financial institutions. We sold the solar entities in December 2018 and the wind entities in April 2019. The financial institutions are noncontrolling tax equity investors to which earnings, tax attributes and cash flows were allocated in accordance with the respective limited liability company agreements. These entities were VIEs and Sempra Energy was the primary beneficiary, generally due to Sempra Energy’s power as the operator of the renewable energy projects to direct the activities that most significantly impacted the economic performance of these VIEs. As the primary beneficiary of these tax equity limited liability companies, we consolidated them.

Sempra Energy’s Condensed Consolidated Balance Sheets include equity of $161 million at March 31, 2019 and $158 million at December 31, 2018 of Other Noncontrolling Interests associated with these entities. Sempra Energy’s Condensed Consolidated Statements of Operations include the following amounts associated with the tax equity limited liability companies, net of eliminations of transactions between Sempra Energy and these entities.

AMOUNTS ASSOCIATED WITH TAX EQUITY ARRANGEMENTS
(Dollars in millions)
	Three months ended March 31,
	2019			2018
REVENUES
Energy-related businesses	$	6		$	17
EXPENSES
Operation and maintenance	(2		)	(4		)
Depreciation and amortization	(3		)	(11		)
Income before income taxes	1			2
Income tax benefit (expense)	1			(5		)
Net income (loss)	2			(3		)
(Earnings) losses attributable to noncontrolling interests(1)	(3		)	21
(Losses) earnings attributable to common shares	$	(1	)	$	18

⁽¹⁾ Net income or loss attributable to NCI is computed using the HLBV method and is not based on ownership percentages.

We provide additional information regarding the tax equity limited liability companies in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

Sempra LNG

Cameron LNG JV is a VIE principally due to contractual provisions that transfer certain risks to customers. Sempra Energy is not the primary beneficiary of the VIE because we do not have the power to direct the most significant activities of Cameron LNG JV, and 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 $1,255 million at

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March 31, 2019 and $1,271 million at December 31, 2018. Our current maximum exposure to loss, which fluctuates over time, includes the carrying value of our investment and the guarantees that we discuss in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.

Other Variable Interest Entities

Sempra Energy’s other businesses also enter into arrangements that could include variable interests. We evaluate these arrangements and applicable entities based on the qualitative and quantitative analyses described above. Certain of these entities are service or project companies that are VIEs because the total equity at risk is not sufficient for the entities to finance their activities without additional subordinated financial support. As the primary beneficiary of these companies, we consolidate them. The assets of these VIEs totaled approximately $502 million at March 31, 2019 and $286 million at December 31, 2018, and consisted primarily of PP&E and other long-term assets. Sempra Energy’s exposure to loss is equal to the carrying value of these assets. In all other cases, we have determined that these arrangements are not variable interests in a VIE and therefore are not subject to the U.S. GAAP requirements concerning the consolidation or disclosures of VIEs.

PENSION AND OTHER POSTRETIREMENT BENEFITS

Net Periodic Benefit Cost

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

NET PERIODIC BENEFIT COST – SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	Three months ended March 31,
	2019			2018			2019			2018
Service cost	$	27		$	33		$	4		$	6
Interest cost	35			35			9			9
Expected return on assets	(36		)	(42		)	(18		)	(18		)
Amortization of:
Prior service cost	3			3			—			—
Actuarial loss (gain)	14			9			(2		)	(1		)
Settlement charges	—			14			—			—
Net periodic benefit cost (credit)	43			52			(7		)	(4		)
Regulatory adjustment	(36		)	(45		)	7			4
Total expense recognized	$	7		$	7		$	—		$	—

NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	Three months ended March 31,
	2019			2018			2019			2018
Service cost	$	8		$	8		$	1		$	1
Interest cost	9			9			2			2
Expected return on assets	(11		)	(13		)	(3		)	(3		)
Amortization of:
Prior service cost	1			—			1			1
Actuarial loss (gain)	4			1			(1		)	(1		)
Settlement charges	—			14			—			—
Net periodic benefit cost	11			19			—			—
Regulatory adjustment	(11		)	(19		)	—			—
Total expense recognized	$	—		$	—		$	—		$	—

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NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	Three months ended March 31,
	2019			2018			2019			2018
Service cost	$	16		$	22		$	3		$	4
Interest cost	23			23			7			7
Expected return on assets	(24		)	(26		)	(14		)	(14		)
Amortization of:
Prior service cost (credit)	2			2			(1		)	(1		)
Actuarial loss (gain)	9			6			(2		)	—
Net periodic benefit cost (credit)	26			27			(7		)	(4		)
Regulatory adjustment	(25		)	(26		)	7			4
Total expense recognized	$	1		$	1		$	—		$	—

Benefit Plan Contributions

The following table shows our year-to-date contributions to pension and other postretirement benefit plans and the amounts we expect to contribute in 2019.

BENEFIT PLAN CONTRIBUTIONS
(Dollars in millions)
	Sempra Energy Consolidated		SDG&E		SoCalGas
Contributions through March 31, 2019:
Pension plans	$	9	$	—	$	1
Other postretirement benefit plans	2		—		—
Total expected contributions in 2019:
Pension plans	$	234	$	40	$	118
Other postretirement benefit plans	9		—		1

RABBI TRUST

In support of its Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans, Sempra Energy maintains dedicated assets, including a Rabbi Trust and investments in life insurance contracts, which totaled $413 million and $416 million at March 31, 2019 and December 31, 2018, respectively.

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EARNINGS PER COMMON SHARE

The following table provides EPS computations for the three months ended March 31, 2019 and 2018. 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 March 31,
	2019			2018
Numerator for continuing operations:
Income from continuing operations, net of income tax	$	560		$	330
(Earnings) losses attributable to noncontrolling interests	(32		)	24
Mandatory convertible preferred stock dividends	(36		)	(28		)
Earnings from continuing operations attributable to common shares	$	492		$	326
Numerator for discontinued operations:
(Loss) income from discontinued operations, net of income tax	$	(42	)	$	28
Earnings attributable to noncontrolling interests	(9		)	(7		)
(Losses) earnings from discontinued operations attributable to common shares	$	(51	)	$	21
Numerator for earnings:
Earnings attributable to common shares	$	441		$	347
Denominator:
Weighted-average common shares outstanding for basic EPS(1)	274,674			257,932
Dilutive effect of stock options and RSUs(2)	969			933
Dilutive effect of common shares sold forward	1,585			625
Weighted-average common shares outstanding for diluted EPS	277,228			259,490
Basic EPS:
Earnings from continuing operations attributable to common shares	$	1.79		$	1.26
(Losses) earnings from discontinued operations attributable to common shares	$	(0.19	)	$	0.08
Earnings attributable to common shares	$	1.60		$	1.34
Diluted EPS:
Earnings from continuing operations attributable to common shares	$	1.78		$	1.25
(Losses) earnings from discontinued operations attributable to common shares	$	(0.19	)	$	0.08
Earnings attributable to common shares	$	1.59		$	1.33

⁽¹⁾ Includes 613 and 628 average fully vested RSUs held in our Deferred Compensation Plan for the three months ended March 31, 2019 and 2018, respectively. These fully vested RSUs are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

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

The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect. The computation of diluted EPS for the three months ended March 31, 2019 and 2018 excludes 316,385 and 80,449 potentially dilutive shares, respectively, because to include them would be antidilutive for the period. However, these shares could potentially dilute basic EPS in the future.

The potentially dilutive impact from the forward sale of our common stock pursuant to the forward sale agreements that we entered into in 2018 is reflected in our diluted EPS calculation using the treasury stock method. We anticipate there will be a dilutive effect on our EPS when the average market price of shares of our common stock is above the applicable adjusted forward sale price, subject to increase or decrease based on the overnight bank funding rate, less a spread, and subject to decrease by

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amounts related to expected dividends on shares of our common stock during the term of the forward sale agreements. Additionally, if we decide to physically settle or net share settle the forward sale agreements, delivery of our shares to the forward purchasers on any such physical settlement or net share settlement of the forward sale agreements would result in dilution to our EPS.

The potentially dilutive impact from mandatory convertible preferred stock that we issued in 2018 is calculated under the if-converted method. The computation of diluted EPS for the three months ended March 31, 2019 and 2018 excludes 18,601,085 and 15,592,572 potentially dilutive shares, respectively, because to include them would be antidilutive for the period. However, these shares could potentially dilute basic EPS in the future.

Pursuant to our Sempra Energy share-based compensation plans, Sempra Energy’s Board of Directors granted 261,075 non-qualified stock options that are exercisable over a three-year period, 384,373 performance-based RSUs and 214,502 service-based RSUs in the three months ended March 31, 2019, primarily in January.

We discuss share-based compensation plans and related awards further in Note 10 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 March 31, 2019 and 2018
Sempra Energy Consolidated(2):
Balance as of December 31, 2018	$	(564	)	$	(82	)	$	(118	)	$	(764	)
Cumulative-effect adjustment from change in accounting principle	—			(25		)	(17		)	(42		)
OCI before reclassifications	32			(45		)	1			(12		)
Amounts reclassified from AOCI	—			(1		)	2			1
Net OCI	32			(46		)	3			(11		)
Balance as of March 31, 2019	$	(532	)	$	(153	)	$	(132	)	$	(817	)
Balance as of December 31, 2017	$	(420	)	$	(122	)	$	(84	)	$	(626	)
Cumulative-effect adjustment from change in accounting principle	—			(3		)	—			(3		)
OCI before reclassifications	24			66			—			90
Amounts reclassified from AOCI	—			(8		)	2			(6		)
Net OCI	24			58			2			84
Balance as of March 31, 2018	$	(396	)	$	(67	)	$	(82	)	$	(545	)
SDG&E:
Balance as of December 31, 2018							$	(10	)	$	(10	)
Cumulative-effect adjustment from change in accounting principle							(2		)	(2		)
Balance as of March 31, 2019							$	(12	)	$	(12	)
Balance as of December 31, 2017 and March 31, 2018							$	(8	)	$	(8	)
SoCalGas:
Balance as of December 31, 2018				$	(12	)	$	(8	)	$	(20	)
Cumulative-effect adjustment from change in accounting principle				(2		)	(2		)	(4		)
Balance as of March 31, 2019				$	(14	)	$	(10	)	$	(24	)
Balance as of December 31, 2017 and March 31, 2018				$	(13	)	$	(8	)	$	(21	)

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

⁽²⁾  Includes discontinued operations.

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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 March 31,
	2019			2018
Sempra Energy Consolidated:
Financial instruments:
Interest rate and foreign exchange instruments(1)	$	1		$	(2	)	Interest Expense
	(3		)	(18		)	Other Income, Net
Interest rate and foreign exchange instruments	1			4			Equity Earnings (Losses)
Foreign exchange instruments	1			—			Revenues: Energy-Related Businesses
Total before income tax	—			(16		)
	—			3			Income Tax Expense
Net of income tax	—			(13		)
	(1		)	5			(Earnings) Losses Attributable to Noncontrolling Interests
	$	(1	)	$	(8	)
Pension and other postretirement benefits:
Amortization of actuarial loss(2)	$	2		$	3		Other Income, Net
Amortization of prior service cost(2)	1			—			Other Income, Net
Total before income tax	3			3
	(1		)	(1		)	Income Tax Expense
Net of income tax	$	2		$	2
Total reclassifications for the period, net of tax	$	1		$	(6	)
SDG&E:
Financial instruments:
Interest rate instruments(1)	$	1		$	3		Interest Expense
	(1		)	(3		)	(Earnings) Losses Attributable to Noncontrolling Interest
Total reclassifications for the period, net of tax	$	—		$	—

⁽¹⁾  Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.

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

For the three months ended March 31, 2019 and 2018, reclassifications out of AOCI to net income were negligible for SoCalGas.

SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS

Sempra Energy Mandatory Convertible Preferred Stock Offerings

In January 2018, we issued 17,250,000 shares of our series A preferred stock in a registered public offering resulting in net proceeds of approximately $1.69 billion. In July 2018, we issued 5,750,000 shares of our series B preferred stock in a registered public offering resulting in net proceeds of approximately $565 million. Each share of series A preferred stock and series B preferred stock has a liquidation value of $100.00. We discuss the preferred stock offerings in Note 13 of the Notes to Consolidated Financial Statements in the Annual Report.

Sempra Energy Common Stock Offerings

In January 2018, we completed the offering of 26,869,158 shares of our common stock, no par value, in a registered public offering at $107.00 per share (approximately $105.07 per share after deducting underwriting discounts), pursuant to forward sale agreements. We received net proceeds totaling approximately $1.27 billion from the sale of shares in the January 2018 offering (including $367 million to cover overallotments) and from the settlement of forward sales in the first quarter of 2018 under the forward sale agreements. We received net proceeds of approximately $800 million from the settlement of forward sales in the second quarter of 2018 under the forward sale agreements. In July 2018, we completed the offering of 11,212,500 shares of our

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common stock, no par value, in a registered public offering at $113.75 per share (approximately $111.87 per share after deducting underwriting discounts), pursuant to forward sale agreements. We received net proceeds of approximately $164 million from the sale of shares in the July 2018 offering to cover overallotments. We discuss the common stock offerings in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report.

As of May 7, 2019, a total of 16,906,185 shares of Sempra Energy common stock remain subject to future settlement under these forward sale agreements, which may be settled on one or more dates specified by us occurring no later than December 15, 2019, which is the final settlement date under the agreements. Although we expect to settle the forward sale agreements entirely by the physical delivery of shares of our common stock in exchange for cash proceeds, we may, subject to certain conditions, elect cash settlement or net share settlement for all or a portion of our obligations under the forward sale agreements. The forward sale agreements are also subject to acceleration by the forward purchasers upon the occurrence of certain events.

SoCalGas Preferred Stock

The preferred stock at SoCalGas is presented at Sempra Energy as a noncontrolling interest. Sempra Energy records charges against income related to NCI for preferred stock dividends declared by SoCalGas. We provide additional information regarding preferred stock in Note 13 of the Notes to Consolidated Financial Statements in the Annual Report.

Other Noncontrolling Interests

Ownership interests that are held by owners other than Sempra Energy and SDG&E in subsidiaries or entities consolidated by them are accounted for and reported as NCI.

Sempra Mexico

In the first quarter of 2019, IEnova repurchased 1,600,000 shares of its outstanding common stock held by NCI for approximately $6 million, resulting in an increase in Sempra Energy’s ownership interest in IEnova from 66.5 percent at December 31, 2018 to 66.6 percent at March 31, 2019.

Sempra Renewables

As we discuss in Note 5, in April 2019, Sempra Renewables sold its remaining wind assets and investments, which included its wind tax equity arrangements. The remaining ownership interest in PXiSE Energy Solutions, LLC was subsumed into Parent and other.

Sempra LNG

On February 7, 2019, Sempra LNG purchased for $20 million the 9.1-percent minority interest in Bay Gas immediately prior to the sale of 100 percent of Bay Gas, which we discuss in Note 5.

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The following table provides information on noncontrolling ownership interests held by others (not including preferred shareholders) in Other Noncontrolling Interests in Total Equity on Sempra Energy’s Condensed Consolidated Balance Sheets.

OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
	Percent ownership held by noncontrolling interests				Equity (deficit) held by noncontrolling interests
	March 31, 2019		December 31, 2018		March 31, 2019			December 31, 2018
SDG&E:
Otay Mesa VIE	100	%	100	%	$	102		$	100
Sempra Mexico:
IEnova	33.4		33.5		1,611			1,592
IEnova subsidiaries(1)	10.0 – 47.6		10.0 – 49.0		13			13
Sempra Renewables:
Tax equity arrangements – wind(2)	NA		NA		161			158
PXiSE Energy Solutions, LLC	11.1		11.1		—			1
Sempra LNG:
Bay Gas	—		9.1		—			18
Liberty Gas Storage, LLC	24.6		24.6		(12		)	(12		)
Discontinued Operations:
Chilquinta Energía subsidiaries(1)	19.7 – 43.4		19.7 – 43.4		24			23
Luz del Sur	16.4		16.4		201			193
Tecsur	9.8		9.8		4			4
Total Sempra Energy					$	2,104		$	2,090

⁽¹⁾  IEnova and Chilquinta Energía have subsidiaries with NCI held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.

⁽²⁾  Net income or loss attributable to NCI is computed using the HLBV method and is not based on ownership percentages.

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TRANSACTIONS WITH AFFILIATES

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

AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	March 31, 2019			December 31, 2018
Sempra Energy Consolidated:
Total due from various unconsolidated affiliates – current	$	50		$	37
Sempra Mexico(1):
IMG – Note due March 15, 2022(2)	$	668		$	641
Energía Sierra Juárez – Note(3)	—			3
Total due from unconsolidated affiliates – noncurrent	$	668		$	644
Total due to various unconsolidated affiliates – current	$	(10	)	$	(10	)
Sempra Mexico(1):
Total due to unconsolidated affiliates – noncurrent – TAG – Note due December 20, 2021(4)	$	(38	)	$	(37	)
SDG&E:
Sempra Energy	$	(37	)	$	(43	)
SoCalGas	(14		)	(6		)
Various affiliates	(12		)	(12		)
Total due to unconsolidated affiliates – current	$	(63	)	$	(61	)
Income taxes due (to) from Sempra Energy(5)	$	(29	)	$	5
SoCalGas:
SDG&E	$	14		$	6
Various affiliates	1			1
Total due from unconsolidated affiliates – current	$	15		$	7
Sempra Energy	$	(39	)	$	(34	)
Various affiliates	(3		)	—
Total due to unconsolidated affiliates – current	$	(42	)	$	(34	)
Income taxes due to Sempra Energy(5)	$	(88	)	$	(4	)

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

⁽²⁾  Mexican peso-denominated revolving line of credit for up to 14.2 billion Mexican pesos or approximately $729 million U.S. dollar-equivalent, at a variable interest rate based on the 91-day Interbank Equilibrium Interest Rate plus 220 bps (10.69 percent at March 31, 2019), to finance construction of the natural gas marine pipeline.

⁽³⁾  U.S. dollar-denominated loan, at a variable interest rate based on the 30-day LIBOR plus 637.5 bps (8.89 percent at December 31, 2018).

⁽⁴⁾  U.S. dollar-denominated loan, at a variable interest rate based on the 6-month LIBOR plus 290 bps (5.54 percent at March 31, 2019).

⁽⁵⁾  SDG&E and SoCalGas are included in the consolidated income tax return of Sempra Energy and are allocated income tax expense from Sempra Energy in an amount equal to that which would result from each company having always filed a separate return.

The following table summarizes revenues and cost of sales from unconsolidated affiliates.

REVENUES AND COST OF SALES FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended March 31,
	2019		2018
Revenues:
Sempra Energy Consolidated	$	14	$	16
SDG&E	1		2
SoCalGas	17		17
Cost of Sales:
Sempra Energy Consolidated	$	14	$	12
SDG&E	20		19
SoCalGas	4		—

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Guarantees

Sempra Energy has provided guarantees to certain of its JVs, including guarantees related to the financing of the Cameron LNG JV project, as we discuss in Note 6 below and in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.

OTHER INCOME, NET

Other Income, Net on the Condensed Consolidated Statements of Operations consisted of the following:

OTHER INCOME, NET
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Sempra Energy Consolidated:
Allowance for equity funds used during construction	$	21		$	27
Investment gains (losses)(1)	26			(1		)
Gains on interest rate and foreign exchange instruments, net	13			62
Foreign currency transaction gains, net(2)	7			30
Non-service component of net periodic benefit credit	24			32
Penalties related to billing practices OII	(8		)	—
Interest on regulatory balancing accounts, net	(1		)	—
Sundry, net	—			2
Total	$	82		$	152
SDG&E:
Allowance for equity funds used during construction	$	12		$	18
Non-service component of net periodic benefit credit	9			9
Sundry, net	1			1
Total	$	22		$	28
SoCalGas:
Allowance for equity funds used during construction	$	8		$	9
Non-service component of net periodic benefit credit	18			25
Penalties related to billing practices OII	(8		)	—
Interest on regulatory balancing accounts, net	(1		)	—
Sundry, net	(1		)	(1		)
Total	$	16		$	33

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

⁽²⁾  Includes gains of $10 million and $39 million in the three months ended March 31, 2019 and 2018, respectively, from translation to U.S. dollars of a Mexican peso-denominated loan to the IMG JV, which are offset by corresponding amounts included in Equity Earnings (Losses) on the Condensed Consolidated Statements of Operations.

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INCOME TAXES

We provide our calculations of ETRs in the following table.

INCOME TAX EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Sempra Energy Consolidated:
Income tax expense from continuing operations	$	42		$	242
Income from continuing operations before income taxes
and equity earnings (losses) of unconsolidated entities	$	501		$	593
Equity earnings, before income tax(1)	5			5
Pretax income	$	506		$	598
Effective income tax rate	8		%	40		%
SDG&E:
Income tax expense	$	5		$	56
Income before income taxes	$	182		$	225
Effective income tax rate	3		%	25		%
SoCalGas:
Income tax expense	$	19		$	59
Income before income taxes	$	283		$	284
Effective income tax rate	7		%	21		%

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

Sempra Energy, 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; and

▪ 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. Such effects are partially mitigated by net gains (losses) from foreign currency derivatives that are hedging Sempra Mexico parent’s exposure to movements in the Mexico peso from its controlling interest in IEnova.

In the three months ended March 31, 2019, SDG&E and SoCalGas recorded income tax benefits of $31 million and $35 million, respectively, from the release of a regulatory liability established in connection with 2017 tax reform for excess deferred income tax balances that the CPUC directed be allocated to shareholders in a January 2019 decision.

Discontinued Operations

On January 25, 2019, our board of directors approved a plan to sell our South American businesses, as we discuss in Note 5. Prior to this decision, our repatriation estimate excluded post-2017 earnings and other basis differences related to our South American

42

businesses. Because of our decision to sell our South American businesses, we no longer assert indefinite reinvestment of these basis differences and have recorded the following in discontinued operations in the three months ended March 31, 2019:

▪ $103 million income tax expense related to outside basis differences existing as of the January 25, 2019 approval of our plan to sell our South American businesses; and

▪ $13 million income tax expense related to the increase in outside basis differences from 2019 earnings since January 25, 2019.

We have not changed our indefinite reinvestment assertion or repatriation plan for our continuing international operations.

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 2016-02, “Leases,” ASU 2018-01, “Land Easement Practical Expedient for Transition to Topic 842,” ASU 2018-10, “Codification Improvements to Topic 842, Leases,” ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” ASU 2018-20, “Narrow-Scope Improvements for Lessors” and ASU 2019-01, “Leases (Topic 842): Codification Improvements” (collectively referred to as the “lease standard”): In 2016, the FASB began issuing the first in a series of ASUs intended to increase transparency and comparability among organizations with leasing activities. The most significant provision of the lease standard is the requirement that lessees recognize operating lease ROU assets and lease liabilities on the balance sheet.

We adopted the lease standard on January 1, 2019, using the optional transition method to apply the new guidance prospectively as of January 1, 2019, rather than as of the earliest period presented. We elected the package of practical expedients that permits us to not reassess (a) whether a contract is or contains a lease, (b) lease classification or (c) determination of initial direct costs, which allows us to carry forward accounting conclusions under previous U.S. GAAP on contracts that commenced prior to adoption of the lease standard. We also elected the land easement practical expedient, which allows us to continue to account for pre-existing land easements under our accounting policy that existed before adoption of the lease standard. We did not elect the practical expedient to use hindsight in making judgments when determining the lease term.

The adoption of the lease standard did not change our previously reported financial statements. However, in accordance with the lease standard, on a prospective basis, a significant portion of finance lease costs for PPAs that have historically been presented in Cost of Electric Fuel and Purchased Power are now presented in Depreciation and Amortization Expense and Interest Expense on Sempra Energy’s and SDG&E’s statements of operations. Additionally, the adoption of the lease standard had a material impact on our balance sheets at January 1, 2019 due to the initial recognition of ROU assets and lease liabilities for operating leases. Our finance leases were already included on our balance sheets prior to adoption of the lease standard, consistent with previous U.S. GAAP for capital leases.

The following table shows the initial (decreases) increases on our balance sheets at January 1, 2019 from adoption of the lease standard.

IMPACT FROM ADOPTION OF THE LEASE STANDARD
(Dollars in millions)
	Sempra Energy Consolidated			SDG&E		SoCalGas
Assets held for sale	$	13		$	—	$	—
Sundry	(71		)	—		—
Property, plant and equipment, net	(147		)	—		—
Right-of-use assets – operating leases	603			130		116
Deferred income tax assets	(3		)	—		—
Other current liabilities	80			20		23
Long-term debt	(138		)	—		—
Deferred credits and other	436			110		93
Retained earnings	17			—		—

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As a result of the adoption of the lease standard, we derecognized our corporate headquarters building lease in accordance with the transition provisions for build-to-suit arrangements. On a prospective basis, we will account for the corporate headquarters building lease as an operating lease. The initial impact is included in the above table.

We include additional disclosures about our leases in Note 11.

ASU 2016-13, “Measurement of Credit Losses on Financial Instruments”: ASU 2016-13 changes how entities will measure credit losses for most financial assets and certain other instruments. The standard introduces an “expected credit loss” impairment model that requires immediate recognition of estimated credit losses expected to occur over the remaining life of most financial assets measured at amortized cost, including trade and other receivables, loan commitments and financial guarantees. ASU 2016-13 also requires use of an allowance to record estimated credit losses on available-for-sale debt securities and expands disclosure requirements regarding an entity’s assumptions, models and methods for estimating the credit losses.

For public entities, ASU 2016-13 is effective for fiscal years beginning after December 15, 2019, including interim periods therein, with early adoption permitted for fiscal years beginning after December 15, 2018. The amendments are to be applied using a modified retrospective approach through a cumulative-effect adjustment to retained earnings at the beginning of the first reporting period in the year of adoption. We are currently evaluating the impact of the standard on our ongoing financial reporting and plan to adopt the standard on January 1, 2020.

ASU 2017-04, “Simplifying the Test for Goodwill Impairment”: ASU 2017-04 removes the second step of the goodwill impairment test, which requires a hypothetical purchase price allocation. An entity will be required to apply a one-step quantitative test and record the amount of goodwill impairment as the excess of a reporting unit’s carrying amount over its fair value, not to exceed the carrying amount of goodwill. For public entities, ASU 2017-04 is effective for annual or interim goodwill impairment tests in fiscal years beginning after December 15, 2019, with early adoption permitted. The amendments are to be applied on a prospective basis. We plan to adopt the standard on January 1, 2020.

ASU 2018-02, “Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income”: ASU 2018-02 contains amendments that allow a reclassification from AOCI to retained earnings for stranded tax effects resulting from the TCJA. Under ASU 2018-02, an entity is required to provide certain disclosures regarding stranded tax effects, including its accounting policy related to releasing the income tax effects from AOCI. The amendments in this update can be applied either as of the beginning of the period of adoption or retrospectively as of the date of enactment of the TCJA and to each period in which the effect of the TCJA is recognized. We adopted ASU 2018-02 on January 1, 2019 and reclassified the income tax effects of the TCJA from AOCI to retained earnings.

The impact from adoption of ASU 2018-02 on January 1, 2019 was as follows:

▪ Sempra Energy: increase of $40 million to beginning Retained Earnings, $2 million to noncurrent Regulatory Liabilities and $42 million to Accumulated Other Comprehensive Loss;

▪ SDG&E: increase of $2 million to beginning Retained Earnings and Accumulated Other Comprehensive Loss; and

▪ SoCalGas: increase of $2 million to beginning Retained Earnings, $2 million to noncurrent Regulatory Liabilities and $4 million to Accumulated Other Comprehensive Loss.

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)
	Three months ended March 31, 2019
	SDG&E			SoCalGas			Sempra Mexico		Sempra Renewables		Sempra LNG		Consolidating adjustments			Sempra Energy Consolidated
By major service line:
Utilities	$	1,236		$	1,528		$	27	$	—	$	—	$	(18	)	$	2,773
Midstream	—			—			171		—		67		(59		)	179
Renewables	—			—			20		4		—		—			24
Other	—			—			66		—		1		—			67
Revenues from contracts with customers	$	1,236		$	1,528		$	284	$	4	$	68	$	(77	)	$	3,043
By market:
Electric	$	997		$	—		$	86	$	4	$	1	$	(1	)	$	1,087
Gas	239			1,528			198		—		67		(76		)	1,956
Revenues from contracts with customers	$	1,236		$	1,528		$	284	$	4	$	68	$	(77	)	$	3,043
Revenues from contracts with customers	$	1,236		$	1,528		$	284	$	4	$	68	$	(77	)	$	3,043
Utilities regulatory revenues	(91		)	(167		)	—		—		—		—			(258		)
Other revenues	—			—			99		3		73		(62		)	113
Total revenues	$	1,145		$	1,361		$	383	$	7	$	141	$	(139	)	$	2,898
	Three months ended March 31, 2018
By major service line:
Utilities	$	1,131		$	1,081		$	28	$	—	$	—	$	(19	)	$	2,221
Midstream	—			—			143		—		54		(21		)	176
Renewables	—			—			22		11		1		(1		)	33
Other	—			—			41		—		2		(2		)	41
Revenues from contracts with customers	$	1,131		$	1,081		$	234	$	11	$	57	$	(43	)	$	2,471
By market:
Electric	$	963		$	—		$	62	$	11	$	2	$	(4	)	$	1,034
Gas	168			1,081			172		—		55		(39		)	1,437
Revenues from contracts with customers	$	1,131		$	1,081		$	234	$	11	$	57	$	(43	)	$	2,471
Revenues from contracts with customers	$	1,131		$	1,081		$	234	$	11	$	57	$	(43	)	$	2,471
Utilities regulatory revenues	(76		)	45			—		—		—		—			(31		)
Other revenues	—			—			74		14		47		(39		)	96
Total revenues	$	1,055		$	1,126		$	308	$	25	$	104	$	(82	)	$	2,536

Remaining Performance Obligations    

For contracts greater than one year, at March 31, 2019, we expect to recognize revenue related to the fixed fee component of the consideration as shown below. SoCalGas did not have any such remaining performance obligations at March 31, 2019.

REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra Energy Consolidated		SDG&E
2019 (excluding first three months of 2019)	$	384	$	2
2020	512		3
2021	513		3
2022	515		3
2023	509		3
Thereafter	2,784		52
Total revenues to be recognized	$	5,217	$	66

⁽¹⁾ Excludes intercompany transactions.

Contract Balances from Revenues from Contracts with Customers

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Activities within Sempra Energy’s contract liabilities are presented below. There were no contract liabilities at SDG&E or SoCalGas for the three months ended March 31, 2019 and 2018.

CONTRACT LIABILITIES
(Dollars in millions)
Balance at January 1, 2019	$	(70	)
Revenue from performance obligations satisfied during reporting period	1
Payments received in advance	(2		)
Balance at March 31, 2019(1)	$	(71	)
Balance at January 1, 2018	$	—
Adoption of ASC 606 adjustment	(61		)
Revenue from performance obligations satisfied during reporting period	5
Payments received in advance	(7		)
Balance at March 31, 2018	$	(63	)

⁽¹⁾ Includes a negligible amount in Other Current Liabilities and $71 million in Deferred Credits and Other on the Sempra Energy Condensed Consolidated Balance Sheet.

Receivables from Revenues from Contracts with Customers

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

RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS
(Dollars in millions)
	March 31, 2019		December 31, 2018
Sempra Energy Consolidated:
Accounts receivable – trade, net	$	1,145	$	1,106
Accounts receivable – other, net	14		11
Due from unconsolidated affiliates – current(1)	6		4
Assets held for sale	1		6
Total	$	1,166	$	1,127
SDG&E:
Accounts receivable – trade, net	$	390	$	368
Accounts receivable – other, net	12		6
Due from unconsolidated affiliates – current(1)	3		3
Total	$	405	$	377
SoCalGas:
Accounts receivable – trade, net	$	674	$	634
Accounts receivable – other, net	2		5
Total	$	676	$	639

⁽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.

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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)
	March 31, 2019			December 31, 2018
SDG&E:
Fixed-price contracts and other derivatives	$	(144	)	$	(150	)
Deferred income taxes refundable in rates	(171		)	(236		)
Pension and other postretirement benefit plan obligations	190			186
Removal obligations	(1,946		)	(1,848		)
Unamortized loss on reacquired debt	6			7
Environmental costs	27			28
Sunrise Powerlink fire mitigation	121			120
Regulatory balancing accounts(1)
Commodity – electric	60			(8		)
Gas transportation	13			45
Safety and reliability	77			70
Public purpose programs	(80		)	(62		)
Other balancing accounts	67			145
Other regulatory liabilities, net(2)	(199		)	(177		)
Total SDG&E	(1,979		)	(1,880		)
SoCalGas:
Pension and other postretirement benefit plan obligations	479			470
Employee benefit costs	49			49
Removal obligations	(804		)	(833		)
Deferred income taxes refundable in rates	(248		)	(336		)
Unamortized loss on reacquired debt	6			7
Environmental costs	32			28
Workers’ compensation	9			9
Regulatory balancing accounts(1)
Commodity – gas, including transportation	16			196
Safety and reliability	348			332
Public purpose programs	(289		)	(325		)
Other balancing accounts	(143		)	(68		)
Other regulatory liabilities, net(2)	(160		)	(130		)
Total SoCalGas	(705		)	(601		)
Sempra Mexico:
Deferred income taxes recoverable in rates	81			81
Other regulatory assets	9			6
Total Sempra Energy Consolidated	$	(2,594	)	$	(2,394	)

⁽¹⁾  At March 31, 2019 and December 31, 2018, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $84 million and $78 million, respectively, and for SoCalGas was $405 million and $185 million, respectively. 

⁽²⁾   Includes regulatory assets earning a rate of return.

CALIFORNIA UTILITIES

CPUC General Rate Case

The CPUC uses a GRC proceeding to set sufficient rates to allow the California Utilities to recover their reasonable cost of O&M and to provide the opportunity to realize their authorized rates of return on their investment.

2019 General Rate Case

On October 6, 2017, SDG&E and SoCalGas filed their 2019 GRC applications requesting CPUC approval of test year revenue requirements for 2019 and attrition year adjustments for 2020 through 2022. SDG&E and SoCalGas are seeking revenue requirements for 2019 of $2.203 billion and $2.937 billion, respectively, which is an increase of $221 million and $481 million

47

over their respective 2018 revenue requirements (the 2019 proposed and 2018 actual revenue requirements reflect the impact of various updates made during the course of the proceeding). The California Utilities are proposing post-test year revenue requirement annual attrition percentages that are estimated to result in annual increases of approximately 5 percent to 7 percent at SDG&E and approximately 6 percent to 8 percent at SoCalGas. The original GRC applications filed in October 2017 did not reflect the impact of the TCJA, which we discuss in “2016 General Rate Case” below and in Note 8 of the Notes to Consolidated Financial Statements in the Annual Report. In April 2018, SDG&E and SoCalGas updated their applications to reflect the impact of the TCJA and filed a joint proposal to address the impacts. The TCJA impact to SDG&E is a reduction of approximately $58 million to its 2019 test year revenue requirement; however, SDG&E’s 2019 requested revenue requirement is unchanged as we evaluate potentially higher costs associated with mitigating wildfire risks. The TCJA impact to SoCalGas’ 2019 requested revenue requirement is a reduction of approximately $58 million, which is reflected in its updated request.

During the course of the proceeding, Cal PA recommended 2019 revenue requirements of $1.918 billion and $2.695 billion for SDG&E and SoCalGas, respectively, which is a net decrease of $64 million for SDG&E and a net increase of $239 million for SoCalGas compared to the 2018 revenue requirements. Cal PA proposes a three-year annual attrition percentage of 4 percent for SDG&E and a range of 4 percent to 5 percent for SoCalGas. Cal PA recommends addressing SDG&E’s potential ownership of OMEC in a separate proceeding. As a result, Cal PA’s proposed 2019 revenue requirement does not include the estimated $68 million included in SDG&E’s GRC application associated with owning and operating the generating facility. As we discuss in Note 1, on March 28, 2019, OMEC LLC exercised the put option requiring SDG&E to purchase the power plant by October 3, 2019, which is subject to the results of rehearing requests. TURN and other intervenors oppose various components of our revenue requests in the 2019 GRC applications.

The results of the rate case may materially and adversely differ from what is contained in the GRC applications.

We expect a preliminary decision from the CPUC in mid-2019.

2016 General Rate Case

As we discuss in Notes 4 and 8 of the Notes to Consolidated Financial Statements in the Annual Report, the 2016 GRC FD required SDG&E and SoCalGas to each establish a two-way income tax expense memorandum account to track certain revenue variances resulting from certain differences between the income tax expense forecasted in the GRC and the income tax expense incurred from 2016 through 2018. At March 31, 2019, the recorded regulatory liability associated with these tracked amounts totaled $90 million and $95 million for SDG&E and SoCalGas, respectively. The recorded liability is primarily related to lower income tax expense incurred than was forecasted in the GRC relating to tax repairs deductions, self-developed software deductions and certain book-over-tax depreciation. The tracking accounts will remain open until the CPUC decides to close the accounts, which we expect will be reviewed in the 2019 GRC proceedings.

The 2016 GRC FD revenue requirement was authorized using a federal income tax rate of 35 percent. As a result of the TCJA, the federal income tax rate of 21 percent became effective January 1, 2018. Since SDG&E and SoCalGas continue to collect authorized revenues based on a 35 percent tax rate, SDG&E and SoCalGas are recording revenue deferrals, aligned with authorized seasonality factors, that reflect the estimated reduction in the revenue requirement. As of March 31, 2019, SDG&E and SoCalGas recorded regulatory liabilities of $95 million and $91 million, respectively, in anticipation of amounts that will benefit customers in future rates. SDG&E also recorded a $85 million regulatory liability at March 31, 2019, relating to its FERC jurisdictional rates, in anticipation of amounts that will benefit customers in future rates for the decrease in the federal income tax rate.

CPUC Cost of Capital

In April 2019, SDG&E and SoCalGas filed separate applications with the CPUC to update their cost of capital effective January 1, 2020. SDG&E proposed to adjust its authorized capital structure by increasing the amount of its common equity from 52 percent to 56 percent. SDG&E also proposed to increase its authorized ROE from 10.2 percent to 14.3 percent, including a premium for wildfire risk of 3.4 percent, and to increase its authorized return on rate base from 7.55 percent to 10.03 percent. SoCalGas proposed to adjust its authorized capital structure by increasing the amount of its common equity from 52 percent to 56 percent. SoCalGas also proposed to increase its authorized ROE from 10.05 percent to 10.7 percent and to increase its authorized return on rate base from 7.34 percent to 7.85 percent.

SOCALGAS

Billing Practices OII

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In May 2017, the CPUC issued an OII to determine whether SoCalGas violated any provisions of the California Public Utilities Code, General Orders, CPUC decisions, or other requirements pertaining to billing practices from 2014 through 2016. The CPUC examined the timeliness of monthly bills, extending the billing period for customers, and issuing estimated bills, including an examination of SoCalGas’ gas tariff rules. In January 2019, the CPUC ordered SoCalGas to pay $8 million in penalties, including $3 million payable to California’s general fund and $5 million to be credited to customers that received delayed bills (greater than 45 days) in the form of a $100 bill credit. SoCalGas filed an appeal of the CPUC’s conclusions in the order, which, in April 2019, the CPUC denied.   

NOTE 5. ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS

We consolidate assets acquired and liabilities assumed as of the purchase date and include earnings from acquisitions in consolidated earnings after the purchase date.

ACQUISITIONS

Sempra Texas Utility

On March 9, 2018, Sempra Energy completed the acquisition of an indirect, 100-percent interest in Oncor Holdings, which owned 80.03 percent of Oncor, and other EFH assets and liabilities unrelated to Oncor, pursuant to the Merger Agreement with EFH. Under the Merger Agreement, we paid Merger Consideration of $9.45 billion in cash and an additional $31 million representing an adjustment for dividends and payments pursuant to a tax sharing agreement with Oncor and Oncor Holdings. Also on March 9, 2018, in a separate transaction, Sempra Energy, through its interest in Oncor Holdings, acquired an additional 0.22 percent of the outstanding membership interests in Oncor from OMI for approximately $26 million in cash, bringing Sempra Energy’s indirect ownership in Oncor to 80.25 percent. TTI, an investment vehicle indirectly owned by third parties unaffiliated with Oncor Holdings or Sempra Energy, continues to own 19.75 percent of Oncor’s outstanding membership interests.

We discuss this acquisition, including the purchase price allocation, in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report.

Sempra South American Utilities

Compañía Transmisora del Norte Grande S.A.

On December 18, 2018, Chilquinta Energía acquired a 100-percent interest in Compañía Transmisora del Norte Grande S.A. through a sales and purchase agreement with AES Gener S.A. and its subsidiary Sociedad Eléctrica Angamos S.A. We completed the acquisition for a purchase price of $226 million and paid $208 million (net of $18 million cash acquired) with available cash on hand at Sempra South American Utilities.

We accounted for this business combination using the acquisition method of accounting. We allocated the $208 million in cash paid ($226 million purchase price less $18 million of cash acquired) to the identifiable assets acquired and liabilities assumed based on their respective fair values, with the excess recognized as goodwill, which is included in assets held for sale in discontinued operations. There were no measurement period adjustments related to this acquisition during the three months ended March 31, 2019. At March 31, 2019, the purchase price allocation was preliminary and subject to completion. Adjustments to the fair value estimates may occur as the process conducted for various valuations and assessments is finalized, primarily related to deferred income taxes.

We discuss this acquisition, including the purchase price allocation, in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report.

PENDING ACQUISITIONS

Sempra Texas Utility

On October 18, 2018, Oncor entered into the InfraREIT Merger Agreement, whereby Oncor has agreed to acquire 100 percent of the issued and outstanding shares of InfraREIT and 100 percent of the limited partnership units of its subsidiary, InfraREIT Partners, for approximately $1,275 million, or $21 per share and unit, plus approximately $40 million for a management

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agreement termination fee, as well as other customary transaction costs incurred by InfraREIT that would be borne by Oncor as part of the acquisition. In addition, the transaction includes InfraREIT’s outstanding debt, which as of March 31, 2019 was approximately $946 million. Consummation of the InfraREIT Merger Agreement is subject to the satisfaction of certain closing conditions, including the substantially concurrent consummation of the transactions contemplated by the Asset Exchange Agreement and Securities Purchase Agreement, discussed below.

On October 18, 2018, Oncor entered into the Asset Exchange Agreement, whereby SDTS has agreed to accept and assume certain assets and liabilities of SU in exchange for certain SDTS assets. As currently contemplated, SDTS would receive certain real property and other assets used in the electric transmission and distribution business in Central, North and West Texas, as well as the equity interests in GS Project Entity, LLC (a wholly owned subsidiary of SU) and SU would receive certain real property and other assets that are near the Texas-Mexico border. Immediately prior to completing the exchange, SDTS would become a wholly owned, indirect subsidiary of InfraREIT Partners. Consummation of the Asset Exchange Agreement is subject to the satisfaction of certain closing conditions, including the substantially concurrent consummation of the transactions contemplated by the Securities Purchase Agreement, discussed below.

On October 18, 2018, Sempra Energy entered into the Securities Purchase Agreement, whereby Sempra Texas Utilities Holdings I, LLC (a wholly owned subsidiary of Sempra Energy in our Sempra Texas Utility reportable segment) has agreed to acquire a 50-percent economic interest in Sharyland Holdings, LP for approximately $98 million, subject to customary closing adjustments. In connection with and prior to the consummation of the Securities Purchase Agreement, Sharyland Holdings, LP would own 100- percent of the membership interests in SU and SU would convert into a limited liability company, which is expected to be named Sharyland Utilities, LLC. Upon consummation of the Securities Purchase Agreement, Sempra Texas Utilities Holdings I, LLC would indirectly own and account for its 50-percent membership interest in Sharyland Utilities, LLC as an equity method investment. Consummation of the Securities Purchase Agreement is subject to the satisfaction of certain closing conditions, including the substantially concurrent consummation of the transactions contemplated by the InfraREIT Merger Agreement and the Asset Exchange Agreement.

For Oncor to fund its acquisition of interests in InfraREIT, Sempra Energy and certain indirect equity holders of TTI have committed to make capital contributions proportionate to their respective ownership interest in Oncor, with the amount estimated to be contributed by Sempra Energy equal to approximately $1,025 million, excluding Sempra Energy’s share of approximately $40 million for a management agreement termination fee, as well as other customary transaction costs incurred by InfraREIT that would be borne by Oncor as part of the acquisition. We expect to fund our capital contribution to Oncor and to purchase the 50-percent limited-partner interest in Sharyland Holdings, LP by utilizing a portion of the proceeds received from the sales of Sempra Renewables’ assets. The capital contributions are contingent on the satisfaction of customary conditions, including the substantially simultaneous closing of the transactions contemplated by the InfraREIT Merger Agreement, but are not a condition to the transactions contemplated therein.

The transactions are subject to the satisfaction of certain closing conditions, including approval by the PUCT. In December 2018, early termination of the 30-day waiting period required by the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, was granted. In March 2019, we received approval from the FERC and clearance from the Committee on Foreign Investment in the United States. In addition, the acquisition of InfraREIT was approved by the InfraREIT stockholders on February 7, 2019. We expect that the transactions will close in mid-2019.

DIVESTITURES

Sempra LNG

On February 7, 2019, Sempra LNG completed the sale of its non-utility natural gas storage assets in the southeast U.S. (comprised of Mississippi Hub and Bay Gas), which we classified as held for sale at December 31, 2018, to an affiliate of ArcLight Capital Partners and received cash proceeds of $322 million (subject to working capital adjustments), net of transaction costs. In January 2019, Sempra LNG completed the sale of other non-utility assets for $5 million.

ASSETS HELD FOR SALE

We classify assets as held for sale when management approves and commits to a formal plan to actively market an asset for sale and we expect the sale to close within the next 12 months. Upon classifying an asset as held for sale, we record the asset at the lower of its carrying value or its estimated fair value reduced for selling costs.

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Sempra Renewables

On February 12, 2019, Sempra Renewables entered into an agreement with American Electric Power Company, Inc. (AEP) to sell its remaining wind assets and investments. On April 22, 2019, Sempra Renewables completed the sale to AEP for $584 million in cash, subject to working capital and other customary adjustments. Upon completion of the sale, remaining nominal business activities at Sempra Renewables were subsumed into Parent and other and the Sempra Renewables segment ceased to exist.

The following table summarizes the carrying amounts of the major classes of assets and related liabilities classified as held for sale.

ASSETS HELD FOR SALE
(Dollars in millions)
	Sempra Renewables’ wind assets
	At March 31, 2019
Cash and cash equivalents	$	4
Accounts receivable – trade, net	2
Other current assets	2
Property, plant and equipment, net	366
Total assets held for sale	$	374
Accounts payable – trade	$	1
Asset retirement obligations	6
Total liabilities held for sale(1)	$	7

⁽¹⁾  Included in Other Current Liabilities on Sempra Energy’s Condensed Consolidated Balance Sheet.

Sempra Renewables’ wind equity method investments totaling $290 million at March 31, 2019, which are included in the sale to AEP, were classified as Other Investments on Sempra Energy’s Condensed Consolidated Balance Sheet.

DISCONTINUED OPERATIONS

On January 25, 2019, our board of directors approved a plan to sell our South American businesses. We launched a formal process to sell our South American businesses and expect to complete the sale by the end of 2019. We determined that these businesses, which previously constituted the Sempra South American Utilities segment, and certain activities associated with those businesses, met the held-for-sale criteria. These businesses are presented as discontinued operations, as the planned sale represents a strategic shift that will have a major effect on our operations and financial results. We do not plan to have significant continuing involvement in or be able to exercise significant influence on the operating or financial policies of these operations after they are sold. Accordingly, the results of operations, financial position and cash flows for these businesses have been reclassified to discontinued operations for all periods presented.

Discontinued operations that were previously in the Sempra South American Utilities segment include our 100-percent interest in Chilquinta Energía in Chile, our 83.6-percent interest in Luz del Sur in Peru and our 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. 

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Summarized results from discontinued operations were as follows:

DISCONTINUED OPERATIONS
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Revenues	$	421		$	426
Cost of sales	(265		)	(293		)
Operating expenses	(45		)	(54		)
Interest and other	(3		)	(5		)
Income before income taxes and equity earnings of unconsolidated entities	108			74
Income tax expense	(151		)	(47		)
Equity earnings	1			1
(Loss) income from discontinued operations, net of income tax	(42		)	28
Earnings attributable to noncontrolling interests	(9		)	(7		)
(Losses) earnings from discontinued operations attributable to common shares	$	(51	)	$	21

The following table summarizes the carrying amounts of the major classes of assets and related liabilities classified as held for sale in discontinued operations.

ASSETS HELD FOR SALE IN DISCONTINUED OPERATIONS
(Dollars in millions)
	March 31, 2019		December 31, 2018
Cash and cash equivalents	$	67	$	88
Accounts receivable, net	331		315
Due from unconsolidated affiliates	3		2
Inventories	41		38
Other current assets	15		16
Current assets	$	457	$	459
Due from unconsolidated affiliates	$	46	$	44
Goodwill and other intangible assets	834		819
Property, plant and equipment, net	2,459		2,357
Other noncurrent assets	49		39
Noncurrent assets	$	3,388	$	3,259
Short-term debt	$	46	$	55
Accounts payable	188		176
Current portion of long-term debt and finance leases	22		29
Other current liabilities	119		108
Current liabilities	$	375	$	368
Long-term debt and finance leases	$	721	$	708
Deferred income taxes	263		250
Other noncurrent liabilities	62		55
Noncurrent liabilities	$	1,046	$	1,013

NOTE 6. INVESTMENTS IN UNCONSOLIDATED ENTITIES

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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 (Losses) on the Condensed Consolidated Statements of Operations. 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.

Our equity method investments include various domestic and foreign entities. Our foreign equity method investees are corporations whose operations are generally taxable on a stand alone basis in the countries in which they operate, and we recognize our equity in such income or loss net of investee income tax.

Oncor is a domestic partnership for U.S. federal income tax purposes and is not included in the consolidated income tax return of Sempra Energy. Rather, only our equity earnings from our investment in Oncor Holdings (a disregarded entity for tax purposes) are included in our consolidated income tax return. A tax sharing agreement with TTI, Oncor Holdings and Oncor provides for the calculation of an income tax liability substantially as if Oncor Holdings and Oncor were taxed as corporations, and requires tax payments determined on that basis. While partnerships are not subject to income taxes, in consideration of the tax sharing agreement and Oncor being subject to the provisions of U.S. GAAP governing rate-regulated operations, Oncor recognizes amounts determined under cost-based regulatory rate-setting processes (with such costs including income taxes), as if it were taxed as a corporation. As a result, since Oncor Holdings consolidates Oncor, we recognize equity earnings from our investment in Oncor Holdings net of its recorded income tax.

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

SEMPRA TEXAS UTILITY

We account for our 100-percent ownership interest in Oncor Holdings as an equity method investment. Due to the ring-fencing measures, governance mechanisms, and commitments in effect following the Merger, 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 each of the first quarter of 2019 and the second quarter of 2019 through May 7, 2019, Sempra Energy contributed $56 million to Oncor, and Oncor Holdings distributed to Sempra Energy $54 million in dividends and $3 million in tax sharing payments.

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

SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS
(Dollars in millions)
	Three months ended March 31, 2019			March 9 - March 31, 2018
Operating revenues	$	1,016		$	236
Operating expense	(775		)	(185		)
Income from operations	241			51
Interest expense	(86		)	(22		)
Income tax expense	(23		)	(7		)
Net income	114			19
Noncontrolling interest held by TTI	(23		)	(4		)
Earnings attributable to Sempra Energy(1)	91			15

⁽¹⁾  Earnings at Oncor Holdings differ from earnings at the Sempra Texas Utility segment due to amortization of a tax sharing liability associated with a tax sharing arrangement and basis differences in AOCI.

SEMPRA MEXICO

Sempra Mexico invested cash of $25 million in the IMG JV in the three months ended March 31, 2018.

SEMPRA RENEWABLES

As we discuss in Note 5, in February 2019, Sempra Renewables entered into an agreement to sell its remaining wind assets and investments. At March 31, 2019, the wind investments had a carrying value of $290 million and were included in Other

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Investments on Sempra Energy’s Condensed Consolidated Balance Sheets. We completed the sale in April 2019, as we discuss in Note 5.

SEMPRA LNG

Sempra LNG capitalized $13 million and $11 million of interest in the three months ended March 31, 2019 and 2018, respectively, related to its investment in Cameron LNG JV, which has not commenced planned principal operations. In the three months ended March 31, 2019 and 2018, Sempra LNG invested cash of $25 million and $29 million, respectively, in this unconsolidated JV.

GUARANTEES

At March 31, 2019, we had outstanding guarantees aggregating a maximum of $4.2 billion with an aggregate carrying value of $10 million. We discuss these guarantees in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.

NOTE 7. DEBT AND CREDIT FACILITIES

LINES OF CREDIT

Primary U.S. Committed Lines of Credit

At March 31, 2019, Sempra Energy Consolidated had an aggregate of approximately $5.4 billion in three primary U.S. committed lines of credit for Sempra Energy, Sempra Global and the California Utilities to provide liquidity and to support commercial paper. The principal terms of these committed lines of credit, which expire in October 2020, 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)
	March 31, 2019
	Total facility			Commercial paper outstanding(1)			Available unused credit
Sempra Energy(2)	$	1,250		$	—		$	1,250
Sempra Global(3)	3,185			(1,289		)	1,896
California Utilities(4):
SDG&E	750			(238		)	512
SoCalGas	750			(190		)	560
Less: subject to a combined limit of $1 billion for both utilities	(500		)	—			(500		)
	1,000			(428		)	572
Total	$	5,435		$	(1,717	)	$	3,718

⁽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⁾  The facility also provides for issuance of up to $400 million of letters of credit on behalf of Sempra Energy with the amount of borrowings otherwise available under the facility reduced by the amount of outstanding letters of credit. No letters of credit were outstanding at March 31, 2019.

⁽³⁾  Commercial paper outstanding is before reductions of unamortized discount of $2 million. Sempra Energy guarantees Sempra Global’s obligations under the credit facility.

⁽⁴⁾  The facility also provides for the issuance of letters of credit on behalf of each utility, subject to a combined letter of credit commitment of $250 million for both utilities. The amount of borrowings otherwise available under the facility is reduced by the amount of outstanding letters of credit. No letters of credit were outstanding at March 31, 2019.

Sempra Energy, SDG&E and SoCalGas must maintain a ratio of indebtedness to total capitalization (as defined in each of the applicable credit facilities) of no more than 65 percent at the end of each quarter. At March 31, 2019, each entity was in compliance with this and all other financial covenants under its respective credit facility.

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Foreign Committed Lines of Credit

In February 2019, IEnova revised the terms of its five-year revolving credit facility by increasing the amount available under the facility from $1.17 billion to $1.5 billion, extending the expiration of the facility from August 2020 to February 2024 and increasing the syndicate of lenders from eight to 10. At March 31, 2019, available unused credit on this line was approximately $692 million.

On April 11, 2019, IEnova entered into a three-year, $100 million revolving credit agreement with Scotiabank Inverlat, S.A. Under the agreement, withdrawals may be made for up to one year in either U.S. dollars or Mexican pesos.

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 March 31, 2019, we had approximately $611 million in standby letters of credit outstanding under these agreements.

WEIGHTED-AVERAGE INTEREST RATES

The weighted-average interest rates on total short-term debt at Sempra Energy Consolidated were 3.07 percent and 2.99 percent at March 31, 2019 and December 31, 2018, respectively. The weighted-average interest rates on total short-term debt at SDG&E were 2.80 percent and 2.97 percent at March 31, 2019 and December 31, 2018, respectively. The weighted-average interest rates on total short-term debt at SoCalGas were 2.49 percent and 2.58 percent at March 31, 2019 and December 31, 2018, respectively.

INTEREST RATE SWAPS

In February 2019, Sempra Energy entered into floating-to-fixed interest rate swaps to hedge interest payments on the $850 million of variable rate notes issued in October 2017 and maturing in March 2021, resulting in an all-in fixed rate of 3.069 percent. We discuss our interest rate swaps to hedge cash flows in Note 8.

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 our asset values may fall or our liabilities 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 designate each derivative as (1) a cash flow hedge, (2) a fair value hedge, 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 hedge), on the balance sheet (fair value hedges and regulatory offsets), or recognized in earnings. 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

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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, Sempra LNG and Sempra Renewables may use natural gas and electricity derivatives, as appropriate, 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 or in Cost of Sales on the Condensed Consolidated Statements of Operations. Certain of these derivatives may also be designated as cash flow hedges. Sempra Mexico may also use natural gas energy derivatives with the objective of managing price risk and lowering natural gas prices at its distribution operations. These derivatives, which are recorded as commodity costs that are offset by regulatory account balances and recovered in rates, are recognized in Cost of Natural Gas on the Condensed Consolidated Statements of Operations.

▪ 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 GHG allowances.

The following table summarizes net energy derivative volumes.

NET ENERGY DERIVATIVE VOLUMES
(Quantities in millions)
Commodity	Unit of measure	March 31, 2019	December 31, 2018
Sempra Energy Consolidated:
Natural gas	MMBtu	33	35
Electricity	MWh	2	2
Congestion revenue rights	MWh	50	52
SDG&E:
Natural gas	MMBtu	32	33
Electricity	MWh	2	2
Congestion revenue rights	MWh	50	52

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 Energy 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. Separately, Otay Mesa VIE has entered into interest rate swap agreements, designated as cash flow hedges, to moderate its exposure to interest rate changes.

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The following table presents the net notional amounts of our interest rate derivatives, excluding JVs.

INTEREST RATE DERIVATIVES
(Dollars in millions)
	March 31, 2019			December 31, 2018
	Notional debt		Maturities	Notional debt		Maturities
Sempra Energy Consolidated:
Cash flow hedges(1)	$	1,430	2019-2032	$	594	2019-2032
SDG&E:
Cash flow hedge(1)	142		2019	142		2019

⁽¹⁾  Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE. In December 2018, OMEC LLC entered into new floating-to-fixed interest rate swaps with notional amounts of $159 million effective April 30, 2019 through October 31, 2019, and a swaption with a notional amount of $142 million effective October 31, 2019 through October 31, 2023.

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 utilize foreign currency derivatives as a means to manage the risk of exposure to significant fluctuations in our income tax expense and equity earnings from these impacts; however, we generally do not hedge our deferred income tax assets and liabilities or for inflation.

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

FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	March 31, 2019			December 31, 2018
	Notional amount		Maturities	Notional amount		Maturities
Sempra Energy Consolidated:
Cross-currency swaps	$	306	2019-2023	$	306	2019-2023
Other foreign currency derivatives	1,084		2019-2020	1,158		2019-2020

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, as the cash collateral was in excess of liability positions.

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DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	March 31, 2019
	Current assets: Other(1)			Other assets: Sundry			Current liabilities: Other			Deferred credits and other liabilities: Deferred credits and other
Sempra Energy Consolidated:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments(2)	$	—		$	—		$	(5	)	$	(146	)
Derivatives not designated as hedging instruments:
Foreign exchange instruments	12			—			—			—
Commodity contracts not subject to rate recovery	58			6			(65		)	(5		)
Associated offsetting commodity contracts	(47		)	(2		)	47			2
Commodity contracts subject to rate recovery	50			236			(41		)	(65		)
Associated offsetting commodity contracts	(5		)	(2		)	5			2
Associated offsetting cash collateral	—			—			3			3
Net amounts presented on the balance sheet	68			238			(56		)	(209		)
Additional cash collateral for commodity contracts not subject to rate recovery	25			—			—			—
Additional cash collateral for commodity contracts subject to rate recovery	26			—			—			—
Total(3)	$	119		$	238		$	(56	)	$	(209	)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	45		$	234		$	(37	)	$	(65	)
Associated offsetting commodity contracts	(5		)	(2		)	5			2
Associated offsetting cash collateral	—			—			3			3
Net amounts presented on the balance sheet	40			232			(29		)	(60		)
Additional cash collateral for commodity contracts subject to rate recovery	25			—			—			—
Total(3)	$	65		$	232		$	(29	)	$	(60	)
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	5		$	2		$	(4	)	$	—
Net amounts presented on the balance sheet	5			2			(4		)	—
Additional cash collateral for commodity contracts subject to rate recovery	1			—			—			—
Total	$	6		$	2		$	(4	)	$	—

 

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

⁽²⁾ Includes a negligible amount for Otay Mesa VIE.

⁽³⁾ 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, 2018
	Current assets: Other(1)			Other assets: Sundry			Current liabilities: Other			Deferred credits and other liabilities: Deferred credits and other
Sempra Energy Consolidated:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments(2)	$	2		$	—		$	(3	)	$	(147	)
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	153			7			(164		)	(6		)
Associated offsetting commodity contracts	(133		)	(3		)	133			3
Commodity contracts subject to rate recovery	64			233			(42		)	(72		)
Associated offsetting commodity contracts	(6		)	(2		)	6			2
Associated offsetting cash collateral	—			—			—			2
Net amounts presented on the balance sheet	80			235			(70		)	(218		)
Additional cash collateral for commodity contracts not subject to rate recovery	19			—			—			—
Additional cash collateral for commodity contracts subject to rate recovery	33			—			—			—
Total(3)	$	132		$	235		$	(70	)	$	(218	)
SDG&E:
Derivatives designated as hedging instruments:
Interest rate instruments(2)	$	—		$	—		$	(1	)	$	—
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	60			233			(37		)	(72		)
Associated offsetting commodity contracts	(6		)	(2		)	6			2
Associated offsetting cash collateral	—			—			—			2
Net amounts presented on the balance sheet	54			231			(32		)	(68		)
Additional cash collateral for commodity contracts subject to rate recovery	28			—			—			—
Total(3)	$	82		$	231		$	(32	)	$	(68	)
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	4		$	—		$	(5	)	$	—
Net amounts presented on the balance sheet	4			—			(5		)	—
Additional cash collateral for commodity contracts subject to rate recovery	5			—			—			—
Total	$	9		$	—		$	(5	)	$	—

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

⁽²⁾ Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE.

⁽³⁾ Normal purchase contracts previously measured at fair value are excluded.

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The table below 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 March 31,							Three months ended March 31,
	2019			2018			Location	2019			2018
Sempra Energy Consolidated:
Interest rate and foreign exchange instruments(1)	$	(3	)	$	54		Interest Expense	$	(1	)	$	2
							Other Income, Net	3			18
Interest rate and foreign exchange instruments	(68		)	70			Equity Earnings (Losses)	(1		)	(4		)
Foreign exchange instruments	(3		)	(7		)	Revenues: Energy- Related Businesses	(1		)	—
Total	$	(74	)	$	117			$	—		$	16
SDG&E:
Interest rate instruments(1)	$	—		$	1		Interest Expense	$	(1	)	$	(3	)

⁽¹⁾  Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.

For Sempra Energy Consolidated, we expect that net gains of $5 million, which are net of income tax expense, that are currently recorded in AOCI (including $1 million of losses in NCI related to Otay Mesa VIE at SDG&E) related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. SoCalGas expects that $1 million of losses, net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. Actual amounts ultimately reclassified into earnings depend on the interest rates in effect when derivative contracts mature.

For all forecasted transactions, the maximum remaining term over which we are hedging exposure to the variability of cash flows at March 31, 2019 is approximately 13 years and less than one year for Sempra Energy Consolidated and SDG&E, respectively. The maximum remaining term for which we are hedging exposure to the variability of cash flows at our equity method investees is 15 years.

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

UNDESIGNATED DERIVATIVE IMPACTS
(Dollars in millions)
		Pretax gain (loss) on derivatives recognized in earnings
		Three months ended March 31,
	Location	2019		2018
Sempra Energy Consolidated:
Foreign exchange instruments	Other Income, Net	$	10	$	44
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	—		(9		)
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	2		2
Commodity contracts subject to rate recovery	Cost of Natural Gas	2		1
Total		$	14	$	38
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	2	$	2
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas	$	2	$	1

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CONTINGENT FEATURES

For Sempra Energy Consolidated, 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 Energy Consolidated, the total fair value of this group of derivative instruments in a net liability position at March 31, 2019 and December 31, 2018 was $14 million and $16 million, respectively. For SoCalGas, the total fair value of this group of derivative instruments in a net liability position at March 31, 2019 and December 31, 2018 was $4 million and $5 million, respectively. At March 31, 2019, if the credit ratings of Sempra Energy or SoCalGas were reduced below investment grade, $15 million and $4 million, respectively, of additional assets could be required to be posted as collateral for these derivative contracts.

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

NOTE 9. FAIR VALUE MEASUREMENTS

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

RECURRING FAIR VALUE MEASURES

The three tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis at March 31, 2019 and December 31, 2018. 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 value 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, 2018.

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 (other than a $7 million investment at March 31, 2019 measured at net asset value):

▪ Nuclear decommissioning trusts reflect the assets of SDG&E’s NDT, excluding cash balances. 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.”

▪ 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 March 31, 2019 and December 31, 2018.

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RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
	Fair value at March 31, 2019
	Level 1			Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	454		$	5	$	—	$	459
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies	39			9		—		48
Municipal bonds	—			279		—		279
Other securities	—			238		—		238
Total debt securities	39			526		—		565
Total nuclear decommissioning trusts(1)	493			531		—		1,024
Interest rate and foreign exchange instruments	—			12		—		12
Commodity contracts not subject to rate recovery	—			15		—		15
Effect of netting and allocation of collateral(2)	25			—		—		25
Commodity contracts subject to rate recovery	—			8		271		279
Effect of netting and allocation of collateral(2)	21			—		5		26
Total	$	539		$	566	$	276	$	1,381
Liabilities:
Interest rate and foreign exchange instruments	$	—		$	151	$	—	$	151
Commodity contracts not subject to rate recovery	—			21		—		21
Commodity contracts subject to rate recovery	6			4		89		99
Effect of netting and allocation of collateral(2)	(6		)	—		—		(6		)
Total	$	—		$	176	$	89	$	265
	Fair value at December 31, 2018
	Level 1			Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	407		$	4	$	—	$	411
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies	43			10		—		53
Municipal bonds	—			269		—		269
Other securities	—			234		—		234
Total debt securities	43			513		—		556
Total nuclear decommissioning trusts(1)	450			517		—		967
Interest rate and foreign exchange instruments	—			2		—		2
Commodity contracts not subject to rate recovery	—			24		—		24
Effect of netting and allocation of collateral(2)	19			—		—		19
Commodity contracts subject to rate recovery	2			9		278		289
Effect of netting and allocation of collateral(2)	28			—		5		33
Total	$	499		$	552	$	283	$	1,334
Liabilities:
Interest rate and foreign exchange instruments	$	—		$	150	$	—	$	150
Commodity contracts not subject to rate recovery	—			34		—		34
Commodity contracts subject to rate recovery	2			5		99		106
Effect of netting and allocation of collateral(2)	(2		)	—		—		(2		)
Total	$	—		$	189	$	99	$	288

⁽¹⁾  Excludes cash balances and cash equivalents.

⁽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 March 31, 2019
	Level 1			Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	454		$	5	$	—	$	459
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies	39			9		—		48
Municipal bonds	—			279		—		279
Other securities	—			238		—		238
Total debt securities	39			526		—		565
Total nuclear decommissioning trusts(1)	493			531		—		1,024
Commodity contracts subject to rate recovery	—			1		271		272
Effect of netting and allocation of collateral(2)	20			—		5		25
Total	$	513		$	532	$	276	$	1,321
Liabilities:
Commodity contracts subject to rate recovery	$	6		$	—	$	89	$	95
Effect of netting and allocation of collateral(2)	(6		)	—		—		(6		)
Total	$	—		$	—	$	89	$	89
	Fair value at December 31, 2018
	Level 1			Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	407		$	4	$	—	$	411
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies	43			10		—		53
Municipal bonds	—			269		—		269
Other securities	—			234		—		234
Total debt securities	43			513		—		556
Total nuclear decommissioning trusts(1)	450			517		—		967
Commodity contracts subject to rate recovery	1			6		278		285
Effect of netting and allocation of collateral(2)	23			—		5		28
Total	$	474		$	523	$	283	$	1,280
Liabilities:
Interest rate instruments	$	—		$	1	$	—	$	1
Commodity contracts subject to rate recovery	2			—		99		101
Effect of netting and allocation of collateral(2)	(2		)	—		—		(2		)
Total	$	—		$	1	$	99	$	100

⁽¹⁾  Excludes cash balances and cash equivalents.

⁽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 March 31, 2019
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	—	$	7	$	—	$	7
Effect of netting and allocation of collateral(1)	1		—		—		1
Total	$	1	$	7	$	—	$	8
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	4	$	—	$	4
Total	$	—	$	4	$	—	$	4
	Fair value at December 31, 2018
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	1	$	3	$	—	$	4
Effect of netting and allocation of collateral(1)	5		—		—		5
Total	$	6	$	3	$	—	$	9
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	5	$	—	$	5
Total	$	—	$	5	$	—	$	5

⁽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

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 Energy Consolidated and SDG&E.

LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Balance at January 1	$	179		$	(28	)
Realized and unrealized gains	5			4
Allocated transmission instruments	—			3
Settlements	(2		)	(19		)
Balance at March 31	$	182		$	(40	)
Change in unrealized gains (losses) relating to instruments still held at March 31	$	13		$	(8	)

⁽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
2019	$	(8.57	)	to	$	35.21	$	(2.94	)
2018	(7.25		)	to	11.99		0.09

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 were as follows:

LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS
Settlement year		Price per MWh					Weighted-average price per MWh
2019	$	23.25	to	$	81.75	$	42.49
2018		20.00	to		47.65		35.42

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

Realized gains and losses associated with CRRs and long-term 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 Instruments

The fair values of certain of our financial instruments (cash, accounts and notes 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)
	March 31, 2019
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
Sempra Energy Consolidated:
Long-term amounts due from unconsolidated affiliates	$	668	$	—	$	689	$	—	$	689
Long-term amounts due to unconsolidated affiliates	38		—		37		—		37
Total long-term debt(1)(2)	20,814		—		20,598		248		20,846
SDG&E:
Total long-term debt(2)(3)	$	4,978	$	—	$	4,918	$	220	$	5,138
SoCalGas:
Total long-term debt(4)	$	3,459	$	—	$	3,595	$	—	$	3,595
	December 31, 2018
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
Sempra Energy Consolidated:
Long-term amounts due from unconsolidated affiliates	$	644	$	—	$	648	$	4	$	652
Long-term amounts due to unconsolidated affiliates	37		—		35		—		35
Total long-term debt(2)(5)	21,340		—		20,616		247		20,863
SDG&E:
Total long-term debt(6)	$	4,996	$	—	$	4,897	$	220	$	5,117
SoCalGas:
Total long-term debt(7)	$	3,459	$	—	$	3,505	$	—	$	3,505

⁽¹⁾  Before reductions of unamortized discount and debt issuance costs of $201 million and excluding finance lease obligations of $1,277 million.

⁽²⁾  Level 3 instruments includes $220 million at both March 31, 2019 and December 31, 2018 related to Otay Mesa VIE.

⁽³⁾  Before reductions of unamortized discount and debt issuance costs of $48 million and excluding finance lease obligations of $1,272 million.

⁽⁴⁾  Before reductions of unamortized discount and debt issuance costs of $32 million and excluding finance lease obligations of $5 million.

⁽⁵⁾  Before reductions of unamortized discount and debt issuance costs of $206 million and excluding build-to-suit and capital lease obligations of $1,413 million.

⁽⁶⁾  Before reductions of unamortized discount and debt issuance costs of $49 million and excluding capital lease obligations of $1,272 million.

⁽⁷⁾  Before reductions of unamortized discount and debt issuance costs of $32 million and excluding capital lease obligations of $3 million.

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 ceased operations in June 2013, and in which SDG&E has a 20-percent 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. 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 majority of the dismantlement work is expected to take 10 years. 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 percent of the total contract price.

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

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CPUC regulations. The NDT assets are presented on the Sempra Energy 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. SDG&E has received authorization from the CPUC to access NDT funds of up to $455 million for 2013 through 2019 (2019 forecasted) SONGS decommissioning costs. This includes up to $93 million authorized by the CPUC in January 2019 to be withdrawn from the NDT for forecasted 2019 SONGS Units 2 and 3 costs as decommissioning costs are incurred.

In December 2016, the IRS and the U.S. Department of the Treasury issued proposed regulations that clarify the definition of “nuclear decommissioning costs,” which are costs that may be paid for or reimbursed from a qualified trust fund. The proposed regulations state that costs related to the construction and maintenance of independent spent fuel management installations are included in the definition of “nuclear decommissioning costs.” The proposed regulations will be effective prospectively once they are finalized; however, the IRS has stated that it will not challenge taxpayer positions consistent with the proposed regulations for taxable years ending on or after the date the proposed regulations were issued. SDG&E is awaiting the adoption of, or additional refinement to, the proposed regulations before determining whether the proposed regulations will allow SDG&E to access the NDT funds for reimbursement or payment of the spent fuel management costs incurred in 2017 and subsequent years. Further clarification of the proposed regulations could enable SDG&E to access the NDT to recover spent fuel management costs before Edison reaches final settlement with the DOE regarding the DOE’s reimbursement of these costs. Historically, the DOE’s reimbursements of spent fuel storage costs have not resulted in timely or complete recovery of these costs. We discuss the DOE’s responsibility for spent nuclear fuel below. The IRS held public hearings on the proposed regulations in October 2017. It is unclear when clarification of the proposed regulations might be provided or when the proposed regulations will be finalized.

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 March 31, 2019:
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies(1)	$	48	$	—	$	—		$	48
Municipal bonds(2)	271		8		—			279
Other securities(3)	236		3		(1		)	238
Total debt securities	555		11		(1		)	565
Equity securities	166		299		(6		)	459
Cash and cash equivalents	13		—		—			13
Total	$	734	$	310	$	(7	)	$	1,037
At December 31, 2018:
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies	$	52	$	1	$	—		$	53
Municipal bonds	266		4		(1		)	269
Other securities	238		1		(5		)	234
Total debt securities	556		6		(6		)	556
Equity securities	168		253		(10		)	411
Cash and cash equivalents	7		—		—			7
Total	$	731	$	259	$	(16	)	$	974

⁽¹⁾  Maturity dates are 2019-2049.

⁽²⁾  Maturity dates are 2019-2056.

⁽³⁾  Maturity dates are 2019-2064.

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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 March 31,
	2019			2018
Proceeds from sales	$	225		$	210
Gross realized gains	5			4
Gross realized losses	(2		)	(3		)

Net unrealized gains and losses, as well as realized gains and losses that are reinvested in the NDT, are included in noncurrent Regulatory Liabilities on Sempra Energy’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

SDG&E’s ARO related to decommissioning costs for the SONGS units was $620 million at March 31, 2019. 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 2018 dollars is approximately $810 million.

U.S. DEPARTMENT OF ENERGY NUCLEAR FUEL DISPOSAL

Spent nuclear fuel from SONGS is currently stored on-site in an ISFSI licensed by the Nuclear Regulatory Commission or temporarily in spent fuel pools. In October 2015, the California Coastal Commission approved Edison’s application for the proposed expansion of the ISFSI at SONGS. The ISFSI expansion began construction in 2016 and the transfer of the spent nuclear fuel from Units 2 and 3 to the ISFSI began in 2018. Edison suspended this transfer on August 3, 2018 due to an incident that occurred when a spent fuel canister was getting loaded into the ISFSI. The incident did not result in any harm to the public or workers and the canister was subsequently safely loaded into the IFSFI. Edison has not resumed spent fuel transfer operations at SONGS, but has publicly stated that it will resume operations once it is satisfied all corrective actions are in place and proven effective and the NRC has completed its on-site inspection activities. The ISFSI will operate until 2049, when it is assumed that the DOE will have taken custody of all the SONGS spent fuel. The ISFSI would then be decommissioned, and the site restored to its original environmental state. Until then, SONGS owners are responsible for interim storage of spent nuclear fuel at SONGS.

The Nuclear Waste Policy Act of 1982 made the DOE responsible for accepting, transporting, and disposing of spent nuclear fuel. However, it is uncertain when the DOE will begin accepting spent nuclear fuel from SONGS. This delay will lead to increased costs for spent fuel storage. SDG&E will continue to support Edison in its pursuit of claims on behalf of the SONGS co-owners against the DOE for its failure to timely accept the spent nuclear fuel. However, it is unclear whether Edison will enter into a new settlement with the DOE or pursue litigation claims for spent fuel management costs incurred on or after January 1, 2017.

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 owners, including SDG&E, also maintain nuclear property damage insurance at $1.5 billion, with a $500 million property damage sublimit on the ISFSI, which exceeds the minimum federal requirements of $1.06 billion. This insurance coverage is provided through NEIL. The NEIL policies have specific exclusions and limitations that can result in reduced or eliminated 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 $10.4 million of retrospective premiums based on overall member claims.

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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 applicable insurance coverage and could materially adversely affect our business, cash flows, results of operations, financial condition and prospects. Unless otherwise indicated, we are unable to estimate reasonably possible losses in excess of any amounts accrued.

At March 31, 2019, loss contingency accruals for legal matters, including associated legal fees, that are probable and estimable were $104 million for Sempra Energy Consolidated, including $54 million for SoCalGas. Amounts for Sempra Energy and SoCalGas include $53 million for matters related to the Aliso Canyon natural gas storage facility gas leak, which we discuss below.

SDG&E

2007 Wildfire Litigation and Net Cost Recovery Status

SDG&E has resolved all civil litigation associated with three wildfires that occurred in October 2007.

As a result of a CPUC decision denying SDG&E’s request to recover wildfire costs, SDG&E wrote off the wildfire regulatory asset, resulting in a charge of $351 million ($208 million after-tax) in the third quarter of 2017. SDG&E continues to vigorously pursue recovery of these costs, which were incurred through settling claims brought under the doctrine of inverse condemnation. SDG&E applied to the CPUC for rehearing of its decision on January 2, 2018. On July 12, 2018, the CPUC adopted a decision denying the rehearing requests filed by SDG&E and other parties. On August 3, 2018, SDG&E filed an appeal with the California Court of Appeal seeking to reverse the CPUC’s decision. The filing also asked the court to direct the CPUC to award SDG&E recovery for payments made to settle inverse condemnation claims and limit any reasonableness review to the amounts of those payments. On November 13, 2018, the California Court of Appeal denied SDG&E’s petition. On November 26, 2018, SDG&E filed an appeal with the California Supreme Court seeking to reverse the decisions of the CPUC and the California Court of Appeal. In January 2019, the California Supreme Court denied SDG&E’s petition. On April 30, 2019, SDG&E filed an appeal with the U.S. Supreme Court seeking to reverse the CPUC’s decision.

SoCalGas

Aliso Canyon Natural Gas Storage Facility Gas Leak

On October 23, 2015, SoCalGas discovered a leak at one of its injection-and-withdrawal wells, SS25, at its Aliso Canyon natural gas storage facility, located in the northern part of the San Fernando Valley in Los Angeles County. The Aliso Canyon natural gas storage facility has been operated by SoCalGas since 1972. SS25 is one of more than 100 injection-and-withdrawal wells at the storage facility. SoCalGas worked closely with several of the world’s leading experts to stop the Leak, and on February 18, 2016, DOGGR confirmed that the well was permanently sealed. SoCalGas calculated that approximately 4.62 Bcf of natural gas was released from the Aliso Canyon natural gas storage facility as a result of the Leak.

As discussed in “Cost Estimates and Accounting Impact” below, SoCalGas incurred significant costs for temporary relocation, to control the well and to stop the Leak, as well as to purchase natural gas to replace that lost through the Leak. As discussed in “Local Community Mitigation Efforts” below, during the Leak and in the months following the sealing of the well, SoCalGas provided support to nearby residents who wished to temporarily relocate as a result of the Leak. These programs ended in July 2016.

SoCalGas has additionally incurred significant costs 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 an independent

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third party to conduct a root cause analysis to investigate the technical cause of the Leak; to respond to various government and agency investigations regarding the Leak, and to comply with increased regulation imposed as a result of the Leak. As further described below in “Civil and Criminal Litigation,” “Regulatory Proceedings” and “Governmental Investigations and Orders and Additional Regulation,” these activities are ongoing and SoCalGas anticipates that it will incur additional such costs, which may also be significant.

Local Community Mitigation Efforts. Pursuant to a directive by the DPH and orders by the LA Superior Court, SoCalGas provided temporary relocation support to residents in the nearby community who requested it. Following the permanent sealing of the well, the DPH conducted testing in certain homes in the Porter Ranch community and concluded that indoor conditions did not present a long-term health risk and that it was safe for those residents to return home.

In May 2016, the DPH also issued a directive that SoCalGas additionally professionally clean the homes of all residents located within the Porter Ranch Neighborhood Council boundary, or who participated in the relocation program, or who are located within a five-mile radius of the Aliso Canyon natural gas storage facility and experienced symptoms from the Leak (the Directive). SoCalGas disputed the Directive as invalid and unenforceable, and filed a petition for writ of mandate to set aside the Directive. The Directive was settled and SoCalGas’ petition was dismissed pursuant to the Government Plaintiffs Settlement that we discuss below in “Civil and Criminal Litigation.”

The costs incurred to remediate and stop the Leak and to mitigate local community impacts have been significant and may increase, and we may be subject to potentially significant damages, restitution, and civil, administrative and criminal fines, penalties and other costs. If any of these costs are not covered by insurance (including any costs in excess of applicable policy limits), if there are significant 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 could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

Civil and Criminal Litigation. As of May 2, 2019, 394 lawsuits, including approximately 48,500 plaintiffs, are pending against SoCalGas, some of which have also named Sempra Energy. All these cases, other than a matter brought by the Los Angeles County District Attorney and the federal securities class action discussed below, are coordinated before a single court in the LA Superior Court for pretrial management (the Coordination Proceeding).

Pursuant to the Coordination Proceeding, in November 2017, the individuals and business entities asserting tort and Proposition 65 claims filed a Third Amended Consolidated Master Case Complaint for Individual Actions, through which their separate lawsuits will be 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, with certain causes also naming Sempra Energy. 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 (including penalties associated with Proposition 65 claims alleging violation of requirements for warning about certain chemical exposures), and attorneys’ fees.

In January 2017, pursuant to the Coordination Proceeding, two consolidated class action complaints were filed against SoCalGas and Sempra Energy, 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). Both complaints assert claims for strict liability for ultra-hazardous activities, negligence and violation of the California Unfair Competition Law. The Property Class Action also asserts claims for negligence per se, trespass, permanent and continuing public and private nuisance, and inverse condemnation. The Business Class Action also asserts a claim for negligent interference with prospective economic advantage. Both complaints seek compensatory, statutory and punitive damages, injunctive relief and attorneys’ fees. In December 2017, the California Court of Appeal, Second Appellate District ruled that the purely economic damages alleged in the Business Class Action are not recoverable under the law. In February 2018, the California Supreme Court granted a petition filed by the plaintiffs to review that ruling, and oral argument on the appeal was heard in March 2019.

Complaints by property developers were filed in 2017 and 2018 against SoCalGas and Sempra Energy 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. These claims are also joined in the Coordination Proceeding.

In addition to the lawsuits described above, in October 2018 and January 2019, complaints were filed on behalf of 51 plaintiffs who are firefighters stationed near the Aliso Canyon natural gas storage facility and allege they were injured by exposure to chemicals released during the Leak. The complaints against SoCalGas and Sempra Energy assert causes of actions for negligence,

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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 attorney’s fees. These claims are also joined in the Coordination Proceeding.

In addition, a federal securities class action alleging violation of the federal securities laws has been filed against Sempra Energy and certain of its officers and certain of its directors in the SDCA. In March 2018, the court dismissed the action with prejudice, and in December 2018 the court denied the plaintiffs’ request for reconsideration of that order. The plaintiffs have filed a notice of appeal of the dismissal.

Five shareholder derivative actions are also pending in the Coordination Proceeding alleging breach of fiduciary duties against certain officers and certain directors of Sempra Energy and/or SoCalGas, four of which were joined in a Consolidated Shareholder Derivative Complaint in August 2017.

Three actions by public entities were filed in the Coordination Proceeding, including complaints by the County of Los Angeles, on behalf of itself and the people of the State of California, the California Attorney General, acting in an independent capacity and on behalf of the people of the State of California and the CARB, and the Los Angeles City Attorney alleging public nuisance, unfair competition, and violations of California Health and Safety Code provisions regarding discharge of contaminants, among other things, which sought injunctive relief, abatement, civil penalties and damages.

Additionally, the County of Los Angeles filed a petition against DOGGR and its State Oil and Gas Supervisor and the CPUC and its Executive Director, as to which SoCalGas is the real party in interest, alleging that they failed to comply with the provisions of SB 380 in authorizing the resumption of injections of natural gas at the Aliso Canyon natural gas storage facility, and seeking a writ of mandate requiring DOGGR and the State Oil and Gas Supervisor to comply with SB 380 and CEQA, as well as declaratory and injunctive relief against any authorization to inject natural gas and attorneys’ fees.

In August 2018, SoCalGas entered into a settlement agreement with the Los Angeles City Attorney’s Office, the County of Los Angeles, the California Office of the Attorney General and CARB (collectively, the Government Plaintiffs) to settle the three public entity actions and the Directive for payments and funding for environmental projects totaling $120 million, including $21 million in civil penalties (the Government Plaintiffs Settlement). Under the settlement agreement, SoCalGas also agreed to continue its fence-line methane monitoring program, establish a safety committee and hire an independent ombudsman to monitor and report on the safety at the facility. This settlement also fully resolves SoCalGas’ commitment to mitigate the actual natural gas released during the Leak and fulfills the requirements of the Governor’s Order, described below, for SoCalGas to pay for a mitigation program developed by CARB. The Government Plaintiffs Settlement was approved by the LA Superior Court in February 2019.

Separately, in February 2016, the Los Angeles County District Attorney’s Office filed a misdemeanor criminal complaint against SoCalGas seeking penalties and other remedies for alleged failure to provide timely notice of the Leak pursuant to California Health and Safety Code section 25510(a), Los Angeles County Code section 12.56.030, and Title 19 California Code of Regulations section 2703(a), and for allegedly violating California Health and Safety Code section 41700 prohibiting discharge of air contaminants that cause annoyance to the public. Pursuant to a settlement agreement with the Los Angeles County District Attorney’s Office, SoCalGas agreed to plead no contest to the notice charge under Health and Safety Code section 25510(a) and agreed to pay the maximum fine of $75,000, penalty assessments of approximately $233,500, and operational commitments estimated to cost approximately $6 million, reimbursements and assessments in exchange for the Los Angeles County District Attorney’s Office moving to dismiss the remaining counts at sentencing and settling the complaint (the District Attorney Settlement). In November 2016, SoCalGas completed the commitments and obligations under the District Attorney Settlement, and on November 29, 2016, the LA Superior Court approved the settlement and entered judgment on the notice charge. Certain individuals who object to the settlement have filed an appeal of the judgment, contending they should be granted restitution.

The costs of defending against these civil and criminal lawsuits, and any damages, restitution, and civil, administrative and criminal fines, penalties and other costs, if awarded or imposed, as well as the costs of mitigating the actual natural gas released, could be significant. If any of these costs are not covered by insurance (including any costs in excess of applicable policy limits), if there are significant 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 could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

Regulatory Proceedings. In February 2017, the CPUC opened a proceeding pursuant to SB 380 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. The CPUC indicated it intends to conduct the proceeding in two phases, with Phase 1 undertaking a comprehensive effort to develop the appropriate analyses and scenarios to evaluate the impact of reducing or eliminating the use

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of the Aliso Canyon natural gas storage facility and Phase 2 using those analyses and scenarios to evaluate the impacts of reducing or eliminating the use of the Aliso Canyon natural gas storage facility.

The order establishing the scope of the proceeding expressly excludes issues with respect to air quality, public health, causation, culpability or cost responsibility regarding the Leak. In January 2019, the CPUC concluded Phase 1 of the proceeding by establishing 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 will evaluate 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. The CPUC has indicated that it expects to issue its report in 2020.

Governmental Investigations and Orders and Additional Regulation. Various governmental agencies, including DOE, DOGGR, DPH, SCAQMD, CARB, Los Angeles Regional Water Quality Control Board, California Division of Occupational Safety and Health, CPUC, PHMSA, EPA, Los Angeles County District Attorney’s Office and California Attorney General’s Office, have investigated or are investigating this incident. In January 2016, DOGGR and the CPUC selected Blade Energy Partners to conduct, under their supervision, an independent analysis of the technical root cause of the Leak, to be funded by SoCalGas. The independent root cause analysis is ongoing, and its timing is under the control of Blade Energy Partners, DOGGR and the CPUC. We expect the report will be issued in the second quarter of 2019.

In January 2016, the Governor of the State of California proclaimed a state of emergency in Los Angeles County due to the Leak. The proclamation ordered various actions with respect to the Leak, including: (1) applicable agencies must convene an independent panel of scientific and medical experts to review public health concerns stemming from the Leak and evaluate whether additional measures are needed to protect public health; (2) the CPUC must ensure that SoCalGas covers costs related to the Leak and its response while protecting ratepayers; (3) CARB must develop a program, to be funded by SoCalGas, to fully mitigate the Leak’s emissions of methane; and (4) DOGGR, CPUC, CARB and the CEC must submit to the Governor’s Office a report that assesses the long-term viability of natural gas storage facilities in California.

In March 2016, CARB issued its “Aliso Canyon Methane Leak Climate Impacts Mitigation Program” recommending a program to fully mitigate the emissions from the Leak. In October 2016, CARB issued a report concluding that SoCalGas should mitigate 109,000 metric tons of methane to fully mitigate the GHG impacts of the Leak. The Government Plaintiffs Settlement described above satisfies the mitigation requirement of the Governor’s emergency proclamation.

Cost Estimates and Accounting Impact. At March 31, 2019, SoCalGas estimates its costs related to the Leak are $1,071 million (the cost estimate), which includes $1,043 million of costs recovered or probable of recovery from insurance. Approximately 53 percent of the cost estimate is for the temporary relocation program (including cleaning costs and certain labor costs). The remaining portion of the cost estimate includes costs incurred to defend litigation, the costs of the government-ordered response to the Leak including the costs for an independent third party to conduct a root cause analysis, efforts to control the well, to mitigate the actual natural gas released, the cost of replacing the lost gas, and other costs, as well as the estimated costs to settle certain actions. SoCalGas adjusts the cost estimate as additional information becomes available. A substantial portion of the cost estimate has been paid, and $60 million is accrued as Reserve for Aliso Canyon Costs as of March 31, 2019 on SoCalGas’ and Sempra Energy’s Condensed Consolidated Balance Sheets.

As of March 31, 2019, we recorded the expected recovery of the cost estimate related to the Leak of $477 million as Insurance Receivable for Aliso Canyon Costs on SoCalGas’ and Sempra Energy’s Condensed Consolidated Balance Sheets. This amount is net of insurance retentions and $566 million of insurance proceeds we received through March 31, 2019. The Insurance Receivable for Aliso Canyon Costs and insurance proceeds received to date relate to portions of the cost estimate described above, including temporary relocation and associated processing costs, control-of-well expenses, costs of the government-ordered response for an independent third party to conduct a root cause analysis, the costs to settle certain claims as described above, the estimated costs to perform obligations pursuant to settlement of some of those claims, legal costs and lost gas. If we were to conclude that this receivable or a portion of it is no longer probable of recovery from insurers, some or all of this receivable would be charged against earnings, which could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

As described in “Civil and Criminal Litigation” above, the actions seek compensatory, statutory and punitive damages, restitution, and civil, administrative and criminal fines, penalties and other costs, which, except for the amounts paid or estimated to settle certain actions as described above, are not included in the cost estimate as it is not possible at this time to predict the outcome of these actions or reasonably estimate the amount of damages, restitution or civil, administrative or criminal fines, penalties or other costs that may be imposed. The recorded amounts above also do not include future legal costs necessary to defend litigation, and other potential costs that we currently do not anticipate incurring or that we cannot reasonably estimate. Furthermore, the cost estimate does not include certain other costs incurred by Sempra Energy associated with defending against shareholder derivative lawsuits.

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Insurance. Excluding directors’ and officers’ liability insurance, we have at least four kinds of insurance policies that together we estimate provide between $1.2 billion to $1.4 billion in insurance coverage, depending on the nature of the claims. We cannot predict all of the potential categories of costs or the total amount of costs that we may incur as a result of the Leak. Subject to various policy limits, exclusions and conditions, based on what we know as of the filing date of this report, we believe that our insurance policies collectively should cover the following categories of costs: costs incurred for temporary relocation and associated processing costs (including cleaning costs and certain labor costs), costs to address the Leak and stop or reduce emissions, costs of the government-ordered response to the Leak including the costs for an independent third party to conduct a root cause analysis, the value of lost gas, costs incurred to mitigate the actual natural gas released, costs associated with litigation and claims by nearby residents and businesses, any costs to clean additional homes pursuant to the Directive, and, in some circumstances depending on their nature and manner of assessment, fines and penalties. We have been communicating with our insurance carriers and, as discussed above, we have received insurance payments for portions of the costs described above, including temporary relocation and associated processing costs, control-of-well expenses, legal costs and lost gas. We intend to pursue the full extent of our insurance coverage for the costs we have incurred or may incur. There can be no assurance that we will be successful in obtaining additional insurance recovery for these costs, and to the extent we are not successful in obtaining coverage or these costs exceed the amount of our coverage, such costs could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

At March 31, 2019, SoCalGas’ estimate of costs related to the Leak of $1,071 million include $1,043 million of costs recovered or probable of recovery from insurance. This estimate may rise significantly as more information becomes available. Costs not included in the $1,071 million cost estimate could be material. If any costs are not covered by insurance (including any costs in excess of applicable policy limits), if there are significant 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 could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

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 heating needs in the winter. The Aliso Canyon natural gas storage facility, with a capacity of 86 Bcf (representing 63 percent of SoCalGas’ natural gas storage capacity), is the largest SoCalGas storage facility and an important element of SoCalGas’ delivery system. As a result of the Leak, SoCalGas suspended injection of natural gas into the Aliso Canyon natural gas storage facility beginning in October 2015, and following a comprehensive safety review and authorization by DOGGR and the CPUC’s Executive Director, resumed limited injection operations in July 2017.

During the suspension period, SoCalGas advised the California ISO, CEC, CPUC and PHMSA of its concerns that the inability to inject natural gas into the Aliso Canyon natural gas storage facility posed a risk to energy reliability in Southern California. Following the resumption of injection operations, 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 to help ensure safety and reliability for the region and just and reasonable rates in California, the most recent of which, issued in July 2018, directed SoCalGas to maintain up to 34 Bcf of working gas. Limited withdrawals of natural gas from the facility were made in 2018 and 2019 to augment natural gas supplies during critical demand periods.

If the Aliso Canyon natural gas storage facility were to be permanently closed, or if future cash flows were otherwise insufficient to recover its carrying value, it could result in an impairment of the facility and significantly higher than expected operating costs and/or additional capital expenditures, and natural gas reliability and electric generation could be jeopardized. At March 31, 2019, the Aliso Canyon natural gas storage facility had a net book value of $741 million. Any significant impairment of this asset could have a material adverse effect on SoCalGas’ and Sempra Energy’s results of operations for the period in which it is recorded. Higher operating costs and additional capital expenditures incurred by SoCalGas may not be recoverable in customer rates, and could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

Sempra Mexico

Property Disputes and Permit Challenges

Energía Costa Azul. IEnova has been engaged in a long-running land dispute relating to property adjacent to its ECA LNG terminal near Ensenada, Mexico. A claimant to the adjacent property filed complaints in the federal Agrarian Court challenging the refusal of SEDATU in 2006 to issue a title to him for the disputed property. In November 2013, the federal Agrarian Court ordered that SEDATU issue the requested title and cause it to be registered. Both SEDATU and IEnova challenged the ruling, due to lack of notification of the underlying process. Both challenges are pending to be resolved by a Federal Court in Mexico. IEnova expects additional proceedings regarding the claims.

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Several administrative challenges are pending in Mexico before the Mexican environmental protection agency and the Federal Tax and Administrative Courts seeking revocation of the environmental impact authorization issued to ECA 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.

Additionally, in August 2018, a claimant filed a challenge in the federal district court in Ensenada, Baja California in relation to the environmental and social impact permits issued to ECA in September 2017 and December 2017, respectively, to allow natural gas liquefaction activities at the ECA LNG terminal. The court issued a provisional injunction on September 28, 2018 and maintained that provisional injunction at an April 11, 2019 hearing. The provisional injunction has uncertain application and requires clarification by the court, which is being pursued through additional proceedings that are pending before the court. In December 2018, the relevant Mexican regulators approved modifications to the environmental permit that facilitate the development of the proposed natural gas liquefaction facility at the ECA LNG terminal in two phases.

Cases involving two parcels of real property have been filed against ECA. In one case, filed in the federal Agrarian Court in 2006, the plaintiffs seek to annul the recorded property title for a parcel on which the ECA LNG terminal is situated and to obtain possession of a different parcel that allegedly sits in the same place. Another civil complaint filed in the state court was served in April 2012 seeking to invalidate the contract by which ECA purchased another of the terminal parcels, on the grounds the purchase price was unfair; the plaintiff filed a second complaint in 2013 in the federal Agrarian Court seeking an order that SEDATU issue title to her. In January 2016, the federal Agrarian Court ruled against the plaintiff, and the plaintiff appealed the ruling. In May 2018, the state court dismissed the civil complaint, and the plaintiff has appealed. IEnova expects further proceedings on these two matters.

An unfavorable final decision on these property disputes or permit challenges could materially and adversely affect our planned natural gas liquefaction projects currently in development at ECA.

Guaymas-El Oro Segment of the Sonora Pipeline. 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, an appellate court ruled that the scope of the 2016 suspension order encompassed the wider Yaqui territory. The legal challenge remains pending. IEnova has subsequently reported damage to the Guaymas-El Oro segment of the Sonora pipeline in the Yaqui territory that has made that section inoperable since August 23, 2017 and, as a result, declared a force majeure event. IEnova will continue to exercise its rights under the contract, which includes seeking continued force majeure payments for the two-year period such force majeure payments are required to be made, which ends on August 22, 2019, and just consideration following the expiration of the two-year period in which force majeure payments are made. The Sasabe-Puerto Libertad-Guaymas segment of the Sonora pipeline remains in full operation.

Other Litigation

Sempra Energy holds an NCI in RBS Sempra Commodities, a limited liability partnership in the process of being liquidated. NatWest Markets plc, formerly RBS, 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 has since been sold to JP Morgan 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. After paying the assessment, RBS filed a Notice of Appeal of the assessment with the First-Tier Tribunal. Trial on the matter has not been scheduled.

During 2015, liquidators filed a claim in the High Court of Justice against RBS and Mercuria Energy Europe Trading Limited (the Defendants) on behalf of ten 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, at the close of which

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the Liquidating Companies asserted that the Defendants were liable to the Liquidating Companies in the amount of £71.5 million (approximately $93 million in U.S. dollars at March 31, 2019) for dishonest assistance and, to the extent that claim is unsuccessful, to the liquidators in the same amount under the U.K. Insolvency Act of 1986. If the High Court of Justice finds the Defendants liable, it will determine the amount. JP Morgan has notified us that Mercuria Energy Group, Ltd. has sought indemnity for the claim, and JP Morgan has in turn sought indemnity from Sempra Energy and RBS.

While the ultimate outcome remains uncertain, we continue to evaluate the likelihood of recovery of our investment. Accordingly, in the third quarter of 2018, we fully impaired our remaining $65 million equity method investment in RBS Sempra Commodities.

Certain EFH subsidiaries that we acquired as part of the Merger are defendants in personal injury lawsuits brought in state courts throughout the U.S. As of May 2, 2019, 114 such lawsuits are pending and 1,685 such lawsuits have been filed but not 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. We anticipate additional lawsuits will be filed. None of these claims or lawsuits were discharged in the EFH bankruptcy proceeding.

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

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 combine lease components and nonlease components for all existing classes of underlying assets as a single lease component, 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, if the timing and pattern of transfer of the lease components and nonlease components are the same, and the lease component would be classified as an operating lease if accounted for separately, we combine the lease components and nonlease components.

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.

Some of our leases include options to extend the lease terms for up to 25 years, while others include options to terminate the leases within one year. Our lease liabilities and ROU assets are based on lease terms that may include such options to extend or terminate the lease when it is reasonably certain that we will exercise that option.

Certain of our contracts are short-term leases, which have a lease term of 12 months or less at lease commencement. We do not recognize a lease liability or ROU asset arising from short-term leases for all existing classes of underlying assets. In such cases, we recognize short-term lease costs on a straight-line basis over the lease term. Our short-term lease costs for the period reasonably reflect our short-term lease commitments.

Certain of our leases contain escalation clauses requiring annual increases in rent ranging from 1 percent to 5 percent or based on the Consumer Price Index. The rentals payable under these leases may increase by a fixed amount each year or by a percentage of a base year. Variable lease payments that are based on an index or rate are included in the initial measurement of our lease liability and ROU asset based on the index or rate at lease commencement and are not remeasured because of changes to the index or rate. Rather, changes to the index or rate are treated as variable lease payments and recognized in the period in which the obligation for those payments is incurred.

Similarly, PPAs for the purchase of renewable energy at SDG&E require lease payments based on a stated rate per MWh produced by the facilities, and we are required to purchase substantially all the output from the facilities. SDG&E is required to pay additional amounts for capacity charges and actual purchases of energy that exceed the minimum energy commitments. Under these contracts, we do not recognize a lease liability or ROU asset for leases for which there are no fixed lease payments. Rather, these variable lease payments are recognized separately as variable lease costs.

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As of the lease commencement date, we recognize a lease liability for our obligation to make future lease payments, which we initially measure at present value using our incremental borrowing rate at the date of lease commencement, unless the rate implicit in the lease is readily determinable. We determine our incremental borrowing rate based on the rate of interest that we would have to pay to borrow, on a collateralized basis over a similar term, an amount equal to the lease payments in a similar economic environment. We also record an ROU asset for our right to use the underlying asset, which is initially equal to the lease liability and adjusted for lease payments made at or before lease commencement, lease incentives, and any initial direct costs. Like other long-lived assets, we test ROU assets for recoverability whenever events or changes in circumstances have occurred that may affect the recoverability or the estimated useful lives of the ROU assets.

For our operating leases, our non-regulated entities recognize a single lease cost on a straight-line basis over the lease term in operating expenses. The California Utilities recognize this single lease cost on a basis that is consistent with the recovery of such costs in accordance with U.S. GAAP governing rate-regulated operations.

For our finance leases, the interest expense on the lease liability and amortization of the ROU asset are accounted for separately. Our non-regulated entities use the effective interest rate method to account for the imputed interest on the lease liability and amortize the ROU asset on a straight-line basis over the lease term. The California Utilities recognize amortization of the ROU asset on a basis that is consistent with the recovery of such costs in accordance with U.S. GAAP governing rate-regulated operations.

Our leases do not contain any material residual value guarantees, restrictions or covenants.

Classification of ROU assets and lease liabilities and the weighted-average remaining lease term and discount rate associated with operating and finance leases are summarized in the table below.

LESSEE INFORMATION ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	March 31, 2019
	Sempra Energy Consolidated			SDG&E			SoCalGas
Right-of-use assets:
Operating leases:
Right-of-use assets	$	612		$	135		$	110
Finance leases:
Property, plant and equipment	1,322			1,315			7
Accumulated depreciation	(45		)	(43		)	(2		)
Property, plant and equipment, net	1,277			1,272			5
Total right-of-use assets	$	1,889		$	1,407		$	115
Lease liabilities:
Operating leases:
Other current liabilities	$	52		$	24		$	22
Deferred credits and other	455			110			88
	507			134			110
Finance leases:
Current portion of long-term debt and finance leases	21			18			3
Long-term debt and finance leases	1,256			1,254			2
	1,277			1,272			5
Total lease liabilities	$	1,784		$	1,406		$	115
Weighted-average remaining lease term (in years):
Operating leases	14			7			6
Finance leases	20			20			3
Weighted-average discount rate:
Operating leases	5.87		%	3.69		%	3.76		%
Finance leases	14.91		%	14.92		%	3.94		%

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The components of lease costs were as follows:

LESSEE INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS(1)
(Dollars in millions)
	Three months ended March 31, 2019
	Sempra Energy Consolidated		SDG&E		SoCalGas
Operating lease costs	$	24	$	8	$	7
Finance lease costs:
Amortization of ROU assets	5		4		1
Interest on lease liabilities	47		47		—
Total finance lease costs	52		51		1
Short-term lease costs(2)	1		—		—
Variable lease costs(2)	92		90		2
Total lease costs	$	169	$	149	$	10

⁽¹⁾  Includes costs capitalized in PP&E.

⁽²⁾  Short-term leases with variable lease costs are recorded and presented as variable lease costs.

Cash paid for amounts included in the measurement of lease liabilities was as follows:

LESSEE INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in millions)
	Three months ended March 31, 2019
	Sempra Energy Consolidated		SDG&E		SoCalGas
Operating activities:
Cash paid for operating leases	$	39	$	8	$	7
Cash paid for finance leases	43		43		—
Financing activities:
Cash paid for finance leases	5		4		1
Increase in operating lease obligations for right-of-use assets	552		142		117
Increase in finance lease obligations for investment in PP&E	7		4		3

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The table below presents the maturity analysis of our lease liabilities and reconciliation to the present value of lease liabilities:

LESSEE MATURITY ANALYSIS OF LIABILITIES
(Dollars in millions)
	March 31, 2019
	Sempra Energy Consolidated						SDG&E						SoCalGas
	Operating leases			Finance leases			Operating leases			Finance leases			Operating leases			Finance leases
2019 (excluding first three months of 2019)	$	60		$	146		$	24		$	143		$	20		$	3
2020	69			190			25			189			22			1
2021	65			188			24			188			20			—
2022	59			188			21			188			17			—
2023	50			188			17			188			13			—
Thereafter	479			2,806			42			2,805			31			1
Total undiscounted lease payments	782			3,706			153			3,701			123			5
Less: imputed interest	(275		)	(2,429		)	(19		)	(2,429		)	(13		)	—
Total lease liabilities	507			1,277			134			1,272			110			5
Less: current lease liabilities	(52		)	(21		)	(24		)	(18		)	(22		)	(3		)
Long-term lease liabilities	$	455		$	1,256		$	110		$	1,254		$	88		$	2

Leases that Have Not Yet Commenced

SDG&E has PPAs for three battery storage facilities that are currently under construction. When construction is complete and delivery of contracted power commences, which is scheduled to occur in 2019 through 2022, we will account for the PPAs as finance leases. The future minimum lease payments are expected to be $1 million per year in 2020 through 2023 and $18 million thereafter. These PPA’s expire at various dates from 2031 through 2039.

SDG&E and SoCalGas have lease agreements for future acquisitions of fleet vehicles with an aggregate maximum lease limit of $194 million. SDG&E and SoCalGas have utilized $52 million and $75 million, respectively, as of March 31, 2019.

Lease Disclosures Under Previous U.S. GAAP

The table below presents the future minimum lease payments under previous U.S. GAAP:

FUTURE MINIMUM LEASE PAYMENTS
(Dollars in millions)
	December 31, 2018
	Sempra Energy Consolidated							SDG&E					SoCalGas
	Build-to-suit lease		Operating leases		Capital leases			Operating leases		Capital leases			Operating leases		Capital leases
2019	$	10	$	77	$	215		$	23	$	212		$	26	$	3
2020	11		55		210			22		210			22		—
2021	11		53		211			22		211			21		—
2022	11		50		211			21		211			20		—
2023	11		42		211			17		211			16		—
Thereafter	217		253		3,196			48		3,196			28		—
Total undiscounted lease payments	$	271	$	530	4,254			$	153	4,251			$	133	3
Less: estimated executory costs					(480		)			(480		)			—
Less: imputed interest					(2,483		)			(2,483		)			—
Total future minimum lease payments					$	1,291				$	1,288				$	3

Lessor Accounting

Sempra Mexico is a lessor for certain of its natural gas and ethane pipelines, compressor stations and LPG storage facilities, and land and office space. These operating leases expire at various dates from 2026 through 2039.

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Sempra Mexico expects to continue to derive value from the underlying assets associated with its pipelines following the end of their respective lease terms based on the expected remaining useful life, expected market conditions and our plans to re-market and re-contract the underlying assets.

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 from one period to the next.

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

LESSOR INFORMATION – SEMPRA ENERGY
(Dollars in millions)
	March 31, 2019
Assets subject to operating leases:
Assets held for sale	$	148
Property, plant and equipment(1)	$	1,026
Accumulated depreciation	(151		)
Property, plant and equipment, net	$	875
Maturity analysis of operating lease payments:
2019 (excluding first three months of 2019)	$	151
2020	200
2021	200
2022	200
2023	200
Thereafter	2,619
Total undiscounted cash flows	$	3,570

⁽¹⁾   Included in Machinery and Equipment — Pipelines and Storage within the major functional categories of PP&E.

LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA ENERGY
(Dollars in millions)
	Three months ended March 31,
	2019		2018
Minimum lease payments	$	50	$	49
Variable lease payments	4		13
Total revenues from operating leases	$	54	$	62
Depreciation expense	$	9	$	17

OTHER CONTRACTUAL COMMITMENTS

We discuss below significant changes in the first three months of 2019 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 terminal. The commitment amount is calculated using a predetermined formula based on estimated forward prices of the index applicable from 2019 to 2029. At March 31, 2019, we expect the commitment amount to decrease by $96 million in 2019 and increase by $19 million in 2020, $8 million in 2021, $3 million in 2022, $2 million in 2023 and $52 million thereafter (through contract termination in 2029) compared to December 31, 2018, reflecting changes in estimated forward prices since December 31, 2018 and actual transactions for the first three months of 2019. 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. 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

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Sempra LNG. 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.

CONCENTRATION OF CREDIT RISK

We maintain credit policies and systems designed to manage our overall credit risk. These policies include an evaluation of potential counterparties’ financial condition and an assignment of credit limits. These credit limits are established based on risk and return considerations under terms customarily available in the industry. We grant credit to utility customers and counterparties, substantially all of whom are located in our service territory, which covers most of Southern California and a portion of central California for SoCalGas, and all of San Diego County and an adjacent portion of Orange County for SDG&E. Sempra Mexico’s Ecogas also grants credit to its utility customers and counterparties in Mexico.

Projects and businesses owned or partially owned by Sempra Energy place significant reliance on the ability of their suppliers, customers and partners to perform on long-term agreements and on our ability to enforce contract terms in the event of nonperformance. We consider many factors, including the negotiation of supplier and customer agreements, when we evaluate and approve development projects and investment opportunities.

NOTE 12. SEGMENT INFORMATION

At March 31, 2019, we had six 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 Utility holds our investment in Oncor Holdings, which owns an 80.25-percent interest in Oncor, a regulated electric transmission and distribution utility serving customers in the north-central, eastern and western parts of Texas.

▪ 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 Renewables develops, owns and operates, or holds interests in, wind power generation facilities serving wholesale electricity markets in the U.S. In December 2018, Sempra Renewables completed the sale of all its operating solar assets, solar and battery storage development projects and one wind generation facility. In April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments. Upon completion of this sale, remaining nominal business activities at Sempra Renewables were subsumed into Parent and other and the Sempra Renewables segment ceased to exist.

▪ Sempra LNG (previously known as Sempra LNG & Midstream) develops, owns and operates, or holds interests in, terminals for the import and export of LNG and sale of natural gas, natural gas pipelines and marketing operations, all within the U.S. and Mexico. In February 2019, we completed the sale of our natural gas storage assets at Mississippi Hub and Bay Gas.

As we discuss in Note 5, the financial information related to our businesses that constituted the Sempra South American Utilities segment has been reclassified to discontinued operations for all periods presented. The information in the tables below excludes amounts from discontinued operations unless otherwise noted.

We evaluate each segment’s performance based on its contribution to Sempra Energy’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. The California Utilities’ operations are based on rates set by the CPUC and 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 March 31,
	2019			2018
REVENUES
SDG&E	$	1,145		$	1,055
SoCalGas	1,361			1,126
Sempra Mexico	383			308
Sempra Renewables	7			25
Sempra LNG	141			104
Adjustments and eliminations	—			(1		)
Intersegment revenues(1)	(139		)	(81		)
Total	$	2,898		$	2,536
INTEREST EXPENSE
SDG&E	$	103		$	52
SoCalGas	34			27
Sempra Mexico	30			30
Sempra Renewables	3			5
Sempra LNG	4			8
All other	109			112
Intercompany eliminations	(23		)	(28		)
Total	$	260		$	206
INTEREST INCOME
SDG&E	$	1		$	1
Sempra Mexico	19			15
Sempra Renewables	10			2
Sempra LNG	14			13
All other	1			16
Intercompany eliminations	(24		)	(18		)
Total	$	21		$	29
DEPRECIATION AND AMORTIZATION
SDG&E	$	186		$	166
SoCalGas	147			135
Sempra Mexico	44			43
Sempra Renewables	—			13
Sempra LNG	2			11
All other	4			4
Total	$	383		$	372
INCOME TAX EXPENSE (BENEFIT)
SDG&E	$	5		$	56
SoCalGas	19			59
Sempra Mexico	72			155
Sempra Renewables	(10		)	(7		)
Sempra LNG	4			12
All other	(48		)	(33		)
Total	$	42		$	242
EQUITY EARNINGS (LOSSES)
Equity earnings before income tax:
Sempra Renewables	$	3		$	5
Sempra LNG	2			—
	5			5
Equity earnings (losses) net of income tax:
Sempra Texas Utility	94			15
Sempra Mexico	2			(41		)
	96			(26		)
Total	$	101		$	(21	)

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SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended March 31,
	2019			2018
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E	$	176		$	170
SoCalGas	264			225
Sempra Texas Utility	94			15
Sempra Mexico	57			20
Sempra Renewables	13			21
Sempra LNG	5			(16		)
Discontinued operations	(51		)	21
All other	(117		)	(109		)
Total	$	441		$	347
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E	$	356		$	475
SoCalGas	324			403
Sempra Mexico	85			59
Sempra Renewables	—			31
Sempra LNG	18			6
All other	—			5
Total	$	783		$	979
	March 31, 2019			December 31, 2018
ASSETS
SDG&E	$	19,558		$	19,225
SoCalGas	15,904			15,389
Sempra Texas Utility	9,748			9,652
Sempra Mexico	9,382			9,165
Sempra Renewables	1,310			2,549
Sempra LNG	3,731			4,060
Discontinued operations	3,845			3,718
All other	1,135			1,070
Intersegment receivables	(2,995		)	(4,190		)
Total	$	61,618		$	60,638
EQUITY METHOD AND OTHER INVESTMENTS
Sempra Texas Utility	$	9,748		$	9,652
Sempra Mexico	737			747
Sempra Renewables	290			291
Sempra LNG	1,255			1,271
All other	8			11
Total	$	12,038		$	11,972

⁽¹⁾  Revenues for reportable segments include intersegment revenues of $1 million, $17 million, $28 million and $93 million for the three months ended March 31, 2019 and $1 million, $17 million, $29 million and $34 million for the three months ended March 31, 2018, 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 contained in this Form 10-Q, and the Consolidated Financial Statements and the Notes thereto, “Item 7. MD&A” and “Item 1A. Risk Factors” contained in the Annual Report.

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OVERVIEW

Sempra Energy is a Fortune 500 energy-services holding company. Our businesses, which consist of six separately managed reportable segments, invest in, develop and operate energy infrastructure, and provide electric and gas services to customers in North America.

On January 25, 2019, our board of directors approved a plan to sell our South American businesses, which were previously included in our Sempra South American Utilities segment. Our South American businesses and certain activities associated with those businesses have been reclassified to discontinued operations for all periods presented. Nominal activities that are not classified as discontinued operations have been subsumed into Parent and other. Our discussions below exclude discontinued operations, unless otherwise noted.

In the first quarter of 2019, our Sempra LNG & Midstream segment was renamed “Sempra LNG.” This segment name change had no impact on our historical position, results of operations, cash flow or segment results previously reported.

We provide additional information about discontinued operations in Note 5 of the Notes to Condensed Consolidated Financial Statements and about our reportable segments in Note 12 of the Notes to Condensed Consolidated Financial Statements herein and in “Item 1. Business” in the Annual Report.

This report includes information for the following separate registrants:

▪ Sempra Energy and its consolidated entities

▪ SDG&E and its consolidated VIE

▪ SoCalGas

References to “we,” “our” and “Sempra Energy Consolidated” are to Sempra Energy and its consolidated entities, collectively, unless otherwise indicated by the context. We refer to SDG&E and SoCalGas collectively as the California Utilities, which do not include our Texas utility or the utility in our Sempra Mexico segment. It also does not include utilities within our South American businesses that have been reclassified as discontinued operations. All references in this MD&A 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 Energy and its subsidiaries and VIEs;

▪ the Condensed Consolidated Financial Statements and related Notes of SDG&E and its VIE; and

▪ the Condensed Financial Statements and related Notes of SoCalGas.

RESULTS OF OPERATIONS

We discuss the following in Results of Operations:

▪ Overall results of our operations

▪ Segment results

▪ Adjusted earnings and adjusted EPS

▪ Significant changes in revenues, costs and earnings between periods

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

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OVERALL RESULTS OF OPERATIONS OF SEMPRA ENERGY

Our earnings increased by $94 million (27%) to $441 million in the three months ended March 31, 2019 compared to the prior year period, while diluted EPS increased by $0.26 per share (20%) to $1.59 per share. The change in EPS included a decrease of $0.11 attributable to an increase in the weighted-average common shares outstanding and dilutive common stock equivalents, primarily due to the common stock issuances in the third quarter of 2018. Our results and diluted EPS were impacted by variances discussed in “Segment Results” below and by the items included in the table “Sempra Energy Adjusted Earnings and Adjusted EPS,” also below.

SEGMENT RESULTS

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

SEMPRA ENERGY EARNINGS (LOSSES) BY SEGMENT
(Dollars in millions)
	Three months ended March 31,
	2019			2018
SDG&E	$	176		$	170
SoCalGas	264			225
Sempra Texas Utility	94			15
Sempra Mexico	57			20
Sempra Renewables	13			21
Sempra LNG	5			(16		)
Parent and other(1)	(117		)	(109		)
Discontinued operations	(51		)	21
Earnings attributable to common shares	$	441		$	347

⁽¹⁾  Includes after-tax interest expense ($79 million and $81 million for the three months ended March 31, 2019 and 2018, respectively), intercompany eliminations recorded in consolidation and certain corporate costs.

SDG&E

The increase in earnings of $6 million (4%) in the three months ended March 31, 2019 was primarily due to:

▪ $31 million income tax benefit from the release of a regulatory liability established in connection with 2017 tax reform for excess deferred income tax balances that the CPUC directed be allocated to shareholders in a January 2019 decision; and

▪ $9 million higher earnings from electric transmission operations; offset by

▪ $27 million lower CPUC base operating margin in 2019 due to the delay in the 2019 GRC decision while absorbing higher operating costs, including higher wildfire insurance premiums.

SoCalGas

The increase in earnings of $39 million (17%) in the three months ended March 31, 2019 was primarily due to:

▪ $35 million income tax benefit from the impact of the January 2019 CPUC decision allocating certain excess deferred income tax balances to shareholders; and

▪ $5 million higher regulatory awards; offset by

▪ $8 million in penalties related to the SoCalGas billing practices OII that we discuss in Note 4 of the Notes to Condensed Consolidated Financial Statements.

Sempra Texas Utility

The increase in earnings of $79 million for the three months ended March 31, 2019 represents higher equity earnings from our investment in Oncor Holdings, which we acquired in March 2018.

Sempra Mexico

The increase in earnings of $37 million in the three months ended March 31, 2019 was primarily due to:

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▪ $45 million favorable impact from foreign currency and inflation effects net of foreign currency derivatives effects, comprised of:

◦ in 2019, $25 million unfavorable foreign currency and inflation effects, offset by a $7 million gain from foreign currency derivatives, offset by

◦ in 2018, $95 million unfavorable foreign currency and inflation effects, offset by $32 million gain from foreign currency derivatives. We discuss these effects below in “Impact of Foreign Currency and Inflation Rates on Results of Operations;”

▪ $11 million higher capitalized financing costs, primarily from higher equity earnings in 2019 from AFUDC at the IMG joint venture; and

▪ $10 million improved operating results at TdM mainly due to higher power prices and volumes; offset by

▪ $28 million earnings attributable to NCI at IEnova in 2019 compared to $2 million losses in 2018.

Sempra Renewables

The decrease in earnings of $8 million (38%) in the three months ended March 31, 2019 was primarily due to:

▪ $16 million lower pretax losses attributed to NCI, primarily due to the 2018 impact of the TCJA on NCI allocations computed using the HLBV method; and

▪ $7 million lower earnings from assets sold in December 2018; offset by

▪ $7 million lower general and administrative and other costs due to the wind-down of this business; and

▪ $4 million lower depreciation as a result of wind assets held for sale.

Sempra LNG

Earnings of $5 million in the three months ended March 31, 2019 compared to losses of $16 million for the same period in 2018 were primarily due to:

▪ $15 million higher earnings from our marketing operations primarily driven by changes in natural gas prices; and

▪ $9 million unfavorable adjustment in 2018 to TCJA provisional amounts recorded in 2017 related to the remeasurement of deferred income taxes.

Parent and Other

The increase in losses of $8 million (7%) in the three months ended March 31, 2019 was primarily due to:

▪ $17 million increase in net interest expense; and

▪ $8 million increase in mandatory convertible preferred stock dividends; offset by

▪ $15 million of investment gains in 2019 compared to $4 million of investment losses in 2018 on dedicated assets in support of our executive retirement and deferred compensation plans, including higher deferred compensation expense associated with these investments; and

▪ $3 million higher income tax benefit including $10 million from a reduction in a valuation allowance against certain NOL carryforwards as a result of our decision to sell our South American businesses.

Discontinued Operations

Discontinued operations that were previously in our Sempra South American Utilities segment include our 100-percent interest in Chilquinta Energía in Chile, our 83.6-percent interest in Luz del Sur in Peru and our 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 South American businesses, that were previously included in the holding company of the South American businesses at Parent and other.

Losses of $51 million in the three months ended March 31, 2019 compared to earnings of $21 million for the same period in 2018 were primarily due to:

▪ $93 million higher income tax expense primarily due to:

◦ $103 million income tax expense in 2019 from outside basis differences in our South American businesses primarily related to the change in our indefinite reinvestment assertion from our decision on January 25, 2019 to hold those businesses for sale, and

◦ $13 million income tax expense related to the increase in outside basis differences from 2019 earnings since January 25, 2019, offset by

◦ $16 million income tax expense in 2018 to adjust TCJA provisional amounts recorded in 2017 primarily related to withholding tax on our expected future repatriation of foreign undistributed earnings; offset by

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▪ $23 million higher earnings from South American operations, including $15 million at Peru due to an increase in rates and lower cost of purchased power and $7 million lower depreciation expense due to assets classified as held for sale.

ADJUSTED EARNINGS AND ADJUSTED EPS

We prepare the Condensed Consolidated Financial Statements in conformity with U.S. GAAP. However, management may use earnings and EPS adjusted to exclude certain items (referred to as Adjusted Earnings and Adjusted EPS) internally for financial planning, for analysis of performance and for reporting of results to the board of directors. We may also use Adjusted Earnings and Adjusted EPS when communicating our financial results and earnings outlook to analysts and investors. Adjusted Earnings and Adjusted EPS are non-GAAP financial measures. Because of the significance and/or nature of the excluded items, management believes that these non-GAAP financial measures provide a meaningful comparison of the performance of business operations to prior and future periods. Non-GAAP financial measures are supplementary information that should be considered in addition to, but not as a substitute for, the information prepared in accordance with U.S. GAAP.

For each period in which a non-GAAP financial measure is used, we provide in the table below a reconciliation of Sempra Energy Adjusted Earnings, Adjusted EPS, and Weighted-Average Common Shares Outstanding – Adjusted to GAAP Earnings, GAAP EPS, and Weighted-Average Common Shares Outstanding – GAAP, which we consider to be the most directly comparable financial measures calculated in accordance with U.S. GAAP.

SEMPRA ENERGY ADJUSTED EARNINGS AND ADJUSTED EPS
(Dollars in millions, except per share amounts; shares in thousands)
	Income tax expense (benefit)			Earnings			Diluted EPS
	Three months ended March 31, 2019
Sempra Energy GAAP Earnings				$	441		$	1.59
Impact of dilutive shares excluded from GAAP EPS(1)							(0.07		)
Excluded items:
Associated with holding the South American businesses for sale:
Change in indefinite reinvestment assertion of basis differences in discontinued operations	$	103		103			0.35
Reduction in tax valuation allowance against certain NOL carryforwards	(10		)	(10		)	(0.04		)
Sempra Energy Adjusted Earnings				534
Add back series A preferred stock dividends(1)				26			0.09
Sempra Energy Adjusted Earnings for Adjusted EPS(1)				$	560		$	1.92
Weighted-average common shares outstanding, diluted – GAAP							277,228
Add series A preferred stock shares(1)							13,951
Weighted-average common shares outstanding, diluted – Adjusted							291,179
	Three months ended March 31, 2018
Sempra Energy GAAP Earnings				$	347		$	1.33
Excluded item:
Impact from the TCJA	$	25		25			0.10
Sempra Energy Adjusted Earnings				$	372		$	1.43
Weighted-average common shares outstanding, diluted – GAAP							259,490

⁽¹⁾ In the three months ended March 31, 2019, the assumed conversion of the series A preferred stock and the series B preferred stock are antidilutive for GAAP Earnings, however, the series A preferred stock is dilutive for the higher Adjusted Earnings. As such, the series A preferred stock dividends have been added back to the numerator and the dilutive effect of the series A preferred stock shares has been added to the denominator when calculating Adjusted EPS.

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 Energy, SDG&E and SoCalGas.

Utilities Revenues

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 the Sempra Energy Condensed Consolidated Statements of Operations.

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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. However, SoCalGas’ GCIM 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 Condensed Consolidated Financial Statements herein and in “Item 1. Business – Ratemaking Mechanisms” in the Annual Report.

▪ permits 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 in subsequent periods through rates.

▪ permits the California Utilities to recover certain expenses for programs authorized by the CPUC, or “refundable programs.”

Because changes in SoCalGas’ and SDG&E’s cost of natural gas and/or electricity are substantially 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 herein 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. Accordingly, a significant portion of SoCalGas’ annual earnings are 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.

The table below summarizes revenues and cost of sales for our consolidated utilities.

UTILITIES REVENUES AND COST OF SALES
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Natural gas revenues:
SoCalGas	$	1,361		$	1,126
SDG&E	205			171
Sempra Mexico	27			28
Eliminations and adjustments	(17		)	(17		)
Total	1,576			1,308
Electric revenues:
SDG&E	940			884
Eliminations and adjustments	(1		)	(2		)
Total	939			882
Total utilities revenues	$	2,515		$	2,190
Cost of natural gas:
SoCalGas	$	455		$	289
SDG&E	79			50
Sempra Mexico	5			13
Eliminations and adjustments	(8		)	(4		)
Total	$	531		$	348
Cost of electric fuel and purchased power:
SDG&E	$	258		$	274
Eliminations and adjustments	(2		)	(3		)
Total	$	256		$	271

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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 March 31,
	2019		2018
SoCalGas	$	3.85	$	2.92
SDG&E	4.60		3.54

In the three months ended March 31, 2019, Sempra Energy’s natural gas revenues increased by $268 million (20%) to $1.6 billion primarily due to:

▪ $235 million increase at SoCalGas, which included:

◦ $166 million increase in cost of natural gas sold, which we discuss below,

◦ $20 million higher revenues from capital projects,

◦ $9 million higher recovery of costs associated with CPUC-authorized refundable programs, which revenues are offset in O&M,

◦ $7 million decrease in charges in 2019 associated with tracking the income tax benefit from flow-through items in relation to forecasted amounts in the 2016 GRC FD, and

◦ $7 million GCIM award approved by the CPUC in February 2019; and

▪ $34 million increase at SDG&E, primarily due to an increase in the cost of natural gas sold, which we discuss below.

In the three months ended March 31, 2019, our cost of natural gas increased by $183 million (53%) to $531 million primarily due to:

▪ $166 million increase at SoCalGas due to $109 million from higher average natural gas prices and $57 million from higher volumes driven by weather; and

▪ $29 million increase at SDG&E due to $18 million from higher average natural gas prices and $11 million from higher volumes driven by weather.

Electric Revenues and Cost of Electric Fuel and Purchased Power

In the three months ended March 31, 2019, our electric revenues increased by $57 million (6%) to $939 million, primarily at SDG&E, including:

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

▪ $23 million higher revenues from transmission operations.

Our utility cost of electric fuel and purchased power decreased by $15 million (6%) to $256 million in the three months ended March 31, 2019 primarily at SDG&E. The decrease was due to $51 million in finance lease costs for PPAs that are now included in Interest Expense and Depreciation and Amortization Expense as a result of the 2019 adoption of the lease standard, which we discuss in Note 2 of the Notes to Condensed Consolidated Financial Statements, partially offset by $35 million in higher electricity market costs and an additional capacity contract.

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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 March 31,
	2019			2018
REVENUES
Sempra Mexico	$	356		$	280
Sempra Renewables	7			25
Sempra LNG	141			104
Eliminations and adjustments	(121		)	(63		)
Total revenues	$	383		$	346
COST OF SALES(1)
Sempra Mexico	$	121		$	61
Sempra LNG	103			70
Eliminations and adjustments	(116		)	(62		)
Total cost of sales	$	108		$	69

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

In the three months ended March 31, 2019, revenues from our energy-related businesses increased by $37 million (11%) to $383 million primarily due to:

▪ $76 million increase at Sempra Mexico primarily due to:

◦ $54 million from the marketing business, primarily from higher natural gas prices and volumes, including higher volumes due to new regulations that went into effect on March 1, 2018 that require high consumption end users (previously serviced by Ecogas and other natural gas utilities) to procure their natural gas needs from natural gas marketers, including Sempra Mexico’s marketing business, and

◦ $25 million at TdM due to higher prices and volumes; and

▪ $37 million increase at Sempra LNG primarily due to:

◦ $34 million higher natural gas sales to Sempra Mexico due to higher natural gas prices and volumes, and

◦ $22 million from natural gas marketing activities from changes in natural gas prices, offset by

◦ $12 million from LNG sales to Cameron LNG JV in January 2018; offset by

▪ $58 million from higher intercompany eliminations associated with sales between Sempra LNG and Sempra Mexico; and

▪ $18 million decrease at Sempra Renewables primarily due to the sale of solar assets in December 2018.

In the three months ended March 31, 2019, the cost of sales for our energy-related businesses increased by $39 million to $108 million primarily due to:

▪ $60 million increase at Sempra Mexico mainly associated with higher revenues from the marketing business as a result of higher natural gas prices and volumes, including higher volumes due to new regulations that went into effect in 2018. The increase at Sempra Mexico was also due to higher prices and volumes at TdM; and

▪ $33 million increase at Sempra LNG mainly from natural gas marketing activities primarily from higher natural gas prices; offset by

▪ $54 million primarily from higher intercompany eliminations associated with sales between Sempra LNG and Sempra Mexico.

Operation and Maintenance

Our O&M increased by $91 million (12%) to $832 million in the three months ended March 31, 2019 primarily due to:

▪ $38 million increase at SDG&E, which included:

◦ $16 million higher expenses associated with CPUC-authorized refundable programs for which costs incurred are recovered in revenue (refundable program expenses), and

◦ $16 million higher non-refundable operating costs, including wildfire insurance premiums and administrative and support costs;

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▪ $26 million increase at SoCalGas, which included:

◦ $17 million higher non-refundable operating costs due to weather related impacts, and

◦ $9 million higher expenses associated with CPUC-authorized refundable programs expenses; and

▪ $21 million increase at Parent and other primarily from higher retained operating costs.

Other Income, Net

As part of our central risk management function, we 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 Income, Net, as described below, and partially mitigate the transactional effects of foreign currency and inflation included in Income Taxes and in earnings from Sempra Mexico’s equity method investments. We discuss policies governing our risk management in “Item 7A. Quantitative and Qualitative Disclosure about Market Risk” in the Annual Report.

Other income, net, decreased by $70 million (46%) to $82 million in the three months ended March 31, 2019 primarily due to:

▪ $72 million lower net gains in 2019 from interest rate and foreign exchange instruments and foreign currency transactions primarily due to:

◦ $34 million lower gains on foreign currency derivatives as a result of fluctuation of the Mexican peso, and

◦ $29 million lower foreign currency gains on a Mexican peso-denominated loan to the IMG JV, which is offset in Equity Earnings (Losses);

▪ $8 million lower non-service component of net periodic benefit credit in 2019; and

▪ $8 million in penalties related to the SoCalGas billing practices OII; offset by

▪ $26 million investment gains in 2019 compared to $1 million of investment losses in 2018 on dedicated assets in support of our executive retirement and deferred compensation plans.

Interest Expense

Interest expense increased by $54 million (26%) to $260 million in the three months ended March 31, 2019 primarily due to the inclusion of finance lease costs for SDG&E’s PPAs as a result of adoption of the lease standard. Prior to 2019, such costs were included in Cost of Electric Fuel and Purchased Power.

Income Taxes

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

INCOME TAX EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Sempra Energy Consolidated:
Income tax expense from continuing operations	$	42		$	242
Income from continuing operations before income taxes
and equity earnings (losses) of unconsolidated entities	$	501		$	593
Equity earnings, before income tax(1)	5			5
Pretax income	$	506		$	598
Effective income tax rate	8		%	40		%
SDG&E:
Income tax expense	$	5		$	56
Income before income taxes	$	182		$	225
Effective income tax rate	3		%	25		%
SoCalGas:
Income tax expense	$	19		$	59
Income before income taxes	$	283		$	284
Effective income tax rate	7		%	21		%

⁽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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Sempra Energy Consolidated

The decrease in income tax expense in the three months ended March 31, 2019 was due to lower pretax income and a lower ETR. The change in ETR was primarily due to:

▪ $69 million lower income tax expense from foreign currency and inflation effects as a result of fluctuation of the Mexican peso;

▪ $66 million total income tax benefits from the release of regulatory liabilities at SDG&E and SoCalGas established in connection with 2017 tax reform for excess deferred income tax balances that the CPUC directed be allocated to shareholders in a January 2019 decision;

▪ $10 million income tax benefit from a reduction in a valuation allowance against certain NOL carryforwards as a result of our decision to sell our South American businesses; and

▪ $9 million income tax expense in 2018 to adjust provisional estimates recorded in 2017 for the effects of tax reform.

We discuss the impact of foreign 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 herein 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

The decrease in SDG&E’s income tax expense in the three months ended March 31, 2019 was due to lower pretax income and a lower ETR. The change in ETR was primarily due to:

▪ $31 million income tax benefit from the release of a regulatory liability established in connection with 2017 tax reform for excess deferred income tax balances that the CPUC directed be allocated to shareholders in a January 2019 decision; and

• higher income tax benefits from flow-through deductions.

SoCalGas

The decrease in SoCalGas’ income tax expense in the three months ended March 31, 2019 was due to a lower ETR offset by higher pretax income. The change in ETR was primarily due to a $35 million income tax benefit from the release of a regulatory liability established in connection with 2017 tax reform for excess deferred income tax balances that the CPUC directed be allocated to shareholders in a January 2019 decision.

Equity Earnings (Losses)

In the three months ended March 31, 2019, equity earnings were $101 million compared to losses of $21 million for the same period in 2018 primarily due to:

▪ $79 million higher equity earnings, net of income tax, from our investment in Oncor Holdings, which we acquired in March 2018; and

▪ $29 million lower foreign currency losses in 2019 at the IMG JV on its Mexican peso-denominated loans from its JV owners, which is fully offset in Other Income, Net.

(Earnings) Losses Attributable to Noncontrolling Interests

Earnings attributable to NCI for the three months ended March 31, 2019 were $41 million compared to losses attributable to NCI of $17 million for the same period in 2018. The change was primarily due to:

▪ $30 million increase in earnings attributable to NCI at Sempra Mexico in 2019; and

▪ $21 million pretax losses attributed to tax equity investors at Sempra Renewables in 2018.

Mandatory Convertible Preferred Stock Dividends

In the three months ended March 31, 2019, mandatory convertible preferred stock dividends increased by $8 million to $36 million primarily due to dividends associated with our series B preferred stock, which were issued in July 2018.

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IMPACT OF FOREIGN CURRENCY AND INFLATION RATES ON RESULTS OF OPERATIONS

Because our natural gas distribution utility in Mexico 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 Energy Consolidated’s results of operations. We discuss further the impact of foreign currency and inflation rates on results of operations, including impacts on income taxes and related hedging activity, in “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 Energy’s comparative results of operations. In the three months ended March 31, 2019 compared to the prior-year period, the change in our earnings as a result of foreign currency translation was not material.

Foreign Currency Transactional Impacts

Income statement activities at our foreign operations and their JVs are also impacted by transactional gains and losses. A summary of these foreign currency transactional gains and losses included in our reported results is shown in the table below:

TRANSACTIONAL GAINS (LOSSES) FROM FOREIGN CURRENCY AND INFLATION
(Dollars in millions)
	Total reported amounts						Transactional gains (losses) included in reported amounts
	Three months ended March 31,
	2019			2018			2019			2018
Other income, net	$	82		$	152		$	20		$	92
Income tax expense	(42		)	(242		)	(23		)	(94		)
Equity earnings (losses)	101			(21		)	(12		)	(51		)
Income from continuing operations	560			330			(18		)	(65		)
(Loss) income from discontinued operations, net of income tax	(42		)	28			—			1
Earnings attributable to common shares	441			347			(10		)	(31		)

CAPITAL RESOURCES AND LIQUIDITY

OVERVIEW

We expect to meet our cash requirements through cash flows from operations, unrestricted cash and cash equivalents, proceeds from recent and planned asset sales, borrowings under our credit facilities, distributions from our equity method investments, issuances of debt and equity securities, project financing and other equity sales, including partnering in JVs.

Our lines of credit provide liquidity and support commercial paper. As we discuss in Note 7 of the Notes to Condensed Consolidated Financial Statements, at March 31, 2019, Sempra Energy, Sempra Global and the California Utilities each had five-year revolving credit facilities expiring in 2020. The table below shows the amount of available funds, including available unused credit on these three credit facilities. In addition, IEnova has a $1.5 billion line of credit, with approximately $692 million available unused credit at March 31, 2019.

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AVAILABLE FUNDS AT MARCH 31, 2019
(Dollars in millions)
	Sempra Energy Consolidated		SDG&E		SoCalGas
Unrestricted cash and cash equivalents(1)	$	78	$	10	$	3
Available unused credit(2)(3)	3,718		512		560

⁽¹⁾  Amounts at Sempra Energy Consolidated included $58 million held in non-U.S. jurisdictions. We discuss repatriation in Note 1 of the Notes to Condensed Consolidated Financial Statements.

⁽²⁾  Available unused credit is the total available on Sempra Energy’s, Sempra Global’s and the California Utilities’ credit facilities that we discuss in Note 7 of the Notes to Condensed Consolidated Financial Statements. Borrowings on the shared line of credit at SDG&E and SoCalGas are limited to $750 million for each utility and a combined total of $1 billion. The available balance at each of the California Utilities assumes no additional borrowings by the other.

⁽³⁾  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.

Sempra Energy Consolidated

We believe that these available funds, combined with cash flows from operations, proceeds from recent and planned asset sales, distributions from our equity method investments, issuances of debt and equity securities, project financing and other equity sales, including partnering in JVs, 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 maturing long-term debt; and

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

Sempra Energy and the California Utilities currently have ready access to the long-term debt markets and are not currently constrained in their ability to borrow at reasonable rates. However, changing economic conditions, the inability of California legislative and regulatory bodies to reduce the economic exposure of our California Utilities to any potential future wildfires, our financing activities and actions by credit rating agencies 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 of large projects. 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 used $1.6 billion in cash proceeds received from Sempra Renewables’ December 2018 sale, which we discuss in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report, to temporarily pay down commercial paper, pending the close of Oncor’s agreement to purchase InfraREIT and our agreement to purchase a 50-percent interest in Sharyland Holdings, LP, as described below. We use short-term debt primarily to meet liquidity requirements, fund shareholder dividends, and temporarily finance capital expenditures, acquisitions or start-ups. Our corporate short-term, unsecured promissory notes, or commercial paper, were our primary sources of short-term debt funding in the first three months of 2019. Our California Utilities use short-term debt primarily to meet working capital needs.

At March 31, 2019, Sempra Energy had loans to unconsolidated affiliates totaling $668 million and a loan from an unconsolidated affiliate totaling $38 million, which we discuss in Note 1 of the Notes to Condensed Consolidated Financial Statements.

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 the activity in the equity and fixed income markets, have not affected the trust funds’ abilities to make required payments. However, changes in asset values may, along with a number of other factors such as changes to discount rates, assumed rates of return, mortality tables, and regulations, impact funding requirements for pension and other postretirement benefit plans and SDG&E’s NDT. 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.

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Common Stock Under Forward Sale Agreements

As we discuss in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report, our forward sale agreements permit us to elect cash settlement or net share settlement for all or a portion of our obligations under the forward sale agreements. We expect to settle the forward sale agreements entirely by the physical delivery of shares of our common stock in exchange for cash proceeds. As of May 7, 2019, based on the initial forward sale price of approximately $105.07 per share in January 2018 and approximately $111.87 per share in July 2018, we expect that the net proceeds from full physical settlement of the remaining forward sale agreements would be approximately $1.8 billion (net of underwriting discounts, but before deducting equity issuance costs, and subject to certain adjustments pursuant to the forward sale agreements). If we were to elect cash settlement or net share settlement, the amount of cash proceeds we receive upon settlement could differ, perhaps substantially, or we may not receive any cash proceeds or we may deliver cash (in an amount which could be significant) or shares of our common stock to the forward purchasers. We expect to settle the remaining portion of the forward sale agreements in one or more settlements no later than December 15, 2019, which is the final settlement date under the agreements.

Discontinued Operations

On January 25, 2019, our board of directors approved a plan to sell our South American businesses. As such, we have reclassified these businesses to held for sale and presented them as discontinued operations. We expect to complete the sale by the end of 2019 and use the proceeds from such sale to focus on capital investment in the U.S. and Mexico to support additional growth opportunities and strengthen our balance sheet by reducing debt.

Our utilities in South America have historically provided relatively stable earnings and liquidity. We expect the cash provided by earnings from our focused capital investment will exceed the absence of cash flows from these discontinued operations. However, there can be no assurance that we will derive these anticipated benefits. While we expect to complete the sale of our South American businesses by the end of 2019, the planned sale will depend on several factors beyond our control, including, but not limited to, regulatory approvals, market conditions, political and macroeconomic factors, industry trends, consent rights or other rights granted to or held by third parties and the availability of financing to potential buyers on reasonable terms. Further, there can be no assurance that the sale, if completed, will result in a sales price that we believe adequately values these businesses or additional value to our shareholders, or that we will be able to redeploy the capital that we obtain from such sale in a way that would result in cash flows or earnings exceeding those historically generated by these businesses.

California Utilities

SDG&E and SoCalGas expect that the available unused credit described above, cash flows from operations, and debt issuances will continue to be adequate to fund their respective operations. As we discuss below in “Item 3. Quantitative and Qualitative Disclosures About Market Risk – Credit Ratings,” the credit ratings of SDG&E and SoCalGas may affect the rates at which borrowings bear interest, collateral to be posted and fees on outstanding credit facilities. The California Utilities manage their capital structure and pay dividends when appropriate and as approved by their respective boards of directors.

SDG&E declared common stock dividends of $250 million in the year ended December 31, 2018. SDG&E’s declared common stock dividends on an annual historical basis may not be indicative of future declarations, and could be impacted over the next few years in order for SDG&E to maintain its authorized capital structure while managing its capital investment program (approximately $1.6 billion in 2019, which does not include the impact of the OMEC LLC put option that we discuss below).

SoCalGas declared common stock dividends of $50 million in the year ended December 31, 2018. As a result of its capital investment program, SoCalGas had not previously declared or paid common stock dividends since 2015. SoCalGas expects that its common stock dividends will continue to be impacted by its ability to maintain its authorized capital structure while managing its capital investment program (approximately $1.5 billion in 2019).

As we discuss 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, as these changes generally represent the difference between when costs are incurred and when they are ultimately recovered in rates through billings to customers.

SDG&E’s and SoCalGas’ balancing accounts include:

▪ Energy Resource Recovery Balancing Account (ERRA) – tracks the difference between amounts billed to customers and the actual cost of electric fuel and purchased power. SDG&E’s ERRA balance was undercollected by $126 million and $50 million at March 31, 2019 and December 31, 2018, respectively. The increase in the ERRA undercollected balance in 2019 was primarily due to seasonalized electric rates. We typically undercollect in the winter months due to lower winter rates and overcollect in the summer months when the higher summer rates take effect. We expect the ERRA undercollected balance to decrease through the end of the year.

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▪ Core Fixed Cost Account (CFCA) – tracks the difference between amounts billed to customers and the authorized margin and other costs allocated to core customers. SDG&E’s CFCA balance was undercollected by $18 million and $51 million at March 31, 2019 and December 31, 2018, respectively, and SoCalGas’ CFCA balance was undercollected by $63 million and $177 million at March 31, 2019 and December 31, 2018, respectively. The decrease in undercollection was mainly due to cold weather resulting in higher natural gas consumption compared to authorized levels.

SDG&E

As we discuss in Note 1 of the Notes to Condensed Consolidated Financial Statements, SDG&E has a tolling agreement to purchase power generated at OMEC, a 605-MW generating facility. Under the terms of a related agreement, OMEC LLC can require SDG&E to purchase the power plant (referred to as the put option) for $280 million, subject to adjustments. On March 28, 2019, OMEC LLC exercised the put option requiring SDG&E to purchase the power plant by October 3, 2019.

SoCalGas

Aliso Canyon Natural Gas Storage Facility Gas Leak

We provide information on the natural gas leak at the Aliso Canyon natural gas storage facility further in Note 11 of the Notes to Condensed Consolidated Financial Statements herein, in “Factors Influencing Future Performance” below and in “Item 1A. Risk Factors” in the Annual Report. The costs incurred to remediate and stop the Leak and to mitigate local community impacts are significant and may increase, and the costs of defending against the related civil and criminal lawsuits and cooperating with related investigations, and any damages, restitution, and civil, administrative and criminal fines, costs and other penalties, if awarded or imposed, as well as costs of mitigating the actual natural gas released, could be significant, and to the extent not covered by insurance (including any costs in excess of applicable policy limits), if there were to be significant 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 could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations. Also, higher operating costs and additional capital expenditures incurred by SoCalGas as a result of new laws, orders, rules and regulations arising out of this incident or our responses thereto could be significant and may not be recoverable in customer rates, which may have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

Sempra Texas Utility

Oncor’s business is capital intensive, and it relies on external financing as a significant source of liquidity for its capital requirements. In the past, Oncor has financed a substantial portion of its cash needs from operations and with proceeds from indebtedness. In the event that Oncor fails to meet its capital requirements, we may be required to make additional investments in Oncor, or if Oncor is unable to access sufficient capital to finance its ongoing needs, we may elect to make additional investments in 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, financial condition and prospects. In that regard, our commitments to the PUCT prohibit us from making loans to Oncor. As a result, if Oncor requires additional financing and cannot obtain it from other sources, we may be required to make a capital contribution to Oncor.

On October 18, 2018, Sempra Energy committed to make a capital contribution to Oncor for Oncor to fund its pending acquisition of interests in InfraREIT, which we expect will close in mid-2019. We estimate the capital contribution to be $1,025 million, excluding Sempra Energy’s share of approximately $40 million for a management agreement termination fee, as well as other customary transaction costs incurred by InfraREIT that will be borne by Oncor as part of the acquisition. We expect to fund our capital contribution to Oncor and to purchase the 50-percent limited partner interest in Sharyland Holdings, LP by utilizing a portion of the proceeds received from the sales of Sempra Renewables’ assets. The capital contribution is contingent on the satisfaction of customary conditions, including the substantially simultaneous closing of the transactions contemplated by the InfraREIT Merger Agreement. We discuss these transactions in Note 5 of the Notes to Condensed Consolidated Financial Statements herein and below in “Factors Influencing Future Performance.”

Sempra Mexico

We expect to fund operations and dividends at IEnova with available funds, including credit facilities, and funds internally generated by the Sempra Mexico businesses, as well as funds from IEnova’s securities issuances, project financing, interim funding from the parent or affiliates, and partnering in JVs.

IEnova paid $71 million of dividends to minority shareholders in the year ended December 31, 2018.

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IEnova’s shareholders approved the formation of a fund for IEnova to repurchase its own shares for a maximum amount of $250 million. Repurchases shall not exceed IEnova’s total net profits, including retained earnings, as stated in their financial statements. In the three months ended March 31, 2019, IEnova repurchased 1,600,000 shares of its outstanding common stock held by NCI for approximately $6 million, resulting in an increase in Sempra Energy’s ownership interest in IEnova from 66.5 percent at December 31, 2018 to 66.6 percent at March 31, 2019.

Sempra Renewables

As we discuss in Note 5 of the Notes to Condensed Consolidated Financial Statements herein and below in “Factors Influencing Future Performance,” in April 2019, Sempra Renewables sold its remaining wind assets and investments for $584 million in cash, subject to working capital and other customary adjustments. The proceeds from the sale will be used to pay down debt and redeploy capital to support the strategic growth of Sempra Energy in North America.

Sempra LNG

Sempra LNG, through its interest in Cameron LNG JV, is constructing a natural gas liquefaction export facility at the Cameron LNG JV terminal. The majority of the current three-train liquefaction project is project-financed, with most or all of the remainder of the capital requirements to be provided by the project partners, including Sempra Energy, through equity contributions under the project equity agreements. We expect that our remaining equity requirements to complete the project will be met by a combination of our share of cash generated from each liquefaction train as it comes on line and additional cash contributions. Sempra Energy guarantees 50.2 percent of Cameron LNG JV’s obligations under the financing agreements for a maximum amount of up to $3.9 billion. The guarantees will terminate upon satisfaction of certain conditions, including all three trains achieving commercial operation and meeting certain operational performance tests. We anticipate that the guarantees will be terminated approximately nine months after all three trains achieve commercial operation. We discuss Cameron LNG JV and the JV financing further in Note 6 of the Notes to Consolidated Financial Statements, in “Item 1A. Risk Factors” and in “Item 7. MD&A – Factors Influencing Future Performance” in the Annual Report. We also discuss Cameron LNG JV below in “Factors Influencing Future Performance.”

We expect Sempra LNG to require funding for the development and expansion of its remaining portfolio of projects, which may be financed through a combination of operating cash flow, funding from the parent, project financing and partnering in JVs.

CASH FLOWS FROM OPERATING ACTIVITIES

CASH PROVIDED BY OPERATING ACTIVITIES
(Dollars in millions)
	Three months ended March 31, 2019		2019 change					Three months ended March 31, 2018
Sempra Energy Consolidated	$	951	$	(15	)	(2	)%	$	966
SDG&E	443		39			10		404
SoCalGas	376		(43		)	(10	)	419

Sempra Energy Consolidated

Cash provided by operating activities at Sempra Energy decreased in 2019 primarily due to:

▪ $100 million net decrease in Reserve for Aliso Canyon Costs in 2019 compared to an $18 million net increase in 2018. The $100 million net decrease in 2019 includes $116 million of cash paid, offset by $16 million of additional accruals; and

▪ $3 million decrease in interest payable in 2019 compared to a $91 million increase in 2018; offset by

▪ $203 million increase in net overcollected regulatory balancing accounts (including long-term amounts included in regulatory assets) at SoCalGas in 2019 compared to a $94 million increase in 2018;

▪ $54 million distribution of earnings received from Oncor in 2019; and

▪ $71 million decrease in inventory in 2019 compared to a $25 million decrease in 2018.

Our discontinued operations provided cash from operating activities of $93 million in 2019 compared to $76 million in 2018.

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SDG&E

Cash provided by operating activities at SDG&E increased in 2019 primarily due to:

▪ $36 million increase in contributions in aid of construction in 2019; and

▪ $16 million lower purchases of GHG allowances in 2019; offset by

▪ $34 million increase in income taxes payable in 2019 compared to a $67 million increase in 2018.

SoCalGas

Cash provided by operating activities at SoCalGas decreased in 2019 primarily due to:

▪ $100 million net decrease in Reserve for Aliso Canyon Costs in 2019 compared to an $18 million net increase in 2018. The $100 million net decrease in 2019 includes $116 million of cash paid, offset by $16 million of additional accruals;

▪ $77 million lower net income, adjusted for noncash items included in earnings, in 2019 compared to 2018; and

▪ $36 million increase in accounts receivable in 2019 compared to a $6 million decrease in 2018; offset by

▪ $203 million increase in net overcollected regulatory balancing accounts (including long-term amounts included in regulatory assets) in 2019 compared to a $94 million increase in 2018; and

▪ $84 million increase in income taxes payable in 2019 compared to an $11 million increase in 2018.

CASH FLOWS FROM INVESTING ACTIVITIES

CASH USED IN INVESTING ACTIVITIES
(Dollars in millions)
	Three months ended March 31, 2019			2019 change					Three months ended March 31, 2018
Sempra Energy Consolidated	$	(610	)	$	(10,092	)	(94	)%	$	(10,702	)
SDG&E	(356		)	(119		)	(25	)	(475		)
SoCalGas	(324		)	(76		)	(19	)	(400		)

Sempra Energy Consolidated

Cash used in investing activities at Sempra Energy decreased in 2019 primarily due to:

▪ $9.55 billion paid, including $9.45 billion of Merger Consideration, for the acquisition of our investment in Oncor Holdings in March 2018, as we discuss in Note 5 of the Notes to Condensed Consolidated Financial Statements;

▪ $327 million net proceeds from the sale of Sempra LNG’s non-utility natural gas storage assets; and

▪ $196 million decrease in capital expenditures.

Our discontinued operations used cash in investing activities of $70 million in 2019 compared to $58 million in 2018.

SDG&E

Cash used in investing activities at SDG&E decreased in 2019 due to lower capital expenditures.

SoCalGas

Cash used in investing activities at SoCalGas decreased in 2019 primarily due to lower capital expenditures.

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Capital Expenditures

EXPENDITURES FOR PROPERTY, PLANT AND EQUIPMENT
(Dollars in millions)
	Three months ended March 31,
	2019		2018
SDG&E:
Improvements to electric and natural gas distribution systems, including certain pipeline safety
and generation systems	$	268	$	353
PSEP	6		8
Improvements to electric transmission systems	82		114
SoCalGas:
Improvements to natural gas distribution, transmission and storage systems, and for certain
pipeline safety	284		359
PSEP	40		44
Sempra Mexico:
Construction of liquid fuels terminal	24		15
Construction of natural gas pipeline projects and other capital expenditures	32		29
Construction of renewables projects	29		15
Sempra Renewables:
Construction costs for wind and solar projects	—		31
Sempra LNG:
LNG liquefaction development costs	18		5
Other	—		1
Parent and other	—		5
Total	$	783	$	979

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 and the FERC. Excluding discontinued operations, in 2019, we expect to make capital expenditures and investments of approximately $5.8 billion, as we discuss in “Item 7. MD&A – Capital Resources and Liquidity” in the Annual Report.

CASH FLOWS FROM FINANCING ACTIVITIES

CASH FLOWS FROM FINANCING ACTIVITIES
(Dollars in millions)
	Three months ended March 31, 2019			2019 change			Three months ended March 31, 2018
Sempra Energy Consolidated	$	(381	)	$	(10,059	)	$	9,678
SDG&E	(75		)	(142		)	67
SoCalGas	(67		)	(51		)	(16		)

Sempra Energy Consolidated

Financing activities at Sempra Energy were a use of cash in 2019 compared to a source of cash in 2018 primarily due to:

▪ $5.6 billion lower issuances of debt with maturities greater than 90 days, including:

◦ $5 billion for long-term debt issued in 2018 primarily to fund the acquisition of our investment in Oncor Holdings, and

◦ $678 million for commercial paper and other short-term debt ($303 million in 2019 compared to $981 million in 2018);

▪ $1.7 billion proceeds, net of $32 million in offering costs, from the issuance of mandatory convertible preferred stock in 2018;

▪ $1.3 billion proceeds, net of $24 million in offering costs, from the issuances of common stock in 2018;

▪ $683 million higher payments of debt with maturities greater than 90 days, including:

◦ $433 million for long-term debt ($537 million in 2019 compared to $104 million in 2018), and

◦ $250 million for commercial paper and other short-term debt ($300 million in 2019 compared to $50 million in 2018); and

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▪ $497 million increase in short-term debt in 2019 compared to a $1.1 billion increase in 2018.

Cash used in financing activities at our discontinued operations was $45 million in 2019 compared to $6 million in 2018. The change was primarily due to common dividends paid by Peru.

SDG&E

SDG&E’s financing activities were a use of cash in 2019 compared to a source of cash in 2018 primarily due to a $53 million net decrease in short-term debt in 2019 compared to an $87 million net increase in 2018.

SoCalGas

Cash used in financing activities at SoCalGas increased in 2019 primarily due to a higher net decrease in short-term debt in 2019.

FACTORS INFLUENCING FUTURE PERFORMANCE

We discuss various factors that could influence our future performance below and in “Item 7. MD&A – Factors Influencing Future Performance” in the Annual Report. We describe below significant developments to capital projects and any significant new capital projects in 2019. You should read the information below together with “Item 7. MD&A – Factors Influencing Future Performance” and “Item 1A. Risk Factors” contained in the Annual Report.

SEMPRA ENERGY

Capital Rotation

We regularly review our portfolio of assets with a view toward allocating capital to those businesses that we believe can further improve shareholder value. Following a comprehensive strategic review of our businesses and asset portfolio by our board of directors and management, in June 2018, we announced our intention to sell several energy infrastructure assets, including our entire portfolio of U.S. wind and U.S. solar assets, as well as certain non-utility natural gas storage assets in the southeast U.S. We completed the sales of our U.S. solar assets in December 2018, our non-utility natural gas storage assets in February 2019 and our remaining U.S. wind assets in April 2019. In January 2019, our board of directors approved a plan to sell our South American businesses based on our strategic shift to be geographically focused on North America. Our South American businesses and certain activities associated with those businesses have been presented as discontinued operations. We expect to complete the sale by the end of 2019. We discuss these sales and discontinued operations further in Note 5 of the Notes to Condensed Consolidated Financial Statements herein and in Notes 5 and 6 of the Notes to Consolidated Financial Statements in the Annual Report.

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SDG&E

Capital Project Updates

CAPITAL PROJECTS PENDING REGULATORY RESOLUTION – SDG&E
Project description		Estimated capital cost (in millions)		Status
Electric Vehicle Charging
§	January 2018 application, pursuant to SB 350, to make investments to support medium-duty and heavy-duty EVs with an estimated implementation cost of $34 million of O&M.	$121	§	Application seeking approval of settlement filed in November 2018. A draft decision is expected in the second quarter of 2019.
Energy Storage Projects
§	February 2018 application, pursuant to AB 2868, to make investments to accelerate the widespread deployment of distributed energy storage systems. SDG&E’s application requests approval of 100 MW of utility-owned energy storage.	$161	§	Draft decision received in February 2019 to direct new solicitations. Final decision expected in the second quarter of 2019.

Other SDG&E Matters

See “Item 7. MD&A – Factors Influencing Future Performance” in the Annual Report for a discussion about:

▪ Electric Rate Reform – California Assembly Bill 327

▪ Potential Impacts of Community Choice Aggregation and Direct Access

▪ Renewable Energy Procurement

SOCALGAS

Aliso Canyon Natural Gas Storage Facility Gas Leak

In October 2015, SoCalGas discovered a leak at one of its injection-and-withdrawal wells, SS25, at its Aliso Canyon natural gas storage facility located in Los Angeles County. SoCalGas worked closely with several of the world’s leading experts to stop the Leak. In February 2016, DOGGR confirmed that the well was permanently sealed.

See Note 11 of the Notes to Condensed Consolidated Financial Statements for discussions of the following related to the Leak:

▪ Local Community Mitigation Efforts;

▪ Civil and Criminal Litigation;

▪ Regulatory Proceedings;

▪ Governmental Investigations and Orders and Additional Regulation; and

▪ Insurance.

The costs incurred to remediate and stop the Leak and to mitigate local community impacts have been significant and may increase, and we may be subject to potential significant damages, restitution, and civil, administrative and criminal fines, penalties and other costs. In addition, the costs of defending against civil and criminal lawsuits, cooperating with investigations, and any damages, restitution, and civil, administrative and criminal fines, penalties and other costs, if awarded or imposed, as well as the costs of mitigating the actual natural gas released, could be significant. To the extent any of these costs are not covered by insurance (including any costs in excess of applicable policy limits), if there were to be significant 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 could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

Cost Estimates and Accounting Impact

At March 31, 2019, SoCalGas estimates its costs related to the Leak are $1,071 million (the cost estimate), which includes $1,043 million of costs recovered or probable of recovery from insurance. Approximately 53 percent of the cost estimate is for the temporary relocation program (including cleaning costs and certain labor costs). The remaining portion of the cost estimate includes costs incurred to defend litigation, the costs of the government-ordered response to the Leak including the costs for an

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independent third party to conduct a root cause analysis, efforts to control the well, to mitigate the actual natural gas released, the cost of replacing the lost gas, and other costs, as well as the estimated costs to settle certain actions. SoCalGas adjusts the cost estimate as additional information becomes available. A substantial portion of the cost estimate has been paid, and $60 million is accrued as Reserve for Aliso Canyon Costs as of March 31, 2019 on SoCalGas’ and Sempra Energy’s Condensed Consolidated Balance Sheets.

As of March 31, 2019, we recorded the expected recovery of the cost estimate related to the Leak of $477 million as Insurance Receivable for Aliso Canyon Costs on SoCalGas’ and Sempra Energy’s Condensed Consolidated Balance Sheets. This amount is net of insurance retentions and $566 million of insurance proceeds we received through March 31, 2019. The Insurance Receivable for Aliso Canyon Costs and insurance proceeds received to date relate to portions of the cost estimate described above, including temporary relocation and associated processing costs, control-of-well expenses, costs of the government-ordered response for an independent third party to conduct a root cause analysis, the costs to settle certain claims as described in “Civil and Criminal Litigation” in Note 11 of the Notes to Condensed Consolidated Financial Statements, the estimated costs to perform obligations pursuant to settlement of some of those claims, legal costs and lost gas. If we were to conclude that this receivable or a portion of it is no longer probable of recovery from insurers, some or all of this receivable would be charged against earnings, which could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

As described in “Civil and Criminal Litigation” in Note 11 of the Notes to Condensed Consolidated Financial Statements, the actions seek compensatory, statutory and punitive damages, restitution, and civil, administrative and criminal fines, penalties and other costs, which, except for the amounts paid or estimated to settle certain actions, are not included in the cost estimate as it is not possible at this time to predict the outcome of these actions or reasonably estimate the amount of damages, restitution or civil, administrative or criminal fines, penalties or other costs that may be imposed. The recorded amounts above also do not include future legal costs necessary to defend litigation, and other potential costs that we currently do not anticipate incurring or that we cannot reasonably estimate. Furthermore, the cost estimate does not include certain other costs incurred by Sempra Energy associated with defending against shareholder derivative lawsuits.

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 heating needs in the winter. The Aliso Canyon natural gas storage facility, with a capacity of 86 Bcf (representing 63 percent of SoCalGas’ natural gas storage capacity), is the largest SoCalGas storage facility and an important element of SoCalGas’ delivery system. As a result of the Leak, SoCalGas suspended injection of natural gas into the Aliso Canyon natural gas storage facility beginning in October 2015, and following a comprehensive safety review and authorization by DOGGR and the CPUC’s Executive Director, resumed limited injection operations in July 2017.

During the suspension period, SoCalGas advised the California ISO, CEC, CPUC and PHMSA of its concerns that the inability to inject natural gas into the Aliso Canyon natural gas storage facility posed a risk to energy reliability in Southern California. Following the resumption of injection operations, 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 to help ensure safety and reliability for the region and just and reasonable rates in California, the most recent of which, issued in July 2018, directed SoCalGas to maintain up to 34 Bcf of working gas. Limited withdrawals of natural gas from the facility were made in 2018 and 2019 to augment natural gas supplies during critical demand periods.

If the Aliso Canyon natural gas storage facility were to be permanently closed, or if future cash flows were otherwise insufficient to recover its carrying value, it could result in an impairment of the facility and significantly higher than expected operating costs and/or additional capital expenditures, and natural gas reliability and electric generation could be jeopardized. At March 31, 2019, the Aliso Canyon natural gas storage facility had a net book value of $741 million. Any significant impairment of this asset could have a material adverse effect on SoCalGas’ and Sempra Energy’s results of operations for the period in which it is recorded. Higher operating costs and additional capital expenditures incurred by SoCalGas may not be recoverable in customer rates, and could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

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CALIFORNIA UTILITIES – JOINT MATTERS

Capital Project Updates

JOINT CAPITAL PROJECTS PENDING REGULATORY RESOLUTION – CALIFORNIA UTILITIES
Project description		Estimated capital cost (in millions)		Status
Line 1600 Test or Replacement Project
§	In September 2018, SDG&E and SoCalGas submitted a plan to the CPUC to address Line 1600 PSEP requirements by replacing 37 miles of Line 1600 predominately in populated areas and testing 13 miles of Line 1600 in rural areas.	$671	§	In January 2019, the CPUC approved the proposed plan to address Line 1600 PSEP requirements. Cost recovery will be addressed in future GRCs.
§	Estimated O&M implementation cost of $45 million and cost to retire portions of Line 1600 of $14 million at SDG&E.
Mobile Home Park Utility Upgrade Program
§	In April 2018, the CPUC opened an OIR to evaluate the Mobile Home Park Program to convert eligible units to direct utility service and determine if it should be extended beyond the initial three-year pilot to a permanent program, and if extended, to adopt programmatic modifications.	$471 to $508	§	A final decision in the OIR is expected by the end of 2019.
§	In March 2019, the CPUC issued a resolution approving the extension of the pilot program through the earlier of 2021 or the issuance of a CPUC decision on pending proceedings.

Natural Gas Pipeline Operations Safety Assessments

As we discuss in “Item 7. MD&A – Factors Influencing Future Performance” in the Annual Report, since 2011, the California Utilities have incurred costs related to the implementation of the CPUC’s directives to test or replace natural gas transmission pipelines that do not have sufficient documentation of a pressure test and to address retrofitting pipelines to allow for in-line inspection tools and, where appropriate, automated or remote controlled shut-off valves (referred to as PSEP).

As shown in the table below, SoCalGas and SDG&E have made significant pipeline safety investments under the PSEP program, and SoCalGas expects to continue making significant investments as approved through various regulatory proceedings. SDG&E’s PSEP program was substantially completed in 2017, with the exception of Line 1600, which we discuss in the table above. Both utilities have filed joint applications and plan to file future applications with the CPUC for review of the PSEP project costs as follows:

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PIPELINE SAFETY ENHANCEMENT PLAN – REASONABLENESS REVIEW SUMMARY
(Dollars in millions)
	2011 through March 31, 2019
	Total  invested(1)		CPUC review completed(2)		CPUC review pending(3)		2019 and future applications(4)(5)
Sempra Energy Consolidated:
Capital	$	1,725	$	201	$	853	$	671
Operation and maintenance	200		81		85		34
Total	$	1,925	$	282	$	938	$	705
SoCalGas:
Capital	$	1,359	$	187	$	731	$	441
Operation and maintenance	191		80		78		33
Total	$	1,550	$	267	$	809	$	474
SDG&E:
Capital	$	366	$	14	$	122	$	230
Operation and maintenance	9		1		7		1
Total	$	375	$	15	$	129	$	231

⁽¹⁾  Excludes certain pressure testing and pipeline replacement costs incurred through March 31, 2019 that were not eligible for recovery based on prior CPUC decisions. Also excludes $42 million incurred for the Line 1600 Test or Replacement Project.

⁽²⁾  Excludes $2 million of PSEP-specific insurance costs for which SoCalGas and SDG&E are authorized to request recovery in a future filing.

⁽³⁾  Costs for completed projects pursuant to the 2018 Reasonableness Review Application filed in November 2018, with a decision expected in 2020.

⁽⁴⁾  Remaining costs not the subject of prior applications are to be included in subsequent GRCs.

⁽⁵⁾  Authorized to recover 50 percent of the Phase 1 revenue requirement annually, subject to refund.

If either SoCalGas or SDG&E were unable to recover a significant amount of these safety investments from ratepayers, it could have a material adverse effect on the cash flows, results of operations and financial condition of SoCalGas, SDG&E and Sempra Energy.

Senate Bill 901

On September 21, 2018, the Governor of California signed into law SB 901, which includes a number of measures primarily intended to address certain wildfire risks relevant to consumers and utilities and guidelines for the CPUC to determine whether utilities acted reasonably in order to recover costs related to wildfires. Among other things, SB 901 also contains provisions for utility issuance of recovery bonds with respect to certain wildfire costs, subject to CPUC approval, wildfire mitigation plans, and creation of a commission to explore establishment of a fund and options for cost socialization with respect to catastrophic wildfires associated with utility infrastructure. SB 901 does not apply to the wildfires in SDG&E’s service territory in 2007.

The CPUC initiated an OIR in October 2018 to implement the provisions of SB 901 related to electric utility wildfire mitigation plans. The OIR will provide guidance on the form and content of the initial wildfire mitigation plans, provide a venue for review of the initial plans, and develop and refine the content of and process for review and implementation of wildfire mitigation plans to be filed in future years. The electric utilities filed their proposed wildfire mitigation plans in February 2019, and the CPUC issued a proposed decision in April 2019 that approves the plan filed by SDG&E. The scope of the OIR is limited to only the wildfire mitigation plans required by SB 901 and does not include cost recovery. Pursuant to SB 901, in March 2019, the CPUC authorized each utility to establish a memorandum account to track the costs incurred to implement the plan. The costs recorded to the memorandum account shall be incremental to the utility’s authorized recovery and reviewed as part of the utility’s next GRC proceeding.

In April 2019, Governor Gavin Newsom’s Strike Force issued a report entitled “Wildfires and Climate Change: California’s Energy Future” (the Report), and Governor Newsom called for the California legislature to pass legislation to address the issues in the Report by mid-July 2019. The issues raised in the Report include, among others, three concepts designed to help address the imminent wildfire liability issues facing California’s utilities, including SDG&E: a liquidity-only fund, changing strict liability to a fault-based standard and a wildfire fund.

SB 901 did not change the doctrine of inverse condemnation, which imposes strict liability on a utility whose equipment is determined to be a cause of a fire (meaning that the utility may be found liable regardless of fault). In their 2018 ratings actions for SDG&E, which we discuss in “Item 7A. Quantitative and Qualitative Disclosures About Market Risk – Credit Ratings” in the Annual Report, each of Moody’s, Fitch Ratings and S&P indicated that the SDG&E rating downgrades reflected the failure of SB 901 to address the longer-term risks associated with inverse condemnation. Without further changes to the law or other reform,

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the rating agencies believe that SDG&E is exposed to the potential of material liabilities if a major wildfire were to occur in its service territory and it was determined that its equipment was a cause of the fire.

SEMPRA TEXAS UTILITY

Pending Acquisitions

On October 18, 2018, Oncor entered into the InfraREIT Merger Agreement, whereby Oncor has agreed to acquire a 100 percent interest in InfraREIT and InfraREIT Partners for approximately $1,275 million, plus approximately $40 million for a management agreement termination fee, as well as other customary transaction costs incurred by InfraREIT that would be borne by Oncor as part of the acquisition. In addition, the transaction includes InfraREIT’s outstanding debt, which as of March 31, 2019 was approximately $946 million. Also on October 18, 2018, Oncor entered into the Asset Exchange Agreement, whereby SDTS has agreed to accept and assume certain electricity transmission and distribution-related assets and liabilities of SU in exchange for certain SDTS assets. Immediately prior to completing the exchange, SDTS would become a wholly owned, indirect subsidiary of InfraREIT Partners.

On October 18, 2018, Sempra Energy entered into the Securities Purchase Agreement, whereby Sempra Texas Utilities Holdings I, LLC has agreed to acquire 50 percent of the economic interest in Sharyland Holdings, LP for approximately $98 million, subject to customary closing adjustments. In connection with and prior to the consummation of the Securities Purchase Agreement, Sharyland Holdings, LP would own 100 percent of the membership interests in SU and SU would convert into a limited liability company, expected to be named Sharyland Utilities, LLC. Upon consummation of the Securities Purchase Agreement, Sempra Texas Utilities Holdings I, LLC would indirectly own and account for its 50 percent interest in Sharyland Utilities, LLC as an equity method investment.

Consummation of these transactions is subject to the satisfaction of various closing conditions, including the substantially concurrent consummation of these transactions and PUCT approval. In December 2018, early termination of the 30-day waiting period required by the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, was granted. In March 2019, we received approval from the FERC and clearance from the Committee on Foreign Investment in the United States. The acquisition of InfraREIT was approved by InfraREIT stockholders on February 7, 2019. We expect that the transactions will close in mid-2019. There can be no assurance that Oncor and Sempra Energy will derive the anticipated benefits from these acquisitions.

We discuss these transactions further in Note 5 of the Notes to Condensed Consolidated Financial Statements herein and above in “Capital Resources and Liquidity.”

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SEMPRA MEXICO

Capital Project Updates

CAPITAL PROJECTS – SEMPRA MEXICO
Project description		Our share of estimated capital cost (in millions)		Status
Manzanillo Terminal
§	Plan to develop, construct and operate a marine terminal for the receipt, storage and delivery of refined products in Manzanillo, Colima.	$102 to $165	§	Estimated completion: fourth quarter of 2020.
§	Storage capacity of 1.48 million barrels is fully contracted under long-term, U.S. dollar-denominated agreements with Trafigura Mexico, S.A. de C.V. and a major international integrated oil company. Opportunities for future expansion of storage capacity.
§	Owned by TP Terminals, S. de. R.L. de C.V., a JV between IEnova and Trafigura Mexico, S.A. de C.V. IEnova has a 51-percent equity interest in the JV, with an option to increase ownership interest up to 82.5 percent.
La Rumorosa Solar Complex
§	Awarded 41-MW photovoltaic solar energy project located in Baja California, Mexico, in an auction conducted by Mexico’s National Center of Electricity Control (Centro Nacional de Control de Energía) in September 2016.	$50	§	Estimated completion: second quarter of 2019
§	Contracted by the CFE under a 15-year renewable energy agreement and a 20-year clean energy certificate agreement, denominated in U.S. dollars.

Sempra Mexico continues to monitor CFE project opportunities and carefully analyze CFE bids in order to participate in those that fit its overall growth strategy. There can be no assurance that IEnova will be successful in bidding for new CFE projects.

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 “Item 1A. Risk Factors” in the Annual Report.

Energía Costa Azul LNG Terminal

As we discuss in “Item 7. MD&A – Factors Influencing Future Performance” in the Annual Report, Sempra LNG and IEnova are developing a proposed natural gas liquefaction project at IEnova’s existing regasification terminal at ECA. The proposed liquefaction facility project, which we expect will be developed in two phases, is being developed to provide buyers with direct access to west coast LNG supplies. ECA currently has profitable long-term regasification contracts for 100 percent of the regasification facility’s capacity through 2028, making the decisions on whether and how to pursue a new liquefaction facility dependent in part on whether the investment in a new liquefaction facility would, over the long term, be more beneficial financially than continuing to supply regasification services under our existing contracts.

In March 2019, ECA LNG received two authorizations from the DOE to export U.S.-produced natural gas to Mexico and to re-export LNG to non-FTA countries from its Phase 1 and Phase 2 projects in development.

The ultimate participation of TOTAL S.A., Mitsui & Co., Ltd. and Tokyo Gas Co., Ltd. in the potential ECA LNG project as contemplated by a Heads of Agreements signed in November 2018 remains subject to finalization of definitive agreements, among other factors. The development of the ECA LNG Phase 1 and Phase 2 projects is subject to numerous risks and uncertainties, including 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 final investment decision; 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 and permit challenges could materially and adversely affect the development of these projects. For a discussion of these risks, see “Item 1A. Risk Factors” in the Annual Report.

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SEMPRA RENEWABLES

As we discuss in Note 5 of the Notes to Condensed Consolidated Financial Statements, in April 2019, Sempra Renewables sold its remaining wind assets and investments for $584 million in cash, subject to working capital and other customary adjustments. Upon completion of the sale, remaining nominal business activities at Sempra Renewables were subsumed into Parent and other, and the Sempra Renewables segment ceased to exist.

SEMPRA LNG

Cameron LNG JV Three-Train Liquefaction Project

Construction on the current three-train liquefaction project began in the second half of 2014 under an EPC contract with a JV between CB&I, LLC (as assignee of CB&I Shaw Constructors, Inc.), a wholly owned subsidiary of McDermott International, Inc., and Chiyoda International Corporation, a wholly owned subsidiary of Chiyoda Corporation.

Large-scale construction projects like the design, development and construction of the Cameron LNG JV liquefaction facility involve numerous risks and uncertainties, including among others, the potential for unforeseen engineering challenges, substantial construction delays and increased costs. Cameron LNG JV has a turnkey EPC contract, and if the contractor becomes unwilling or unable to perform according to the terms and timetable of the EPC contract, the project could face substantial construction delays and potentially significantly increased costs. If the contractor’s delays or failures are serious enough to cause the contractor to default under the EPC contract, such default could result in Cameron LNG JV’s engagement of a substitute contractor, which would cause further delays.

Based on a number of factors, we believe it is reasonable to expect that Cameron LNG JV will start generating earnings in mid-2019. These factors include, among others, the EPC contractor’s progress to date, the current commissioning activities, the remaining work to be performed, the project schedules received from the EPC contractor, Cameron LNG JV’s own review of the project schedules, the assumptions underlying such schedules, and the inherent risks in constructing and testing facilities such as the Cameron LNG JV liquefaction facility. For a discussion of the Cameron LNG JV and of these risks and other risks relating to the development of the Cameron LNG JV liquefaction project that could adversely affect our future performance, see Note 6 of the Notes to Consolidated Financial Statements and “Item 1A. Risk Factors” in the Annual Report.

Proposed Additional Cameron Liquefaction Expansion

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 from the current three liquefaction trains under construction. The proposed expansion project includes up to two additional liquefaction trains, capable of increasing LNG production capacity by approximately 9 Mtpa to 10 Mtpa, and up to two additional full containment LNG storage tanks (one of which was permitted with the original three-train project).

Under the Cameron LNG JV financing agreements, expansion of the Cameron LNG JV facilities beyond the first three trains is subject to certain restrictions and conditions, including among others, timing restrictions on expansion of the project unless appropriate prior consent is obtained from 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 the partners have been taking place regarding how an expansion may be structured. In July 2018, TOTAL S.A. acquired Engie S.A.’s interest in the Cameron LNG JV. In November 2018, Sempra Energy and TOTAL S.A. entered into an MOU that provides a framework for cooperation for the development of the potential Cameron LNG expansion project and the potential ECA liquefaction-export project that we describe above in “Sempra Mexico – Energía Costa Azul LNG Terminal.” The MOU contemplates TOTAL S.A. potentially contracting for up to approximately 9 Mtpa of LNG offtake across these two development projects, though the ultimate participation of TOTAL S.A. remains subject to finalization of definitive agreements, among other factors, and TOTAL S.A. has no commitment to participate in the project. We expect that discussions on the potential expansion will continue among all the Cameron LNG JV members. There can be no assurance that a mutually agreeable expansion structure will be agreed upon unanimously by the Cameron LNG JV members, which if not accomplished in a timely manner, could materially and adversely impact the development of the expansion project. In light of this, we are unable to predict when we and/or Cameron LNG JV might be able to move forward on this expansion project.

The expansion of the Cameron LNG JV facilities beyond the first three trains is subject to a number of risks and uncertainties, including amending the Cameron LNG JV agreement among the partners, obtaining binding customer commitments, completing the required commercial agreements, securing and maintaining all necessary permits, approvals and consents, obtaining financing,

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reaching a final investment decision among the Cameron LNG JV partners, and other factors associated with the potential investment. See “Item 1A. Risk Factors” in the Annual Report.

Other LNG Liquefaction Development

Design, regulatory and commercial activities are ongoing for potential LNG liquefaction developments at our Port Arthur, Texas site and at Sempra Mexico’s ECA facility. For these development projects, we have met with potential customers and determined there is an interest in long-term contracts for LNG supplies beginning in the 2022 to 2025 time frame.

Port Arthur

Sempra LNG is developing a proposed natural gas liquefaction project on a greenfield site that it owns in the vicinity of Port Arthur, Texas located along the Sabine-Neches waterway.

In April 2019, the FERC approved the siting, construction and operation of the Port Arthur liquefaction facility, along with certain natural gas pipelines that could be used to supply feed gas to the liquefaction facility, assuming the project is completed.

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 project to be exported to all current and future FTA and non-FTA countries.

In June 2018, we selected Bechtel Corporation as the EPC contractor for the proposed Port Arthur liquefaction project. Bechtel Corporation is to perform the engineering, execution planning and related activities necessary to prepare, negotiate and finalize a definitive EPC contract for the project. The current arrangement with Bechtel Corporation does not commit any party to enter into a definitive EPC contract or otherwise participate in the project.

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. Under the agreement, LNG purchases by PGNiG from Port Arthur LNG will be made on a free-on-board basis, with PGNiG responsible for shipping the LNG from the Port Arthur terminal to the final destination. Port Arthur LNG will manage the gas pipeline transportation, liquefaction processing and cargo loading. The agreement is subject to certain conditions precedent, including Port Arthur LNG making a positive final investment decision.

Development of the Port Arthur LNG liquefaction project is subject to a number of risks and uncertainties, including obtaining additional 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 all necessary permits and approvals; obtaining financing and incentives; reaching a final investment decision; and other factors associated with the potential investment. See “Item 1A. Risk Factors” in the Annual Report.

Energía Costa Azul

We further discuss Sempra LNG’s participation in potential LNG liquefaction development at Sempra Mexico’s ECA facility above in “Sempra Mexico – Energía Costa Azul LNG Terminal.”

LITIGATION

We describe legal proceedings that could adversely affect our future performance in Note 11 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 “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.

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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 “Item 7A. Quantitative and Qualitative Disclosures about Market Risk” in the Annual Report.

INTEREST RATE RISK

The table below shows the nominal amount of debt:

NOMINAL AMOUNT OF DEBT(1)
(Dollars in millions)
	March 31, 2019						December 31, 2018
	Sempra Energy Consolidated		SDG&E		SoCalGas		Sempra Energy Consolidated		SDG&E		SoCalGas
Short-term:
California Utilities	$	428	$	238	$	190	$	547	$	291	$	256
Other	2,097		—		—		1,477		—		—
Long-term:
California Utilities fixed-rate	$	8,359	$	4,900	$	3,459	$	8,377	$	4,918	$	3,459
California Utilities variable-rate	78		78		—		78		78		—
Other fixed-rate	11,145		—		—		10,804		—		—
Other variable-rate	1,242		—		—		2,091		—		—

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

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 long-term debt. If weighted-average interest rates on short-term debt outstanding at March 31, 2019 increased or decreased by 10 percent, the change in earnings over the next 12-month period ended March 31, 2020 would be approximately $8 million. If interest rates increased or decreased by 10 percent on all variable-rate long-term debt at March 31, 2019, after considering the effects of interest rate swaps, the change in earnings over the next 12-month period ended March 31, 2020 would be approximately $3 million.

CREDIT RATINGS

The credit ratings of Sempra Energy, SDG&E and SoCalGas remained at investment grade levels in the first three months of 2019. At March 31, 2019:

▪ Moody’s issuer rating was Baa1 with a negative outlook for Sempra Energy, Baa1 with a negative outlook for SDG&E and A1 with a stable outlook for SoCalGas;

▪ S&P’s issuer credit rating was BBB+ with a negative outlook for Sempra Energy, BBB+ with a negative outlook for SDG&E and A with a negative outlook for SoCalGas; and

▪ Fitch Ratings’ long-term issuer default rating was BBB+ with a stable outlook for Sempra Energy, BBB+ with a negative outlook for SDG&E and A with a stable outlook for SoCalGas.

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Our credit ratings may affect the rates at which borrowings bear interest and the commitment fees on available unused credit. A downgrade of Sempra Energy’s or any of its subsidiaries’ credit ratings or rating outlooks may 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 Energy, SDG&E, SoCalGas and Sempra Energy’s other subsidiaries to issue debt securities, to borrow under credit facilities and to raise certain other types of financing.

We provide additional information about the credit ratings of Sempra Energy, SDG&E and SoCalGas in “Item 1A. Risk Factors” and “Item 7A. Quantitative and Qualitative Disclosures about Market Risk – Credit Ratings” in the Annual Report.

Sempra Energy 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 is rated A2, A+ and A at Moody’s, S&P and Fitch Ratings, respectively, at March 31, 2019.

FOREIGN CURRENCY AND INFLATION RATE RISK

We discuss our foreign currency and inflation exposure in “Item 2. MD&A – Impact of Foreign Currency and Inflation Rates on Results of Operations” herein and in “Item 7. MD&A – Impact of Foreign Currency and Inflation Rates on Results of Operations” in the Annual Report. At March 31, 2019, there were no significant changes to our exposure to foreign currency rate risk since December 31, 2018.

ITEM 4. CONTROLS AND PROCEDURES

EVALUATION OF DISCLOSURE CONTROLS AND PROCEDURES

Sempra Energy, SDG&E and SoCalGas have designed and maintain disclosure controls and procedures to ensure that information required to be disclosed in their respective reports 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 other possible controls and procedures.

Under the supervision and with the participation of management, including the principal executive officers and principal financial officers of Sempra Energy, SDG&E and SoCalGas, each company evaluated the effectiveness of the design and operation of its disclosure controls and procedures as of March 31, 2019, the end of the period covered by this report. Based on these evaluations, the principal executive officers and principal financial officers of Sempra Energy, SDG&E and SoCalGas concluded that their respective company’s disclosure controls and procedures were effective at the reasonable assurance level.

INTERNAL CONTROL OVER FINANCIAL REPORTING

There have been no changes in Sempra Energy’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, the companies’ internal control over financial reporting.

PART II – OTHER INFORMATION

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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 herein and in Notes 15 and 16 of the Notes to Consolidated Financial Statements in the Annual Report, or 2) referred to in “Item 7. MD&A” in the Annual Report.

ITEM 1A. RISK FACTORS

When evaluating our company and its subsidiaries, we urge you to carefully consider the risks and other information in this Quarterly Report on Form 10-Q, including the factors discussed above in “Item 2. MD&A” and the risk factors disclosed in “Item 1A. Risk Factors” in the Annual Report. There have been no material changes from the risk factors as previously disclosed in the Annual Report. Any of the risks and other information discussed in this Quarterly Report on Form 10-Q or any of the risks disclosed in “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 immaterial, could materially and 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.

ITEM 6. EXHIBITS

The following exhibits relate to each registrant as indicated.

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			Incorporated by Reference
Exhibit Number	Exhibit Description	Filed Herewith	Form	Period Ending	Exhibit	Filing Date
EXHIBIT 10 -- MATERIAL CONTRACTS
Sempra Energy/San Diego Gas & Electric Company/Southern California Gas Company
10.1	Form of Sempra Energy 2013 Long-Term Incentive Plan 2019 Nonqualified Stock Option Award Agreement.	X
10.2	Form of Sempra Energy 2013 Long-Term Incentive Plan 2019 Performance-Based Restricted Stock Unit Award - EPS Growth Performance Measure.	X
10.3	Form of Sempra Energy 2013 Long-Term Incentive Plan 2019 Performance-Based Restricted Stock Unit Award - Relative Total Shareholder Return Performance Measure - S&P 500 Index.	X
10.4	Form of Sempra Energy 2013 Long-Term Incentive Plan 2019 Performance-Based Restricted Stock Unit Award - Relative Total Shareholder Return Performance Measure - S&P 500 Utilities Index.	X
10.5	Form of Sempra Energy 2013 Long-Term Incentive Plan 2019 Special Time-Based Restricted Stock Unit Award - Ratable vesting.	X
10.6	Amended and Restated Sempra Energy 2005 Deferred Compensation Plan, now known as Sempra Energy Employee and Director Savings Plan.		10-K	12/31/2018	10.40	2/26/2019
Sempra Energy/Southern California Gas Company
10.7	Severance Pay Agreement between Sempra Energy and David J. Barrett, dated January 12, 2019.		10-K	12/31/2018	10.77	2/26/2019
San Diego Gas & Electric/Southern California Gas Company
10.8*	Severance Agreement and Mutual Release between San Diego Gas & Electric Company and Southern California Gas Company and P. Kevin Chase dated April 19, 2019.	X

* Certain sensitive personally identifiable information in this exhibit was omitted by means of redacting a portion of the text and replacing it with [***].

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Exhibit Number	Exhibit Description	Filed Herewith
EXHIBIT 31 -- SECTION 302 CERTIFICATIONS
Sempra Energy
31.1	Certification of Sempra Energy’s Principal Executive Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.	X
31.2	Certification of Sempra Energy’s Principal Financial Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.	X
San Diego Gas & Electric Company
31.3	Certification of San Diego Gas & Electric Company’s Principal Executive Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.	X
31.4	Certification of San Diego Gas & Electric Company’s Principal Financial Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.	X
Southern California Gas Company
31.5	Certification of Southern California Gas Company’s Principal Executive Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.	X
31.6	Certification of Southern California Gas Company’s Principal Financial Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.	X
EXHIBIT 32 -- SECTION 906 CERTIFICATIONS
Sempra Energy
32.1	Certification of Sempra Energy’s Principal Executive Officer pursuant to 18 U.S.C. Sec. 1350.	X
32.2	Certification of Sempra Energy’s Principal Financial Officer pursuant to 18 U.S.C. Sec. 1350.	X
San Diego Gas & Electric Company
32.3	Certification of San Diego Gas & Electric Company’s Principal Executive Officer pursuant to 18 U.S.C. Sec. 1350.	X
32.4	Certification of San Diego Gas & Electric Company’s Principal Financial Officer pursuant to 18 U.S.C. Sec. 1350.	X
Southern California Gas Company
32.5	Certification of Southern California Gas Company’s Principal Executive Officer pursuant to 18 U.S.C. Sec. 1350.	X
32.6	Certification of Southern California Gas Company’s Principal Financial Officer pursuant to 18 U.S.C. Sec. 1350.	X
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	XBRL Taxonomy Extension Schema Document	X
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document	X
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document	X
101.LAB	XBRL Taxonomy Extension Label Linkbase Document	X
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document	X

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SIGNATURES

Sempra Energy:
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
	SEMPRA ENERGY, (Registrant)
Date: May 7, 2019	By:  /s/ Peter R. Wall
	Peter R. Wall Vice President, Controller and Chief Accounting 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: May 7, 2019	By:  /s/ Bruce A. Folkmann
	Bruce A. Folkmann Vice President, Controller, Chief Financial Officer and Chief Accounting 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: May 7, 2019	By:  /s/ Bruce A. Folkmann
	Bruce A. Folkmann Vice President, Controller, Chief Financial Officer and Chief Accounting Officer

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EX-10.1

Exhibit 10.1

SEMPRA ENERGY

<YEAR> LONG TERM INCENTIVE PLAN

YEAR <YEAR> NONQUALIFIED STOCK OPTION AWARD

You have been granted a nonqualified option award representing the right to purchase the number of shares of Sempra Energy Common Stock set forth below, subject to the vesting conditions set forth below. The option may not be sold or assigned. The option will be subject to forfeiture unless and until it is vested in accordance with the attached Year <YEAR> Nonqualified Stock Option Award Agreement (the “Award Agreement”). The terms and conditions of your award are set forth in the attached Award Agreement and in the Sempra Energy <YEAR> Long Term Incentive Plan (the “Plan”), which has been provided to you. The summary below highlights selected terms and conditions but it is not complete and you should carefully read the attachments to fully understand the terms and conditions of your award.
	SUMMARY
Grant Date:		<DATE>, <YEAR>
Name of Optionee:		NAME
Optionee’s Employee Number:		EE ID
Number of Shares of Sempra Energy Common Stock Covered by Option:		# SHARES
Exercise Price per Share:		$TBD
Vesting/Forfeiture of Option: Subject to certain exceptions set forth in the Award Agreement, your option will vest (become exercisable) in three equal annual cumulative installments of one-third each over a three-year period. Once an installment becomes exercisable, it will remain exercisable until it is exercised or your option expires or terminates. Any portion of the option that does not vest will be forfeited.
Option Term:  Ten years subject to earlier expiration if your employment terminates.
Transfer Restrictions:
Your option may not be sold or otherwise transferred and will remain subject to forfeiture conditions until it vests, except as set forth herein.
Termination of Employment:
Subject to certain exceptions set forth in the Award Agreement, your option will expire and will cease to vest upon your termination of employment.
No Dividend Equivalents:
No dividend equivalents will be paid with respect to your option or the shares covered by your option.
Exercise of Option/Taxes:
You may exercise vested portions of the option in accordance with the Award Agreement. Upon exercise of your option you must pay (or make acceptable arrangements to pay) the exercise price for each share for which you exercise your option and any withholding taxes that may be due as a result of exercise.

By your acceptance of this award, you agree to all of the terms and conditions set forth in this Cover Page/Summary, the Award Agreement and the Plan. You will be deemed to have accepted this award unless you affirmatively reject the award in accordance with the procedures described herein or unless you fail to execute the Arbitration Agreement, if any, provided to you in connection with this award.

Sempra Energy:

Title:

2

SEMPRA ENERGY

<YEAR> LONG TERM INCENTIVE PLAN

YEAR <YEAR> NONQUALIFIED STOCK OPTION AWARD

Award:	You have been granted a nonqualified stock option award under Sempra Energy’s <YEAR> Long Term Incentive Plan (the “Plan”). The award consists of an option to purchase the number of shares of Sempra Energy Common Stock (“Common Stock”) set forth on the Cover Page/Summary to this Award Agreement. ˙Capitalized terms used in this Award Agreement and not defined shall have the meaning set forth in the Plan. Unless and until it is vested, your option will be subject to forfeiture and vesting conditions. Subject to the provisions below relating to the treatment of your option in connection with a Change in Control (as defined in the Plan), your option will vest as described herein. Subject to certain exceptions set forth herein, your option will also be forfeited if your employment terminates before it vests. See “Vesting/Forfeiture,” ”Termination of Employment” and “Transfer Restrictions” below.
Vesting/Forfeiture:	Your option vests (becomes exercisable) in equal annual cumulative installments over a three-year period. Each installment is one-third of the original number of shares covered by your option and an installment vests on each of the first three anniversaries of the Grant Date shown on the Cover Page/Summary to this Award Agreement. Once an installment of your option becomes exercisable, it will remain exercisable until it is exercised or your option expires. Any unvested portion of the option will be forfeited in accordance with this Award Agreement.
Term:	Your option will expire at the close of business at Sempra Energy headquarters on the day before the 10th anniversary of the Grant Date shown on the cover sheet and, except as otherwise provided, is subject to earlier expiration or termination (as described below) if your employment terminates.
Termination of Employment: Termination:	If your employment with Sempra Energy and its Subsidiaries terminates for any reason prior to the vesting of your option (other than under the circumstances set forth below), any unvested portion of your option will be forfeited effective immediately after your termination; provided, however, that the Compensation Committee in its sole discretion may determine that all or a portion of your option will not be forfeited but will be vested as of your termination of employment (subject to Code Section 409A requirements and the terms of the Plan). Except as provided below, the vested portion of your option will expire at the close of business at Sempra Energy’s headquarters on the 90th day after your employment terminates or, if earlier, on the ten-year expiration date of the option. The option will not continue to vest after your termination of employment except as provided below or as provided by the Compensation Committee and will be exercisable only as to the number of shares for which it was exercisable on the date of your termination.

	If your employment with Sempra Energy and its Subsidiaries terminates prior to a Change in Control, other than by termination for cause, and you had both completed at least five years of continuous service with Sempra Energy AND met any of the following conditions: 1.)    your employment terminates on or after December 31, <YEAR> and at the date of terminationyou had attained age 55; or 2.)    your employment terminates on or after November 30, <YEAR> and at the date of termination you had attained age 62; or 3.)    at the date of termination you had attained age 65 and you were an officer subject to the company’s mandatory retirement policy; your option will not be forfeited but will continue to be subject to the transfer restrictions and vesting conditions and other terms and conditions of this Award Agreement until the earlier of the ten-year expiration date of the option or the third anniversary of your termination date (fifth anniversary of your termination date if you were at least age 62 at the time of your termination). If your employment with Sempra Energy and its Subsidiaries terminates by reason of your death prior to the vesting of your option and your option would otherwise be forfeited (you do not meet the age and service conditions described above), the unvested portion of your option will not expire but will continue to be subject to the transfer restrictions and vesting conditions and other terms and conditions of this Award Agreement until the earlier of the ten-year expiration date of the option or the third anniversary of your death.
Termination for Cause:	If your employment with Sempra Energy and its Subsidiaries terminates for cause, or your employment would have been subject to termination for cause, prior to the vesting of your option, the unvested portion of your option will be forfeited and cancelled. Prior to the consummation of a Change in Control, a termination for cause is (i) the willful failure by you to substantially perform your duties with the Company (other than any such failure resulting from your incapacity due to physical or mental illness), (ii) the grossly negligent performance of such obligations referenced in clause (i) of this definition, (iii) your gross insubordination; and/or (iv) your commission of one or more acts of moral turpitude that constitute a violation of applicable law (including but not limited to a felony) which have or result in an adverse effect on the Company, monetarily or otherwise, or one or more significant acts of dishonesty. For purposes of clause (i), no act, or failure to act, on your part shall be deemed “willful” unless done, or omitted to be done, by you not in good faith and without reasonable belief that your act, or failure to act, was in the best interests of the Company. If your option remains outstanding following a Change in Control pursuant to a Replacement Award, a termination for cause following such Change in Control shall be determined in accordance with the provisions of the Plan that define “Cause”, including reasonable notice and, if possible, a reasonable opportunity to cure as provided therein.
Change in Control:	The terms of the Plan relating to treatment of awards in the event of a Change in Control shall apply to your option in the event of a Change in Control.
Restrictions on Exercise:	You will not be permitted to exercise your option at any time at which Sempra Energy determines that the issuance of shares may violate any law, regulation or Sempra Energy policy.

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Exercise of Option/Tax Withholding:	You may exercise your option, to the extent vested, prior to the date on which the option expires. Exercise shall be done in accordance with policies and procedures established by Sempra Energy. Upon exercise, Sempra Energy or its Subsidiary is required to withhold taxes. Unless you instruct otherwise and pay or make arrangements satisfactory to Sempra Energy to pay the exercise price and the taxes (which can be accomplished through a broker assisted cashless exercise), upon exercise, Sempra Energy will withhold a sufficient number of shares of common stock that you otherwise would be entitled to receive upon exercise to pay the exercise price for the shares with respect to which the option is exercised and to cover the minimum required withholding taxes and will transfer to you only the remaining balance of the shares with respect to which the option is exercised.
Transfer Restrictions:	Prior to your death, your option may only be exercised by you. You may not sell or otherwise transfer or assign your option. You may, however, dispose of your option in your will. If someone wants to exercise your option after your death, that person must prove to Sempra Energy’s satisfaction that he or she is entitled to do so.
Restrictions on Resale:	You agree not to sell any option shares at a time when applicable laws, regulations or Sempra Energy policies prohibit a sale.
Recoupment (“Clawback”) Policy:	The Company shall require the forfeiture, recovery or reimbursement of awards or compensation under the Plan and this award as (i) required by applicable law, or (ii) required under any policy implemented or maintained by the Company pursuant to any applicable rules or requirements of a national securities exchange or national securities association on which any securities of the Company are listed. The Company reserves the right to recoup compensation paid if it determines that the results on which the compensation was paid were not actually achieved. The Compensation Committee may, in its sole discretion, require the recovery or reimbursement of long-term incentive compensation awards from any employee whose fraudulent or intentional misconduct materially affects the operations or financial results of the Company or any of its Subsidiaries.
Retention Rights:	Neither your option nor this Award Agreement gives you the right to be retained by Sempra Energy or any of its Subsidiaries in any capacity and your employer reserves the right to terminate your employment at any time, with or without cause. The value of the shares subject to your option will not be included as compensation or earnings for purposes of any other benefit plan offered by Sempra Energy or any of its Subsidiaries.
No Shareholder Rights:	You have no rights as a shareholder of Sempra Energy until your option shares have been issued. No adjustments are made for dividends or other rights if the applicable record date occurs before your option shares are issued.
Nonqualified Stock Option:	This option is not intended to be an incentive stock option under section 422 of the Code.
Applicable Law:	This Award Agreement will be interpreted and enforced under the laws of the State of California.
Further Actions:	You agree to take all actions and execute all documents appropriate to carry out the provisions of this Award Agreement. You shall be deemed to have accepted this award unless you affirmatively reject it in writing addressed to the Corporate Secretary of the Company no later than March 31, <YEAR>; provided, however, that you shall not be deemed to have accepted this award if you fail to execute the Arbitration Agreement, if any, provided to you in connection with this award. You also appoint as your attorney-in-fact each individual who at the time of so acting is the Secretary or an Assistant Secretary of Sempra Energy with full authority to effect any transfer of any shares of Common Stock distributable to you pursuant to the option, including any transfer to pay withholding taxes, that is authorized by this Award Agreement.
Disputes:	Any and all disputes between you and the Company relating to or arising out of the Plan or your restricted stock unit award shall be subject to the Arbitration Agreement, if any, provided with this Award Agreement, including, but not limited to, any disputes referenced in the applicable provisions of the Plan.

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Other Agreements: In the event of any conflict between the terms of this Award Agreement and any written employment, severance or other employment-related agreement between you and Sempra Energy, the terms of this Award Agreement, or the terms of such other agreement, whichever are more favorable to you, shall prevail. In the event of a conflict between the terms of this Award Agreement and the Plan, the Plan document shall prevail.

By your acceptance of this award, you agree to all of the terms and conditions set forth in the Cover Page/Summary, this Award Agreement and the Plan. You will be deemed to have accepted this award unless you affirmatively reject the award in accordance with the procedures described herein or unless you fail to execute the Arbitration Agreement, if any, provided to you in connection with this award.

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EX-10.2

Exhibit 10.2

SEMPRA ENERGY

<YEAR>LONG TERM INCENTIVE PLAN

YEAR <YEAR> PERFORMANCE-BASED RESTRICTED STOCK UNIT AWARD

You have been granted a performance-based restricted stock unit award representing the right to receive the number of shares of Sempra Energy Common Stock set forth below, subject to the vesting conditions set forth below. The restricted stock units, and dividend equivalents with respect to the restricted stock units, under your award may not be sold or assigned. They will be subject to forfeiture unless and until they vest based upon the satisfaction of earnings per share performance criteria for the performance period beginning on January 1, <YEAR> and ending on December 31, <YEAR>. Shares of Common Stock will be distributed to you after the completion of the performance period ending on December 31, <YEAR> if, and to the extent that, the restricted stock units vest under the terms and conditions of your award. The terms and conditions of your award are set forth in the attached Year <YEAR> Performance-Based Restricted Stock Unit Award Agreement (the “Award Agreement”) and in the Sempra Energy <YEAR> Long Term Incentive Plan (the “Plan”), which has been provided to you. The summary below highlights selected terms and conditions but it is not complete and you should carefully read the attachments to fully understand the terms and conditions of your award.
	SUMMARY
Date of Award:	<DATE>, <YEAR>
Name of Recipient:	NAME
Recipient’s Employee Number:	EE ID
Number of Restricted Stock Units (prior to any dividend equivalents):
At Target:	# RSU
At Maximum:	200% of Target (e.g. 1,000 at Target = 2,000 at Maximum)
Award Date Fair Market Value per Share of Common Stock (Closing Stock Price on Date of Award):	$<PRICE>
Restricted Stock Units:
Your restricted stock units represent the right to receive shares of Common Stock in the future, subject to the terms and conditions of your award. Your restricted stock units are not shares of Common Stock. The target number of restricted stock units will vest (subject to adjustment as described below) if, and to the extent that, the Compensation Committee of Sempra Energy’s Board of Directors (the “Compensation Committee”) determines that the target “Earnings Per Share Growth” (as defined in the Award Agreement) has been achieved for the performance period. If above target Earnings Per Share Growth is achieved, you may vest in up to the maximum number of restricted stock units plus reinvested dividend equivalents as described below.
Vesting/Forfeiture of Restricted Stock Units:
Subject to certain exceptions set forth in the Award Agreement, your restricted stock units (including units attributable to reinvested dividend equivalents) will vest only in the event, and to the extent, that the Compensation Committee determines and certifies that Sempra Energy has met the specified Earnings Per Share Growth performance, as described below, for the performance period beginning on January 1, <YEAR> and ending December 31, <YEAR>. Any vesting will occur immediately following such determination and certification. Any restricted stock units that do not vest with the Compensation Committee's determination and certification (or otherwise in accordance with the Award Agreement) will be forfeited. All determinations of the Compensation Committee as to the level of Earnings Per Share Growth and the number of your restricted stock units (and accompanying dividend equivalents) that vest is final and binding.
Transfer Restrictions:
Your restricted stock units may not be sold or otherwise transferred and will remain subject to forfeiture conditions until they vest.
Termination of Employment:
Subject to certain exceptions set forth in the Award Agreement, your restricted stock units will be forfeited if your employment terminates.
Dividend Equivalents:

You also have been awarded dividend equivalents with respect to your restricted stock units. Your dividend equivalents represent the right to receive additional shares of Common Stock in the future, subject to the terms and conditions of your award. Your dividend equivalents will be determined based on the dividends that you would have received had you held shares of Common Stock equal to the vested number of your restricted stock units from the date of your award to the date of the distribution of shares of Common Stock following the vesting of your restricted stock units, and assuming that the dividends were reinvested in Common Stock (and any dividends on such shares were reinvested in Common Stock). The dividends will be deemed reinvested in Common Stock in the same manner as dividends reinvested pursuant to the terms of the Sempra Dividend Reinvestment Plan. Your dividend equivalents will be subject to the same transfer restrictions and forfeiture and vesting conditions as the shares represented by your restricted stock units.

Distribution of Shares:

Shares of Common Stock will be distributed to you to the extent your restricted stock units (and accompanying dividend equivalents) vest. Except as provided otherwise inthe Award Agreement, the shares will be distributed to you after the completion of the performance period ending on December 31, <YEAR> and the Compensation Committee’s determination and certification of Earnings Per Share Growth performance for the performance period. The shares of Common Stock will include the additional shares to be distributed pursuant to your vested dividend equivalents.

Taxes:

Upon distribution of shares of Common Stock to you, you will be subject to income taxes on the value of the distributed shares at the time of distribution and must pay applicable withholding taxes.

By your acceptance of this award, you agree to all of the terms and conditions set forth in this Cover Page/Summary, the Award Agreement and the Plan. You will be deemed to have accepted this award unless you affirmatively reject the award in accordance with the procedures described herein or unless you fail to execute the Arbitration Agreement, if any, provided to you in connection with this award.

Sempra Energy:

Title:

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SEMPRA ENERGY

<YEAR> LONG TERM INCENTIVE PLAN

Year <YEAR> Performance-Based Restricted Stock Unit Award Agreement

Award: You have been granted a performance-based restricted stock unit award under Sempra Energy’s <YEAR> Long Term Incentive Plan (the “Plan”). The award consists of the number of restricted stock units set forth on the Cover Page/Summary to this Award Agreement, and dividend equivalents with respect to the restricted stock units (described below). Capitalized terms used in this Award Agreement and not defined shall have the meaning set forth in the Plan. Your restricted stock units represent the right to receive shares of Common Stock in the future, subject to the terms and conditions of your award. Your restricted stock units are not shares of Common Stock. Each restricted stock unit initially represents the right to receive one share of Common Stock upon the vesting of the unit. Unless and until they vest, your restricted stock units and any dividend equivalents will be subject to transfer restrictions and forfeiture and vesting conditions. Subject to the provisions below relating to the treatment of your restricted stock units in connection with a Change in Control, your restricted stock units (and dividend equivalents) will vest only in the event, and only to the extent, that the Compensation Committee of Sempra Energy's Board of Directors (the “Compensation Committee”) determines and certifies that Sempra Energy has met the Earnings Per Share Growth performance for the performance period beginning January 1, <YEAR> and ending on December 31, <YEAR> as described below. Any restricted stock units (and dividend equivalents) that do not vest will be forfeited. Subject to certain exceptions set forth herein, your restricted stock units (and dividend equivalents) will be forfeited if your employment terminates before they vest; provided, however, that the Compensation Committee, in its sole discretion, may determine that all or a portion of such restricted stock units (and dividend equivalents) will not be forfeited but will continue to be subject to transfer restrictions and other vesting conditions applicable under this Award Agreement (subject to Code Section 409A requirements and the terms of the Plan). See “Vesting/Forfeiture,” “Transfer Restrictions,” and “Termination of Employment” below.

Vesting/Forfeiture: Subject to the provisions below relating to the treatment of your restricted stock units in connection with a Change in Control, your restricted stock units (and dividend equivalents) will vest only in the event, and to the extent, that the Compensation Committee determines and certifies that the Earnings Per Share Growth performance for the performance period has been met. Any vesting will occur immediately following such determination and certification. THE COMPENSATION COMMITTEE RETAINS SOLE AND EXCLUSIVE AUTHORITY TO DETERMINE THE LEVEL OF EARNINGS PER SHARE GROWTH AND THE NUMBER OF YOUR RESTRICTED STOCK UNITS (AND ACCOMPANYING DIVIDEND EQUIVALENTS) THAT VEST. THE DETERMINATION OF THE COMPENSATION COMMITTEE AS TO ALL MATTERS RELATING TO THIS AWARD IS FINAL AND BINDING. Earnings Per Share Growth is determined based upon the compound annual growth rate (CAGR) of Sempra Energy’s fiscal <YEAR> and fiscal <YEAR> earnings per share, subject to adjustments by the Compensation Committee in its sole discretion. For purposes of this calculation, (i) the starting point to calculate Earnings Per Share Growth shall be Sempra Energy’s <YEAR> earnings per share, (ii) the ending point to calculate Earnings Per Share Growth shall be Sempra Energy’s <YEAR> earnings per share and (iii) earnings per share shall be calculated using weighted average shares outstanding (WASO) for fiscal <YEAR> and fiscal <YEAR>, as diluted to reflect outstanding stock options and RSUs (Diluted WASO). For fiscal <YEAR>, earnings per share shall exclude the effect of any common stock buybacks not contemplated in Sempra Energy’s most recent financial plans publicly communicated prior to the Date of Award. For the avoidance of doubt, Diluted WASO shall include the impact of any compensation or incentive plan transactions that reduce diluted WASO including, without limitation, transactions from tax withholding obligations and expirations or forfeitures of stock options and restricted stock units. The calculation of the Earnings component of Earnings Per Share is intended to be consistent with the calculation of Earnings under the Sempra Energy annual incentive plans. Adjustments to Earnings are intended to be generally consistent with the adjustments applied under the Sempra Energy annual incentive plans, but the Compensation Committee, in its sole discretion, shall determine what adjustments shall apply for purposes of calculating Earnings Per Share Growth. The Compensation Committee in its sole discretion shall determine the extent to which the Earnings Per Share Growth performance has been achieved and the number of restricted stock units (and accompanying dividend equivalents) that vest. The percentage of your target number of restricted stock units that vest will be determined as follows:

Earnings Per Share Growth <YEAR> - <YEAR>	Percentage of Target Number of Restricted Stock Units that Vest
<PERCENTAGE>	200%
<PERCENTAGE>	150%
<PERCENTAGE>	100%
<PERCENTAGE>	0%

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	If Earnings Per Share Growth as determined by the Compensation Committee does not equal a growth rate level shown in the above table, the percentage of your target number of restricted stock units that vest will be determined by a linear interpolation between the next lowest percentage shown in the table and the next highest percentage shown on the table. If the Earnings Per Share Growth is at or above <PERCENTAGE>, 200% of your target number of restricted stock units will vest. If the Earnings Per Share Growth is at or below <PERCENTAGE>, none of your restricted stock units will vest. As soon as reasonably practicable following the end of the performance period, the Compensation Committee will determine and certify the extent to which Sempra Energy has met the Earnings Per Share Growth performance and the extent to which, if any, your restricted stock units have then vested and any such vesting shall occur immediately following such determination and certification by the Compensation Committee. You will receive the number of shares of Common Stock equal to the number of your vested restricted stock units after the Compensation Committee’s determination and certification. Also, you will receive the number of shares of Common Stock equal to your vested dividend equivalents after the Compensation Committee’s determination and certification. Certificates for the shares will be transferred to your brokerage account unless you specifically instruct otherwise. When the shares of Common Stock are issued to you, your restricted stock units (vested and unvested) and your dividend equivalents will terminate.
Transfer Restrictions:	You may not sell or otherwise transfer or assign your restricted stock units (or your dividend equivalents).
Dividend Equivalents:	You also have been awarded dividend equivalents with respect to your restricted stock units. Your dividend equivalents represent the right to receive additional shares of Common Stock in the future, subject to the terms and conditions of your award. Your dividend equivalents will be determined based on the dividends that you would have received had you held shares of Common Stock equal to the vested number of your restricted stock units from the date of your award to the date of the distribution of shares of Common Stock following the vesting of your restricted stock units, and assuming that the dividends were reinvested in Common Stock (and any dividends on such shares were reinvested in Common Stock). The dividends will be deemed reinvested in Common Stock in the same manner as dividends reinvested pursuant to the terms of the Sempra Dividend Reinvestment Plan. Your dividend equivalents will be subject to the same transfer restrictions and forfeiture and vesting conditions as your restricted stock units. They will vest when and to the extent that your restricted stock units vest. Also, your restricted stock units (and dividend equivalents), including the terms and conditions thereof, will be adjusted to prevent dilution or enlargement of your rights in the event of a stock dividend on shares of Common Stock or as the result of a stock-split, recapitalization, reorganization or other similar transaction in accordance with the terms and conditions of the Plan. Any additional restricted stock units (and dividend equivalents) awarded to you as a result of such an adjustment also will be subject to the same transfer restrictions, forfeiture and vesting conditions and other terms and conditions that are applicable to your restricted stock units (and dividend equivalents).
No Shareholder Rights:	Your restricted stock units (and dividend equivalents) are not shares of Common Stock. You will have no rights as a shareholder unless and until shares of Common Stock are issued to you following the vesting of your restricted stock units (and dividend equivalents) as provided in this Award Agreement and the Plan.

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Distribution of Shares: As described in “Vesting/Forfeiture” above, the Compensation Committee will determine and certify the extent to which Sempra Energy has met the performance criteria and the extent, if any, as to which your restricted stock units (and dividend equivalents) have then vested in accordance with the terms of the award. You will receive the number of shares of Common Stock equal to the number of your restricted stock units that have vested. However, in no event will you receive under this award, and other awards granted to you under the Plan in the same fiscal year of Sempra Energy, more than the maximum number of shares of Common Stock permitted under the Plan. Also, you will receive the number of shares of Common Stock equal to your vested dividend equivalents after the Compensation Committee’s determination and certification. You will receive the shares as soon as reasonably practicable following the Compensation Committee’s determination and certification (and in no event later than March 15, <YEAR>). Once you receive the shares of Common Stock, your vested and unvested restricted stock units (and dividend equivalents) will terminate.

Termination of Employment:

Termination:

If your employment with Sempra Energy and its Subsidiaries terminates for any reason prior to the vesting of your restricted stock units (and dividend equivalents) (other than under the circumstances set forth in the following provisions of this section), all of your restricted stock units (and dividend equivalents) will be forfeited. Subject to the provisions below relating to the treatment of your restricted stock units in connection with a Change in Control, the vesting of your restricted stock units (and dividend equivalents) does not occur until the date of the Compensation Committee’s determination and certification described above. If your employment terminates prior to a Change in Control, other than by termination for cause, and you had both completed at least five years of continuous service with Sempra Energy and its Subsidiaries AND met any of the following conditions: 1.)    your employment terminates on or after December 31, <YEAR> andat the date of terminationyou had attained age 55; or 2.)    your employment terminates on or after November 30, <YEAR> and at the date of termination you had attained age 62; or 3.)    at the date of termination you had attained age 65 and you were an officer subject to the company’s mandatory retirement policy; your restricted stock units (and dividend equivalents) will not be forfeited but will continue to be subject to the transfer restrictions and vesting conditions and other terms and conditions of this Award Agreement (subject to Code Section 409A requirements and the terms of the Plan). If your employment terminates by reason of your death prior to the vesting of your restricted stock units and your award would otherwise be forfeited (for example, you do not meet the age and service conditions described above), your award will be deemed forfeited immediately prior to the date and time it would otherwise vest, unless, and to the extent that, prior to the date and time that the restricted stock units would otherwise vest, the Compensation Committee, in its sole discretion, takes action to waive the service requirement described above. If your employment terminates and your restricted stock units (and dividend equivalents) would otherwise be forfeited, the Compensation Committee, in its sole discretion, may determine prior to such termination that all or a portion of such restricted stock units (and dividend equivalents) will not be forfeited but will continue to be subject to the transfer restrictions and vesting conditions and other terms and conditions of this Award Agreement (subject to Code Section 409A requirements and the terms of the Plan).

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Termination for Cause:	If your employment with Sempra Energy and its Subsidiaries terminates for cause, or your employment would have been subject to termination for cause, prior to the vesting of your restricted stock units (and dividend equivalents), all of your restricted stock units (and dividend equivalents) will be forfeited. Prior to the consummation of a Change in Control, a termination for cause is (i) the willful failure by you to substantially perform your duties with the Company (other than any such failure resulting from your incapacity due to physical or mental illness), (ii) the grossly negligent performance of such obligations referenced in clause (i) of this definition, (iii) your gross insubordination; and/or (iv) your commission of one or more acts of moral turpitude that constitute a violation of applicable law (including but not limited to a felony) which have or result in an adverse effect on the Company, monetarily or otherwise, or one or more significant acts of dishonesty. For purposes of clause (i), no act, or failure to act, on your part shall be deemed “willful” unless done, or omitted to be done, by you not in good faith and without reasonable belief that your act, or failure to act, was in the best interests of the Company. If your restricted stock units remain outstanding following a Change in Control pursuant to a Replacement Award, a termination for cause following such Change in Control shall be determined in accordance with the provisions of the Plan that define “Cause”, including reasonable notice and, if possible, a reasonable opportunity to cure as provided therein.
Taxes:
Withholding Taxes:	When you become subject to withholding taxes upon distribution of the shares of Common Stock or otherwise, Sempra Energy or its Subsidiary is required to withhold taxes. Unless you instruct otherwise and pay or make arrangements satisfactory to Sempra Energy to pay these taxes, upon the distribution of your shares, Sempra Energy will withhold a sufficient number of shares of common stock that you would otherwise be entitled to receive to cover the minimum required withholding taxes and transfer to you only the remaining balance of your shares. In the event that, following a Change in Control, your restricted stock units become eligible for a distribution upon your Retirement by reason of your combined age and service, your restricted stock units may become subject to employment tax withholding prior to the distribution of shares with respect to such units.
Code Section 409A:	Your restricted stock units are subject to provisions of the Plan which set forth terms to comply with Code Section 409A.
Recoupment (“Clawback”) Policy:	The Company shall require the forfeiture, recovery or reimbursement of awards or compensation under the Plan and this award as (i) required by applicable law, or (ii) required under any policy implemented or maintained by the Company pursuant to any applicable rules or requirements of a national securities exchange or national securities association on which any securities of the Company are listed. The Company reserves the right to recoup compensation paid if it determines that the results on which the compensation was paid were not actually achieved. The Compensation Committee may, in its sole discretion, require the recovery or reimbursement of long-term incentive compensation awards from any employee whose fraudulent or intentional misconduct materially affects the operations or financial results of the Company or its Subsidiaries.

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Retention Rights:	Neither your restricted stock unit award nor this Award Agreement gives you any right to be retained by Sempra Energy or any of its Subsidiaries in any capacity and your employer reserves the right to terminate your employment at any time, with or without cause. The value of your award will not be included as compensation or earnings for purposes of any other benefit plan offered by Sempra Energy or any of its Subsidiaries.
Change in Control:	In the event of a Change in Control, the following terms shall apply: §If (i) you have achieved age 55 and have completed at least five years of continuous service with Sempra Energy and its Subsidiaries as of the date of a Change in Control and your restricted stock units have not been forfeited prior to the Change in Control, (ii) your outstanding restricted stock units as of the date of a Change in Control are not subject to a “substantial risk of forfeiture” within the meaning of Code Section 409A and/or (iii) your outstanding restricted stock units are not assumed or substituted with one or more Replacement Awards (as defined in the Plan), then in each case your outstanding restricted stock units and any associated dividend equivalents will vest immediately prior to the Change in Control with the applicable performance goals deemed to have been achieved at the greater of target level as of the date of such vesting or the actual performance level had the performance period ended on the last day of the calendar year immediately preceding the date of the Change in Control. If the foregoing terms apply, immediately prior to the date of the Change in Control you will receive a number of shares of Common Stock equal to the number of your restricted stock units and dividend equivalents that have vested. §If your outstanding restricted stock awards are assumed or substituted with one or more Replacement Awards, then, except as provided otherwise in an individual severance agreement or employment agreement to which you are a party, the terms set forth in the Plan shall apply with respect to such Replacement Award following the Change in Control. If the foregoing terms apply and the Replacement Award vests upon your separation from service or death, on such date, you will receive a number of shares or other property in settlement of the Replacement Awards.
Further Actions:	You agree to take all actions and execute all documents appropriate to carry out the provisions of this Award Agreement. You shall be deemed to have accepted this award unless you affirmatively reject it in writing addressed to the Corporate Secretary of the Company no later than March 31, <YEAR>; provided, however, that you shall not be deemed to have accepted this award if you fail to execute the Arbitration Agreement, if any, provided to you in connection with this award. You also appoint as your attorney-in-fact each individual who at the time of so acting is the Secretary or an Assistant Secretary of Sempra Energy with full authority to effect any transfer of any shares of Common Stock distributable to you, including any transfer to pay withholding taxes, that is authorized by this Award Agreement.
Applicable Law:	This Award Agreement will be interpreted and enforced under the laws of the State of California.
Disputes:	Any and all disputes between you and the Company relating to or arising out of the Plan or your restricted stock unit award shall be subject to the Arbitration Agreement, if any, provided with this Award Agreement, including, but not limited to, any disputes referenced in the applicable provisions of the Plan.
Other Agreements:	In the event of any conflict between the terms of this Award Agreement and any written employment, severance or other employment-related agreement between you and Sempra Energy, the terms of this Award Agreement, or the terms of such other agreement, whichever are more favorable to you, shall prevail, provided that in each case a conflict shall be resolved in a manner consistent with the intent that your restricted stock units comply with Code Section 409A. In the event of a conflict between the terms of this Award Agreement and the Plan, the Plan document shall prevail.

By your acceptance of this award, you agree to all of the terms and conditions set forth in the Cover Page/Summary, this Award Agreement and the Plan. You will be deemed to have accepted this award unless you affirmatively reject the award in accordance with the procedures described herein or unless you fail to execute the Arbitration Agreement, if any, provided to you in connection with this award.

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EX-10.3

Exhibit 10.3

SEMPRA ENERGY

<YEAR> LONG TERM INCENTIVE PLAN

YEAR <YEAR> PERFORMANCE-BASED RESTRICTED STOCK UNIT AWARD

You have been granted a performance-based restricted stock unit award representing the right to receive the number of shares of Sempra Energy Common Stock set forth below, subject to the vesting conditions set forth below. The restricted stock units, and dividend equivalents with respect to the restricted stock units, under your award may not be sold or assigned. They will be subject to forfeiture unless and until they vest based upon the satisfaction of total shareholder return performance criteria for the S&P 500 Index for the performance period beginning on January 1, <YEAR> and ending on the close of trading on the first New York Stock Exchange trading day of <YEAR> [or such other performance period beginning and ending on the dates determined by the Compensation Committee]. Shares of Common Stock will be distributed to you after the completion of the performance period ending on <DATE>, <YEAR> if, and to the extent that, the restricted stock units vest under the terms and conditions of your award. The terms and conditions of your award are set forth in the attached Year <YEAR> Performance-Based Restricted Stock Unit Award Agreement (the “Award Agreement”) and in the Sempra Energy <YEAR> Long Term Incentive Plan (the “Plan”), which has been provided to you. The summary below highlights selected terms and conditions but it is not complete and you should carefully read the attachments to fully understand the terms and conditions of your award.
		SUMMARY
Date of Award:	<DATE>, <YEAR>
Name of Recipient:	NAME
Recipient’s Employee Number:	EE ID
Number of Restricted Stock Units (prior to any dividend equivalents):
At Target:	# RSU
At Maximum:	200% of Target (e.g. 1,000 at Target = 2,000 at Maximum)
Award Date Fair Market Value per Share of Common Stock (Closing Stock Price on Date of Award):	$<PRICE>
Restricted Stock Units:
Your restricted stock units represent the right to receive shares of Common Stock in the future, subject to the terms and conditions of your award. Your restricted stock units are not shares of Common Stock. The target number of restricted stock units will vest (subject to adjustment as described below) if, and to the extent that, the Compensation Committee of Sempra Energy’s Board of Directors (the “Compensation Committee”) determines that the target total shareholder return (a return at the 50th percentile) as described in the Award Agreement has been achieved for the performance period. If above target total shareholder return is achieved, you may vest in up to the maximum number of restricted stock units plus reinvested dividend equivalents as described below.
Vesting/Forfeiture of Restricted Stock Units:
Subject to certain exceptions set forth in the Award Agreement, your restricted stock units (including units attributable to reinvested dividend equivalents) will vest only in the event, and to the extent, that the Compensation Committee determines and certifies that Sempra Energy has met the specified total shareholder return performance criteria for the performance period beginning on January 1, <YEAR> and ending on the close of trading on the first New York Stock Exchange trading day of <YEAR> [or such other performance period beginning and ending on the dates determined by the Compensation Committee]. Any vesting will occur immediately following such determination and certification. Any restricted stock units that do not vest with the Compensation Committee's determination and certification (or otherwise in accordance with the Award Agreement) will be forfeited. All determinations of the Compensation Committee as to total shareholder return (as described below) and the number of your restricted stock units (and accompanying dividend equivalents) that vest is final and binding.
Transfer Restrictions:
Your restricted stock units may not be sold or otherwise transferred and will remain subject to forfeiture conditions until they vest.

Termination of Employment:

Subject to certain exceptions set forth in the Award Agreement, your restricted stock units will be forfeited if your employment terminates.

Dividend Equivalents:

You also have been awarded dividend equivalents with respect to your restricted stock units. Your dividend equivalents represent the right to receive additional shares of Common Stock in the future, subject to the terms and conditions of your award. Your dividend equivalents will be determined based on the dividends that you would have received had you held shares of Common Stock equal to the vested number of your restricted stock units from the date of your award to the date of the distribution of shares of Common Stock following the vesting of your restricted stock units, and assuming that the dividends were reinvested in Common Stock (and any dividends on such shares were reinvested in Common Stock). The dividends will be deemed reinvested in Common Stock in the same manner as dividends reinvested pursuant to the terms of the Sempra Dividend Reinvestment Plan. Your dividend equivalents will be subject to the same transfer restrictions and forfeiture and vesting conditions as the shares represented by your restricted stock units.

Distribution of Shares:

Shares of Common Stock will be distributed to you to the extent your restricted stock units (and accompanying dividend equivalents) vest. Except as provided otherwise inthe Award Agreement, the shares will be distributed to you after the completion of the performance period ending on the close of trading on the first New York Stock Exchange trading day of <YEAR> [or the end of the performance period determined by the Compensation Committee] and the Compensation Committee’s determination and certification of Sempra Energy’s total shareholder return for the performance period. The shares of Common Stock will include the additional shares to be distributed pursuant to your vested dividend equivalents.

Taxes:

Upon distribution of shares of Common Stock to you, you will be subject to income taxes on the value of the distributed shares at the time of distribution and must pay applicable withholding taxes.

By your acceptance of this award, you agree to all of the terms and conditions set forth in this Cover Page/Summary, the Award Agreement and the Plan. You will be deemed to have accepted this award unless you affirmatively reject the award in accordance with the procedures described herein or unless you fail to execute the Arbitration Agreement, if any, provided to you in connection with this award.

Sempra Energy:

Title:

2

SEMPRA ENERGY

<YEAR> LONG TERM INCENTIVE PLAN

Year <YEAR> Performance-Based Restricted Stock Unit Award Agreement

Award: You have been granted a performance-based restricted stock unit award under Sempra Energy’s <YEAR> Long Term Incentive Plan (the “Plan”). The award consists of the number of restricted stock units set forth on the Cover Page/Summary to this Award Agreement, and dividend equivalents with respect to the restricted stock units (described below). Capitalized terms used in this Award Agreement and not defined shall have the meaning set forth in the Plan. Your restricted stock units represent the right to receive shares of Common Stock in the future, subject to the terms and conditions of your award. Your restricted stock units are not shares of Common Stock. Each restricted stock unit initially represents the right to receive one share of Common Stock upon the vesting of the unit. Unless and until they vest, your restricted stock units and any dividend equivalents will be subject to transfer restrictions and forfeiture and vesting conditions. Subject to the provisions below relating to the treatment of your restricted stock units in connection with a Change in Control, your restricted stock units (and dividend equivalents) will vest only in the event, and only to the extent, that the Compensation Committee of Sempra Energy's Board of Directors (the “Compensation Committee”) determines and certifies that Sempra Energy has met specified total shareholder return criteria for the performance period beginning January 1, <YEAR> and ending on the close of trading on the first New York Stock Exchange trading day of <YEAR> [or such other performance period beginning and ending on the dates determined by the Compensation Committee]. Any restricted stock units (and dividend equivalents) that do not vest will be forfeited. Subject to certain exceptions set forth herein, your restricted stock units (and dividend equivalents) will be forfeited if your employment terminates before they vest; provided, however, that the Compensation Committee, in its sole discretion, may determine that all or a portion of such restricted stock units (and dividend equivalents) will not be forfeited but will continue to be subject to transfer restrictions and other vesting conditions applicable under this Award Agreement (subject to Code Section 409A requirements and the terms of the Plan). See “Vesting/Forfeiture,” “Transfer Restrictions,” and “Termination of Employment” below.

Vesting/Forfeiture: Subject to the provisions below relating to the treatment of your restricted stock units in connection with a Change in Control, your restricted stock units (and dividend equivalents) will vest only in the event, and to the extent, that the Compensation Committee determines and certifies that Sempra Energy has met the following total shareholder return performance criteria for the performance period beginning on January 1, <YEAR> and ending on the close of trading on the first New York Stock Exchange trading day of <YEAR> [or such other performance period beginning and ending on the dates determined by the Compensation Committee]. Any vesting will occur immediately following such determination and certification. THE DETERMINATION OF THE COMPENSATION COMMITTEE AS TO TOTAL SHAREHOLDER RETURN PERFORMANCE AND THE NUMBER OF RESTRICTED STOCK UNITS (AND ACCOMPANYING DIVIDEND EQUIVALENTS) THAT VEST IS FINAL AND BINDING. §The percentage of your target number of restricted stock units that vest will be determined as follows, based on the percentile ranking for the performance period (as measured based on the thirty-day average closing stock price immediately preceding the start of the performance period compared to the thirty-day average closing stock price immediately preceding the end of the performance period) of Sempra Energy’s cumulative total shareholder return (consisting of per share appreciation in Common Stock plus reinvested dividends and other distributions paid on Common Stock) among the companies (ranked by cumulative total shareholder returns) in the S&P 500 Index, as determined and certified by the Compensation Committee, subject to adjustment as described below. For the avoidance of doubt, the thirty-day average preceding the beginning of the performance period shall be based on the thirty calendar days prior to and excluding January 1, <YEAR> and the thirty day average preceding the end of the performance period shall be based on the thirty calendar days prior to and including the first NYSE trading day of <YEAR> [or such other performance period beginning and ending on the dates determined by the Compensation Committee].

Sempra Energy Total Shareholder Return Percentile Ranking	Percentage of Target Number of Restricted Stock Units that Vest
90th	200%
80th	175%
70th	150%
60th	125%
50th	100%
40th	70%
35th	55%
30th	40%
25th	0%

2

	If the percentile ranking does not equal a ranking shown in the above table, the percentage of your target number of restricted stock units that vest will be determined by a linear interpolation between the next lowest percentile shown in the table and the next highest percentile shown on the table. o    If the percentile ranking is at or above the 90th percentile, 200% of your target number of restricted stock units will vest. o    If the percentile ranking is at or below the 25th percentile, none of your restricted stock units will vest. As soon as reasonably practicable following the end of the performance period, the Compensation Committee will determine and certify the extent to which Sempra Energy has met the total shareholder return performance criteria and the extent to which, if any, your restricted stock units have then vested and any such vesting shall occur immediately following such determination and certification by the Compensation Committee. You will receive the number of shares of Common Stock equal to the number of your vested restricted stock units after the Compensation Committee’s determination and certification. Also, you will receive the number of shares of Common Stock equal to your vested dividend equivalents after the Compensation Committee’s determination and certification. Certificates for the shares will be transferred to your brokerage account unless you specifically instruct otherwise. When the shares of Common Stock are issued to you, your restricted stock units (vested and unvested) and your dividend equivalents will terminate.
Transfer Restrictions:	You may not sell or otherwise transfer or assign your restricted stock units (or your dividend equivalents).
Dividend Equivalents:	You also have been awarded dividend equivalents with respect to your restricted stock units. Your dividend equivalents represent the right to receive additional shares of Common Stock in the future, subject to the terms and conditions of your award. Your dividend equivalents will be determined based on the dividends that you would have received had you held shares of Common Stock equal to the vested number of your restricted stock units from the date of your award to the date of the distribution of shares of Common Stock following the vesting of your restricted stock units, and assuming that the dividends were reinvested in Common Stock (and any dividends on such shares were reinvested in Common Stock). The dividends will be deemed reinvested in Common Stock in the same manner as dividends reinvested pursuant to the terms of the Sempra Dividend Reinvestment Plan. Your dividend equivalents will be subject to the same transfer restrictions and forfeiture and vesting conditions as your restricted stock units. They will vest when and to the extent that your restricted stock units vest. Also, your restricted stock units (and dividend equivalents), including the terms and conditions thereof, will be adjusted to prevent dilution or enlargement of your rights in the event of a stock dividend on shares of Common Stock or as the result of a stock-split, recapitalization, reorganization or other similar transaction in accordance with the terms and conditions of the Plan. Any additional restricted stock units (and dividend equivalents) awarded to you as a result of such an adjustment also will be subject to the same transfer restrictions, forfeiture and vesting conditions and other terms and conditions that are applicable to your restricted stock units (and dividend equivalents).
No Shareholder Rights:	Your restricted stock units (and dividend equivalents) are not shares of Common Stock. You will have no rights as a shareholder unless and until shares of Common Stock are issued to you following the vesting of your restricted stock units (and dividend equivalents) as provided in this Award Agreement and the Plan.

3

Distribution of Shares:	As described in “Vesting/Forfeiture” above, the Compensation Committee will determine and certify the extent to which Sempra Energy has met the performance criteria and the extent, if any, as to which your restricted stock units (and dividend equivalents) have then vested in accordance with the terms of the award. You will receive the number of shares of Common Stock equal to the number of your restricted stock units that have vested. However, in no event will you receive under this award, and other awards granted to you under the Plan in the same fiscal year of Sempra Energy, more than the maximum number of shares of Common Stock permitted under the Plan. Also, you will receive the number of shares of Common Stock equal to your vested dividend equivalents after the Compensation Committee’s determination and certification. You will receive the shares as soon as reasonably practicable following the Compensation Committee’s determination and certification (and in no event later than March 15, <YEAR>). Once you receive the shares of Common Stock, your vested and unvested restricted stock units (and dividend equivalents) will terminate.
Termination of Employment:
Termination:	If your employment with Sempra Energy and its Subsidiaries terminates for any reason prior to the vesting of your restricted stock units (and dividend equivalents) (other than under the circumstances set forth in the following provisions of this section), all of your restricted stock units (and dividend equivalents) will be forfeited. Subject to the provisions below relating to the treatment of your restricted stock units in connection with a Change in Control, the vesting of your restricted stock units (and dividend equivalents) does not occur until the date of the Compensation Committee’s determination and certification described above. If your employment terminates prior to a Change in Control, other than by termination for cause, and you had both completed at least five years of continuous service with Sempra Energy and its Subsidiaries AND met any of the following conditions: 1.)    your employment terminates on or after December 31, <YEAR> andat the date of terminationyou had attained age 55; or 2.)    your employment terminates on or after November 30, <YEAR> and at the date of termination you had attained age 62; or 3.)    at the date of termination you had attained age 65 and you were an officer subject to the company’s mandatory retirement policy; your restricted stock units (and dividend equivalents) will not be forfeited but will continue to be subject to the transfer restrictions and vesting conditions and other terms and conditions of this Award Agreement (subject to Code Section 409A requirements and the terms of the Plan). If your employment terminates by reason of your death prior to the vesting of your restricted stock units and your award would otherwise be forfeited (for example, you do not meet the age and service conditions described above), your award will be deemed forfeited immediately prior to the date and time it would otherwise vest, unless, and to the extent that, prior to the date and time that the restricted stock units would otherwise vest, the Compensation Committee, in its sole discretion, takes action to waive the service requirement described above. If your employment terminates and your restricted stock units (and dividend equivalents) would otherwise be forfeited, the Compensation Committee, in its sole discretion, may determine prior to such termination that all or a portion of such restricted stock units (and dividend equivalents) will not be forfeited but will continue to be subject to the transfer restrictions and vesting conditions and other terms and conditions of this Award Agreement (subject to Code Section 409A requirements and the terms of the Plan).

4

Termination for Cause:	If your employment with Sempra Energy and its Subsidiaries terminates for cause, or your employment would have been subject to termination for cause, prior to the vesting of your restricted stock units (and dividend equivalents), all of your restricted stock units (and dividend equivalents) will be forfeited. Prior to the consummation of a Change in Control, a termination for cause is (i) the willful failure by you to substantially perform your duties with the Company (other than any such failure resulting from your incapacity due to physical or mental illness), (ii) the grossly negligent performance of such obligations referenced in clause (i) of this definition, (iii) your gross insubordination; and/or (iv) your commission of one or more acts of moral turpitude that constitute a violation of applicable law (including but not limited to a felony) which have or result in an adverse effect on the Company, monetarily or otherwise, or one or more significant acts of dishonesty. For purposes of clause (i), no act, or failure to act, on your part shall be deemed “willful” unless done, or omitted to be done, by you not in good faith and without reasonable belief that your act, or failure to act, was in the best interests of the Company. If your restricted stock units remain outstanding following a Change in Control pursuant to a Replacement Award, a termination for cause following such Change in Control shall be determined in accordance with the provisions of the Plan that define “Cause”, including reasonable notice and, if possible, a reasonable opportunity to cure as provided therein.
Taxes:
Withholding Taxes:	When you become subject to withholding taxes upon distribution of the shares of Common Stock or otherwise, Sempra Energy or its Subsidiary is required to withhold taxes. Unless you instruct otherwise and pay or make arrangements satisfactory to Sempra Energy to pay these taxes, upon the distribution of your shares, Sempra Energy will withhold a sufficient number of shares of common stock that you would otherwise be entitled to receive to cover the minimum required withholding taxes and transfer to you only the remaining balance of your shares. In the event that, following a Change in Control, your restricted stock units become eligible for a distribution upon your Retirement by reason of your combined age and service, your restricted stock units may become subject to employment tax withholding prior to the distribution of shares with respect to such units.
Code Section 409A:	Your restricted stock units are subject to provisions of the Plan which set forth terms to comply with Code Section 409A.
Recoupment (“Clawback”) Policy:	The Company shall require the forfeiture, recovery or reimbursement of awards or compensation under the Plan and this award as (i) required by applicable law, or (ii) required under any policy implemented or maintained by the Company pursuant to any applicable rules or requirements of a national securities exchange or national securities association on which any securities of the Company are listed. The Company reserves the right to recoup compensation paid if it determines that the results on which the compensation was paid were not actually achieved. The Compensation Committee may, in its sole discretion, require the recovery or reimbursement of long-term incentive compensation awards from any employee whose fraudulent or intentional misconduct materially affects the operations or financial results of the Company or its Subsidiaries.
Retention Rights:	Neither your restricted stock unit award nor this Award Agreement gives you any right to be retained by Sempra Energy or any of its Subsidiaries in any capacity and your employer reserves the right to terminate your employment at any time, with or without cause. The value of your award will not be included as compensation or earnings for purposes of any other benefit plan offered by Sempra Energy or any of its Subsidiaries.

5

Change in Control:	In the event of a Change in Control, the following terms shall apply: §If (i) you have achieved age 55 and have completed at least five years of continuous service with Sempra Energy and its Subsidiaries as of the date of a Change in Control and your restricted stock units have not been forfeited prior to the Change in Control, (ii) your outstanding restricted stock units as of the date of a Change in Control are not subject to a “substantial risk of forfeiture” within the meaning of Code Section 409A, and/or (iii) your outstanding restricted stock units are not assumed or substituted with one or more Replacement Awards (as defined in the Plan), then in each case your outstanding restricted stock units and any associated dividend equivalents will vest immediately prior to the Change in Control with the applicable performance goals deemed to have been achieved at the greater of target level as of the date of such vesting or the actual performance level had the performance period ended on the date of the Change in Control. If the foregoing terms apply, immediately prior to the date of the Change in Control you will receive a number of shares of Common Stock equal to the number of your restricted stock units and dividend equivalents that have vested. §If your outstanding restricted stock awards are assumed or substituted with one or more Replacement Awards, then, except as provided otherwise in an individual severance agreement or employment agreement to which you are a party, the terms set forth in the Plan shall apply with respect to such Replacement Award following the Change in Control. If the foregoing terms apply and the Replacement Award vests upon your separation from service or death, on such date, you will receive a number of shares or other property in settlement of the Replacement Awards.
Further Actions:	You agree to take all actions and execute all documents appropriate to carry out the provisions of this Award Agreement. You shall be deemed to have accepted this award unless you affirmatively reject it in writing addressed to the Corporate Secretary of the Company no later than March 31, <YEAR>; provided, however, that you shall not be deemed to have accepted this award if you fail to execute the Arbitration Agreement, if any, provided to you in connection with this award. You also appoint as your attorney-in-fact each individual who at the time of so acting is the Secretary or an Assistant Secretary of Sempra Energy with full authority to effect any transfer of any shares of Common Stock distributable to you, including any transfer to pay withholding taxes, that is authorized by this Award Agreement.
Applicable Law:	This Award Agreement will be interpreted and enforced under the laws of the State of California.
Disputes:	Any and all disputes between you and the Company relating to or arising out of the Plan or your restricted stock unit award shall be subject to the Arbitration Agreement, if any, provided with this Award Agreement, including, but not limited to, any disputes referenced in the applicable provisions of the Plan.
Other Agreements:	In the event of any conflict between the terms of this Award Agreement and any written employment, severance or other employment-related agreement between you and Sempra Energy, the terms of this Award Agreement, or the terms of such other agreement, whichever are more favorable to you, shall prevail, provided that in each case a conflict shall be resolved in a manner consistent with the intent that your restricted stock units comply with Code Section 409A. In the event of a conflict between the terms of this Award Agreement and the Plan, the Plan document shall prevail.

By your acceptance of this award, you agree to all of the terms and conditions set forth in the Cover Page/Summary, this Award Agreement and the Plan. You will be deemed to have accepted this award unless you affirmatively reject the award in accordance with the procedures described herein or unless you fail to execute the Arbitration Agreement, if any, provided to you in connection with this award.

6

EX-10.4

Exhibit 10.4

SEMPRA ENERGY

<YEAR> LONG TERM INCENTIVE PLAN

YEAR <YEAR> PERFORMANCE-BASED RESTRICTED STOCK UNIT AWARD

You have been granted a performance-based restricted stock unit award representing the right to receive the number of shares of Sempra Energy Common Stock set forth below, subject to the vesting conditions set forth below. The restricted stock units, and dividend equivalents with respect to the restricted stock units, under your award may not be sold or assigned. They will be subject to forfeiture unless and until they vest based upon the satisfaction of total shareholder return performance criteria for the S&P 500 Utilities Index (excluding water companies) for the performance period beginning on January 1, <YEAR> and ending on the close of trading on the first New York Stock Exchange trading day of <YEAR> [or such other performance period beginning and ending on the dates determined by the Compensation Committee]. Shares of Common Stock will be distributed to you after the completion of the performance period ending on <DATE>, <YEAR> if, and to the extent that, the restricted stock units vest under the terms and conditions of your award. The terms and conditions of your award are set forth in the attached Year <YEAR> Performance-Based Restricted Stock Unit Award Agreement (the “Award Agreement”) and in the Sempra Energy <YEAR> Long Term Incentive Plan (the “Plan”), which has been provided to you. The summary below highlights selected terms and conditions but it is not complete and you should carefully read the attachments to fully understand the terms and conditions of your award.
		SUMMARY
Date of Award:	<DATE>, <YEAR>
Name of Recipient:	NAME
Recipient’s Employee Number:	EE ID
Number of Restricted Stock Units (prior to any dividend equivalents):
At Target:	# RSU
At Maximum:	200% of Target (e.g. 1,000 at Target = 2,000 at Maximum)
Award Date Fair Market Value per Share of Common Stock (Closing Stock Price on Date of Award):	$<PRICE>
Restricted Stock Units:
Your restricted stock units represent the right to receive shares of Common Stock in the future, subject to the terms and conditions of your award. Your restricted stock units are not shares of Common Stock. The target number of restricted stock units will vest (subject to adjustment as described below) if, and to the extent that, the Compensation Committee of Sempra Energy’s Board of Directors (the “Compensation Committee”) determines that the target total shareholder return (a return at the 50th percentile) as described in the Award Agreement has been achieved for the performance period. If above target total shareholder return is achieved, you may vest in up to the maximum number of restricted stock units plus reinvested dividend equivalents as described below.
Vesting/Forfeiture of Restricted Stock Units:

Subject to certain exceptions set forth in the Award Agreement, your restricted stock units (including units attributable to reinvested dividend equivalents) will vest only in the event, and to the extent, that the Compensation Committee determines and certifies that Sempra Energy has met the specified total shareholder return performance criteria for the performance period beginning on January 1, <YEAR> and ending on the close of trading on the first New York Stock Exchange trading day of <YEAR> [or such other performance period beginning and ending on the dates determined by the Compensation Committee]. Any vesting will occur immediately following such determination and certification. Any restricted stock units that do not vest with the Compensation Committee's determination and certification (or otherwise in accordance with the Award Agreement) will be forfeited. All determinations of the Compensation Committee as to total shareholder return (as described below) and the number of your restricted stock units (and accompanying dividend equivalents) that vest is final and binding.

Transfer Restrictions:

Your restricted stock units may not be sold or otherwise transferred and will remain subject to forfeiture conditions until they vest.

Termination of Employment:

Subject to certain exceptions set forth in the Award Agreement, your restricted stock units will be forfeited if your employment terminates.

Dividend Equivalents:

You also have been awarded dividend equivalents with respect to your restricted stock units. Your dividend equivalents represent the right to receive additional shares of Common Stock in the future, subject to the terms and conditions of your award. Your dividend equivalents will be determined based on the dividends that you would have received had you held shares of Common Stock equal to the vested number of your restricted stock units from the date of your award to the date of the distribution of shares of Common Stock following the vesting of your restricted stock units, and assuming that the dividends were reinvested in Common Stock (and any dividends on such shares were reinvested in Common Stock). The dividends will be deemed reinvested in Common Stock in the same manner as dividends reinvested pursuant to the terms of the Sempra Dividend Reinvestment Plan. Your dividend equivalents will be subject to the same transfer restrictions and forfeiture and vesting conditions as the shares represented by your restricted stock units.

Distribution of Shares:

Shares of Common Stock will be distributed to you to the extent your restricted stock units (and accompanying dividend equivalents) vest. Except as provided otherwise inthe Award Agreement, the shares will be distributed to you after the completion of the performance period ending on the close of trading on the first New York Stock Exchange trading day of <YEAR> [or the end of the performance period determined by the Compensation Committee] and the Compensation Committee’s determination and certification of Sempra Energy’s total shareholder return for the performance period. The shares of Common Stock will include the additional shares to be distributed pursuant to your vested dividend equivalents.

Taxes:

Upon distribution of shares of Common Stock to you, you will be subject to income taxes on the value of the distributed shares at the time of distribution and must pay applicable withholding taxes.

By your acceptance of this award, you agree to all of the terms and conditions set forth in this Cover Page/Summary, the Award Agreement and the Plan. You will be deemed to have accepted this award unless you affirmatively reject the award in accordance with the procedures described herein or unless you fail to execute the Arbitration Agreement, if any, provided to you in connection with this award.

Sempra Energy:

Title:

2

SEMPRA ENERGY

<YEAR> LONG TERM INCENTIVE PLAN

Year <YEAR> Performance-Based Restricted Stock Unit Award Agreement

Award: You have been granted a performance-based restricted stock unit award under Sempra Energy’s <YEAR> Long Term Incentive Plan (the “Plan”). The award consists of the number of restricted stock units set forth on the Cover Page/Summary to this Award Agreement, and dividend equivalents with respect to the restricted stock units (described below). Capitalized terms used in this Award Agreement and not defined shall have the meaning set forth in the Plan. Your restricted stock units represent the right to receive shares of Common Stock in the future, subject to the terms and conditions of your award. Your restricted stock units are not shares of Common Stock. Each restricted stock unit initially represents the right to receive one share of Common Stock upon the vesting of the unit. Unless and until they vest, your restricted stock units and any dividend equivalents will be subject to transfer restrictions and forfeiture and vesting conditions. Subject to the provisions below relating to the treatment of your restricted stock units in connection with a Change in Control, your restricted stock units (and dividend equivalents) will vest only in the event, and only to the extent, that the Compensation Committee of Sempra Energy's Board of Directors (the “Compensation Committee”) determines and certifies that Sempra Energy has met specified total shareholder return criteria for the performance period beginning January 1, <YEAR> and ending on the close of trading on the first New York Stock Exchange trading day of <YEAR> [or such other performance period beginning and ending on the dates determined by the Compensation Committee]. Any restricted stock units (and dividend equivalents) that do not vest will be forfeited. Subject to certain exceptions set forth herein, your restricted stock units (and dividend equivalents) will be forfeited if your employment terminates before they vest; provided, however, that the Compensation Committee, in its sole discretion, may determine that all or a portion of such restricted stock units (and dividend equivalents) will not be forfeited but will continue to be subject to transfer restrictions and other vesting conditions applicable under this Award Agreement (subject to Code Section 409A requirements and the terms of the Plan). See “Vesting/Forfeiture,” “Transfer Restrictions,” and “Termination of Employment” below.

Vesting/Forfeiture:

Subject to the provisions below relating to the treatment of your restricted stock units in connection with a Change in Control, your restricted stock units (and dividend equivalents) will vest only in the event, and to the extent, that the Compensation Committee determines and certifies that Sempra Energy has met the following total shareholder return performance criteria for the performance period beginning on January 1, <YEAR> and ending on the close of trading on the first New York Stock Exchange trading day of <YEAR> [or such other performance period beginning and ending on the dates determined by the Compensation Committee]. Any vesting will occur immediately following such determination and certification. THE DETERMINATION OF THE COMPENSATION COMMITTEE AS TO TOTAL SHAREHOLDER RETURN PERFORMANCE AND THE NUMBER OF RESTRICTED STOCK UNITS (AND ACCOMPANYING DIVIDEND EQUIVALENTS) THAT VEST IS FINAL AND BINDING.

§The percentage of your target number of restricted stock units that vest will be determined as follows, based on the percentile ranking for the performance period (as measured based on the thirty-day average closing stock price immediately preceding the start of the performance period compared to the thirty-day average closing stock price immediately preceding the end of the performance period) of Sempra Energy’s cumulative total shareholder return (consisting of per share appreciation in Common Stock plus reinvested dividends and other distributions paid on Common Stock) among the companies (ranked by cumulative total shareholder returns) in the S&P 500 Utilities Index (excluding water companies), as determined and certified by the Compensation Committee, subject to adjustment as described below. For the avoidance of doubt, the thirty-day average preceding the beginning of the performance period shall be based on the thirty calendar days prior to and excluding January 1, <YEAR> and the thirty day average preceding the end of the performance period shall be based on the thirty calendar days prior to and including the first NYSE trading day of <YEAR> [or such other performance period beginning and ending on the dates determined by the Compensation Committee].

Sempra Energy Total Shareholder Return Percentile Ranking	Percentage of Target Number of Restricted Stock Units that Vest
90th	200%
80th	175%
70th	150%
60th	125%
50th	100%
40th	70%
35th	55%
30th	40%
25th	—%

2

	If the percentile ranking does not equal a ranking shown in the above table, the percentage of your target number of restricted stock units that vest will be determined by a linear interpolation between the next lowest percentile shown in the table and the next highest percentile shown on the table. o    If the percentile ranking is at or above the 90th percentile, 200% of your target number of restricted stock units will vest. o    If the percentile ranking is at or below the 25th percentile, none of your restricted stock units will vest. As soon as reasonably practicable following the end of the performance period, the Compensation Committee will determine and certify the extent to which Sempra Energy has met the total shareholder return performance criteria and the extent to which, if any, your restricted stock units have then vested and any such vesting shall occur immediately following such determination and certification by the Compensation Committee. You will receive the number of shares of Common Stock equal to the number of your vested restricted stock units after the Compensation Committee’s determination and certification. Also, you will receive the number of shares of Common Stock equal to your vested dividend equivalents after the Compensation Committee’s determination and certification. Certificates for the shares will be transferred to your brokerage account unless you specifically instruct otherwise. When the shares of Common Stock are issued to you, your restricted stock units (vested and unvested) and your dividend equivalents will terminate.
Transfer Restrictions:	You may not sell or otherwise transfer or assign your restricted stock units (or your dividend equivalents).
Dividend Equivalents:	You also have been awarded dividend equivalents with respect to your restricted stock units. Your dividend equivalents represent the right to receive additional shares of Common Stock in the future, subject to the terms and conditions of your award. Your dividend equivalents will be determined based on the dividends that you would have received had you held shares of Common Stock equal to the vested number of your restricted stock units from the date of your award to the date of the distribution of shares of Common Stock following the vesting of your restricted stock units, and assuming that the dividends were reinvested in Common Stock (and any dividends on such shares were reinvested in Common Stock). The dividends will be deemed reinvested in Common Stock in the same manner as dividends reinvested pursuant to the terms of the Sempra Dividend Reinvestment Plan. Your dividend equivalents will be subject to the same transfer restrictions and forfeiture and vesting conditions as your restricted stock units. They will vest when and to the extent that your restricted stock units vest. Also, your restricted stock units (and dividend equivalents), including the terms and conditions thereof, will be adjusted to prevent dilution or enlargement of your rights in the event of a stock dividend on shares of Common Stock or as the result of a stock-split, recapitalization, reorganization or other similar transaction in accordance with the terms and conditions of the Plan. Any additional restricted stock units (and dividend equivalents) awarded to you as a result of such an adjustment also will be subject to the same transfer restrictions, forfeiture and vesting conditions and other terms and conditions that are applicable to your restricted stock units (and dividend equivalents).

3

No Shareholder Rights:	Your restricted stock units (and dividend equivalents) are not shares of Common Stock. You will have no rights as a shareholder unless and until shares of Common Stock are issued to you following the vesting of your restricted stock units (and dividend equivalents) as provided in this Award Agreement and the Plan.
Distribution of Shares:	As described in “Vesting/Forfeiture” above, the Compensation Committee will determine and certify the extent to which Sempra Energy has met the performance criteria and the extent, if any, as to which your restricted stock units (and dividend equivalents) have then vested in accordance with the terms of the award. You will receive the number of shares of Common Stock equal to the number of your restricted stock units that have vested. However, in no event will you receive under this award, and other awards granted to you under the Plan in the same fiscal year of Sempra Energy, more than the maximum number of shares of Common Stock permitted under the Plan. Also, you will receive the number of shares of Common Stock equal to your vested dividend equivalents after the Compensation Committee’s determination and certification. You will receive the shares as soon as reasonably practicable following the Compensation Committee’s determination and certification (and in no event later than March 15, <YEAR>). Once you receive the shares of Common Stock, your vested and unvested restricted stock units (and dividend equivalents) will terminate.
Termination of Employment:

4

Termination: If your employment with Sempra Energy and its Subsidiaries terminates for any reason prior to the vesting of your restricted stock units (and dividend equivalents) (other than under the circumstances set forth in the following provisions of this section), all of your restricted stock units (and dividend equivalents) will be forfeited. Subject to the provisions below relating to the treatment of your restricted stock units in connection with a Change in Control, the vesting of your restricted stock units (and dividend equivalents) does not occur until the date of the Compensation Committee’s determination and certification described above. If your employment terminates prior to a Change in Control, other than by termination for cause, and you had both completed at least five years of continuous service with Sempra Energy and its Subsidiaries AND met any of the following conditions: 1.)    your employment terminates on or after December 31, <YEAR> andat the date of terminationyou had attained age 55; or 2.)    your employment terminates on or after November 30, <YEAR> and at the date of termination you had attained age 62; or 3.)    at the date of termination you had attained age 65 and you were an officer subject to the company’s mandatory retirement policy; your restricted stock units (and dividend equivalents) will not be forfeited but will continue to be subject to the transfer restrictions and vesting conditions and other terms and conditions of this Award Agreement (subject to Code Section 409A requirements and the terms of the Plan). If your employment terminates by reason of your death prior to the vesting of your restricted stock units and your award would otherwise be forfeited (for example, you do not meet the age and service conditions described above), your award will be deemed forfeited immediately prior to the date and time it would otherwise vest, unless, and to the extent that, prior to the date and time that the restricted stock units would otherwise vest, the Compensation Committee, in its sole discretion, takes action to waive the service requirement described above. If your employment terminates and your restricted stock units (and dividend equivalents) would otherwise be forfeited, the Compensation Committee, in its sole discretion, may determine prior to such termination that all or a portion of such restricted stock units (and dividend equivalents) will not be forfeited but will continue to be subject to the transfer restrictions and vesting conditions and other terms and conditions of this Award Agreement (subject to Code Section 409A requirements and the terms of the Plan).

5

Termination for Cause:	If your employment with Sempra Energy and its Subsidiaries terminates for cause, or your employment would have been subject to termination for cause, prior to the vesting of your restricted stock units (and dividend equivalents), all of your restricted stock units (and dividend equivalents) will be forfeited. Prior to the consummation of a Change in Control, a termination for cause is (i) the willful failure by you to substantially perform your duties with the Company (other than any such failure resulting from your incapacity due to physical or mental illness), (ii) the grossly negligent performance of such obligations referenced in clause (i) of this definition, (iii) your gross insubordination; and/or (iv) your commission of one or more acts of moral turpitude that constitute a violation of applicable law (including but not limited to a felony) which have or result in an adverse effect on the Company, monetarily or otherwise, or one or more significant acts of dishonesty. For purposes of clause (i), no act, or failure to act, on your part shall be deemed “willful” unless done, or omitted to be done, by you not in good faith and without reasonable belief that your act, or failure to act, was in the best interests of the Company. If your restricted stock units remain outstanding following a Change in Control pursuant to a Replacement Award, a termination for cause following such Change in Control shall be determined in accordance with the provisions of the Plan that define “Cause”, including reasonable notice and, if possible, a reasonable opportunity to cure as provided therein.
Taxes:
Withholding Taxes:	When you become subject to withholding taxes upon distribution of the shares of Common Stock or otherwise, Sempra Energy or its Subsidiary is required to withhold taxes. Unless you instruct otherwise and pay or make arrangements satisfactory to Sempra Energy to pay these taxes, upon the distribution of your shares, Sempra Energy will withhold a sufficient number of shares of common stock that you would otherwise be entitled to receive to cover the minimum required withholding taxes and transfer to you only the remaining balance of your shares. In the event that, following a Change in Control, your restricted stock units become eligible for a distribution upon your Retirement by reason of your combined age and service, your restricted stock units may become subject to employment tax withholding prior to the distribution of shares with respect to such units.
Code Section 409A:	Your restricted stock units are subject to provisions of the Plan which set forth terms to comply with Code Section 409A.
Recoupment (“Clawback”) Policy:	The Company shall require the forfeiture, recovery or reimbursement of awards or compensation under the Plan and this award as (i) required by applicable law, or (ii) required under any policy implemented or maintained by the Company pursuant to any applicable rules or requirements of a national securities exchange or national securities association on which any securities of the Company are listed. The Company reserves the right to recoup compensation paid if it determines that the results on which the compensation was paid were not actually achieved. The Compensation Committee may, in its sole discretion, require the recovery or reimbursement of long-term incentive compensation awards from any employee whose fraudulent or intentional misconduct materially affects the operations or financial results of the Company or its Subsidiaries.
Retention Rights:	Neither your restricted stock unit award nor this Award Agreement gives you any right to be retained by Sempra Energy or any of its Subsidiaries in any capacity and your employer reserves the right to terminate your employment at any time, with or without cause. The value of your award will not be included as compensation or earnings for purposes of any other benefit plan offered by Sempra Energy or any of its Subsidiaries.

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Change in Control:	In the event of a Change in Control, the following terms shall apply: §If (i) you have achieved age 55 and have completed at least five years of continuous service with Sempra Energy and its Subsidiaries as of the date of a Change in Control and your restricted stock units have not been forfeited prior to the Change in Control, (ii) your outstanding restricted stock units as of the date of a Change in Control are not subject to a “substantial risk of forfeiture” within the meaning of Code Section 409A, and/or (iii) your outstanding restricted stock units are not assumed or substituted with one or more Replacement Awards (as defined in the Plan), then in each case your outstanding restricted stock units and any associated dividend equivalents will vest immediately prior to the Change in Control with the applicable performance goals deemed to have been achieved at the greater of target level as of the date of such vesting or the actual performance level had the performance period ended on the date of the Change in Control. If the foregoing terms apply, immediately prior to the date of the Change in Control you will receive a number of shares of Common Stock equal to the number of your restricted stock units and dividend equivalents that have vested. §If your outstanding restricted stock awards are assumed or substituted with one or more Replacement Awards, then, except as provided otherwise in an individual severance agreement or employment agreement to which you are a party, the terms set forth in the Plan shall apply with respect to such Replacement Award following the Change in Control. If the foregoing terms apply and the Replacement Award vests upon your separation from service or death, on such date, you will receive a number of shares or other property in settlement of the Replacement Awards.
Further Actions:	You agree to take all actions and execute all documents appropriate to carry out the provisions of this Award Agreement. You shall be deemed to have accepted this award unless you affirmatively reject it in writing addressed to the Corporate Secretary of the Company no later than March 31, <YEAR>; provided, however, that you shall not be deemed to have accepted this award if you fail to execute the Arbitration Agreement, if any, provided to you in connection with this award. You also appoint as your attorney-in-fact each individual who at the time of so acting is the Secretary or an Assistant Secretary of Sempra Energy with full authority to effect any transfer of any shares of Common Stock distributable to you, including any transfer to pay withholding taxes, that is authorized by this Award Agreement.
Applicable Law:	This Award Agreement will be interpreted and enforced under the laws of the State of California.
Disputes:	Any and all disputes between you and the Company relating to or arising out of the Plan or your restricted stock unit award shall be subject to the Arbitration Agreement, if any, provided with this Award Agreement, including, but not limited to, any disputes referenced in the applicable provisions of the Plan.
Other Agreements:	In the event of any conflict between the terms of this Award Agreement and any written employment, severance or other employment-related agreement between you and Sempra Energy, the terms of this Award Agreement, or the terms of such other agreement, whichever are more favorable to you, shall prevail, provided that in each case a conflict shall be resolved in a manner consistent with the intent that your restricted stock units comply with Code Section 409A. In the event of a conflict between the terms of this Award Agreement and the Plan, the Plan document shall prevail.

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By your acceptance of this award, you agree to all of the terms and conditions set forth in the Cover Page/Summary, this Award Agreement and the Plan. You will be deemed to have accepted this award unless you affirmatively reject the award in accordance with the procedures described herein or unless you fail to execute the Arbitration Agreement, if any, provided to you in connection with this award.

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EX-10.5

Exhibit 10.5

SEMPRA ENERGY

<YEAR> LONG TERM INCENTIVE PLAN

YEAR <YEAR> RESTRICTED STOCK UNIT AWARD

You have been granted a restricted stock unit award representing the right to receive the number of shares of Sempra Energy Common Stock set forth below, subject to the vesting conditions set forth below. The restricted stock units, and dividend equivalents with respect to the restricted stock units, under your award may not be sold or assigned. They will be subject to forfeiture unless and until they vest in accordance with the terms and conditions of the award. Shares of Common Stock will be distributed to you after the completion of the service periods ending in <MONTH> <YEAR>, <YEAR> and <YEAR>, if the restricted stock units vest under the terms and conditions of your award. The terms and conditions of your award are set forth in the attached Year <YEAR> Restricted Stock Unit Award Agreement (the “Award Agreement”) and in the Sempra Energy <YEAR> Long Term Incentive Plan (the “Plan”), which has been provided to you. The summary below highlights selected terms and conditions but it is not complete and you should carefully read the attachments to fully understand the terms and conditions of your award.
		SUMMARY
Date of Award:	<DATE>, <YEAR>
Name of Recipient:	NAME
Recipient’s Employee Number:	EE ID
Number of Restricted Stock Units (prior to any dividend equivalents):	# RSU
Restricted Stock Units:
Your restricted stock units represent the right to receive shares of Common Stock in the future, subject to the terms and conditions of your award. Your restricted stock units are not shares of Common Stock.
Vesting/Forfeiture of Restricted Stock Units:
If not previously forfeited, your restricted stock units will vest in equal annual installments of one–third of the original number of units covered by this award (together with related dividend equivalents) on each of the <”first New York Stock Exchange trading days of <YEAR>, <YEAR> and <YEAR>” [for awards granted on the first New York Stock Exchange trading day of the year] or “the first three anniversaries of the award date” [for awards not granted on the first New York Stock Exchange trading day of the year]>, subject to your continued employment by Sempra Energy or its Subsidiaries through the applicable Vesting Date. Subject to certain exceptions set forth in the Award Agreement, if your employment terminates prior to the applicable Vesting Date, your restricted stock units will be forfeited effective immediately following such termination.
Transfer Restrictions:
Your restricted stock units may not be sold or otherwise transferred and will remain subject to forfeiture conditions until they vest.
Termination of Employment:
Subject to certain exceptions set forth in the Award Agreement, your restricted stock units will be forfeited if your employment terminates before such units vest effective immediately following such termination.
Dividend Equivalents:

You also have been awarded dividend equivalents with respect to your restricted stock units. Your dividend equivalents represent the right to receive additional shares of Common Stock in the future, subject to the terms and conditions of your award. Your dividend equivalents will be determined based on the dividends that you would have received had you held shares of Common Stock equal to the vested number of your restricted stock units from the date of your award to the date of the distribution of shares of Common Stock following the vesting of your restricted stock units, and assuming that the dividends were reinvested in Common Stock (and any dividends on such shares were reinvested in Common Stock). The dividends will be deemed reinvested in Common Stock in the same manner as dividends reinvested pursuant to the terms of the Sempra Dividend Reinvestment Plan. Your dividend equivalents will be subject to the same transfer restrictions and forfeiture and vesting conditions as the shares represented by your restricted stock units.

Distribution of Shares:

Shares of Common Stock will be distributed to you to the extent your restricted stock units (and accompanying dividend equivalents) vest. Except as provided otherwise in the Award Agreement, the shares will be distributed to you after the completion of the applicable service period. The shares of Common Stock will include the additional shares to be distributed pursuant to your vested dividend equivalents.

Taxes:

Upon distribution of shares of Common Stock to you, you will be subject to income taxes on the value of the distributed shares at the time of distribution and must pay applicable withholding taxes.

By your acceptance of this award, you agree to all of the terms and conditions set forth in this Cover Page/Summary, the Award Agreement and the Plan. You will be deemed to have accepted this award unless you affirmatively reject the award in accordance with the procedures described herein or unless you fail to execute the Arbitration Agreement, if any, provided to you in connection with this award.

Sempra Energy:

Title:

2

SEMPRA ENERGY

<YEAR> LONG TERM INCENTIVE PLAN

Year <YEAR> Restricted Stock Unit Award Agreement

Award:	You have been granted a restricted stock unit award under Sempra Energy’s <YEAR> Long Term Incentive Plan (the “Plan”). The award consists of the number of restricted stock units set forth on the Cover Page/Summary to this Award Agreement, and dividend equivalents with respect to the restricted stock units (described below). Capitalized terms used in this Award Agreement and not defined shall have the meaning set forth in the Plan. Your restricted stock units represent the right to receive shares of Common Stock in the future, subject to the terms and conditions of your award. Your restricted stock units are not shares of Common Stock. Each restricted stock unit represents the right to receive one share of Common Stock upon the vesting of the unit. Unless and until they vest, your restricted stock units and any dividend equivalents will be subject to transfer restrictions and forfeiture and vesting conditions. Subject to certain exceptions set forth herein, your restricted stock units (and dividend equivalents) will be forfeited effective immediately following such termination if your employment terminates before they vest; provided, however, that the Compensation Committee, in its sole discretion, may determine to vest you in all or a portion of such restricted stock units (subject to Code Section 409A requirements and the terms of the Plan). See “Vesting/Forfeiture,” “Transfer Restrictions,” and “Termination of Employment” below.
Vesting/Forfeiture:	Subject to the provisions below relating to the treatment of your restricted stock units in connection with a Change in Control, your restricted stock units (and dividend equivalents) will vest in equal annual installments of one–third of the original number of units covered by this award (together with related dividend equivalents) on each of the <”first New York Stock Exchange trading days of <YEAR>, <YEAR> and <YEAR>” [for awards granted on the first New York Stock Exchange trading day of the year] or “the first three anniversaries of the award date” [for awards not granted on the first New York Stock Exchange trading day of the year]>, subject to your continued employment by Sempra Energy or its Subsidiaries through the applicable vesting date and the terms of this Award Agreement. Certificates for the shares will transferred to your brokerage account unless you specifically instruct otherwise. When the shares of Common Stock are issued to you, your restricted stock units (vested and unvested) and your dividend equivalents will terminate.
Transfer Restrictions:	You may not sell or otherwise transfer or assign your restricted stock units (or your dividend equivalents).

Dividend Equivalents:	You also have been awarded dividend equivalents with respect to your restricted stock units. Your dividend equivalents represent the right to receive additional shares of Common Stock in the future, subject to the terms and conditions of your award. Your dividend equivalents will be determined based on the dividends that you would have received had you held shares of Common Stock equal to the vested number of your restricted stock units from the date of your award to the date of the distribution of shares of Common Stock following the vesting of your restricted stock units, and assuming that the dividends were reinvested in Common Stock (and any dividends on such shares were reinvested in Common Stock). The dividends will be deemed reinvested in Common Stock in the same manner as dividends reinvested pursuant to the terms of the Sempra Dividend Reinvestment Plan. Your dividend equivalents will be subject to the same transfer restrictions and forfeiture and vesting conditions as your restricted stock units. They will vest when and to the extent that your restricted stock units vest. Also, your restricted stock units (and dividend equivalents), including the terms and conditions thereof, will be adjusted to prevent dilution or enlargement of your rights in the event of a stock dividend on shares of Common Stock or as the result of a stock-split, recapitalization, reorganization or other similar transaction in accordance with the terms and conditions of the Plan. Any additional restricted stock units (and dividend equivalents) awarded to you as a result of such an adjustment also will be subject to the same transfer restrictions, forfeiture and vesting conditions and other terms and conditions that are applicable to your restricted stock units (and dividend equivalents).
No Shareholder Rights:	Your restricted stock units (and dividend equivalents) are not shares of Common Stock. You will have no rights as a shareholder unless and until shares of Common Stock are issued to you following the vesting of your restricted stock units (and dividend equivalents) as provided in this Award Agreement and the Plan.
Distribution of Shares:	Following the vesting of your restricted stock units, you will receive the number of shares of Common Stock equal to the number of your restricted stock units that have vested. However, in no event will you receive under this award, and other awards granted to you under the Plan in the same fiscal year of Sempra Energy, more than the maximum number of shares of Common Stock permitted under the Plan. Also, you will receive the number of shares of Common Stock equal to your vested dividend equivalents. You will receive the shares as soon as reasonably practicable following each vesting date (and in no event later than March 15 of the year following the applicable vesting date). Once you receive the shares of Common Stock, your restricted stock units (and dividend equivalents) will terminate.
Termination of Employment:
Termination:	If your employment with Sempra Energy and its Subsidiaries terminates for any reason other than by reason of your death prior to the vesting of your restricted stock units (and dividend equivalents), all of your restricted stock units (and dividend equivalents) will be forfeited effective immediately following such termination; provided, however, that the Compensation Committee in its sole discretion may determine to vest you in all or a portion of such restricted stock units (subject to Code Section 409A requirements and the terms of the Plan). If your employment terminates by reason of your death prior to the vesting of your restricted stock units (and dividend equivalents), all of your restricted stock units (and dividend equivalents) will vest upon your death.

2

Termination for Cause:	If your employment with Sempra Energy and its Subsidiaries terminates for cause, or your employment would have been subject to termination for cause, prior to the vesting of your restricted stock units (and dividend equivalents), all of your restricted stock units (and dividend equivalents) will be forfeited effective immediately following such termination. Prior to the consummation of a Change in Control, a termination for cause is (i) the willful failure by you to substantially perform your duties with the Company (other than any such failure resulting from your incapacity due to physical or mental illness), (ii) the grossly negligent performance of such obligations referenced in clause (i) of this definition, (iii) your gross insubordination; and/or (iv) your commission of one or more acts of moral turpitude that constitute a violation of applicable law (including but not limited to a felony) which have or result in an adverse effect on the Company, monetarily or otherwise, or one or more significant acts of dishonesty. For purposes of clause (i), no act, or failure to act, on your part shall be deemed “willful” unless done, or omitted to be done, by you not in good faith and without reasonable belief that your act, or failure to act, was in the best interests of the Company. If your restricted stock units remain outstanding following a Change in Control pursuant to a Replacement Award, a termination for cause following such Change in Control shall be determined in accordance with the provisions of the Plan that define “Cause”, including reasonable notice and, if possible, a reasonable opportunity to cure as provided therein.
Taxes:
Withholding Taxes:	When you become subject to withholding taxes upon distribution of the shares of Common Stock or otherwise, Sempra Energy or its Subsidiary is required to withhold taxes. Unless you instruct otherwise and pay or make arrangements satisfactory to Sempra Energy to pay these taxes, upon the distribution of your shares, Sempra Energy will withhold a sufficient number of shares of common stock that you would otherwise be entitled to receive to cover the minimum required withholding taxes and transfer to you only the remaining balance of your shares. In the event that, following a Change in Control, your restricted stock units become eligible for a distribution upon your Retirement by reason of your combined age and service, your restricted stock units may become subject to employment tax withholding prior to the distribution of shares with respect to such units.
Code Section 409A: Recoupment (“Clawback”) Policy:	Your restricted stock units are subject to provisions of the Plan which set forth terms to comply with Code Section 409A. The Company shall require the forfeiture, recovery or reimbursement of awards or compensation under the Plan and this award as (i) required by applicable law, or (ii) required under any policy implemented or maintained by the Company pursuant to any applicable rules or requirements of a national securities exchange or national securities association on which any securities of the Company are listed. The Company reserves the right to recoup compensation paid if it determines that the results on which the compensation was paid were not actually achieved. The Compensation Committee may, in its sole discretion, require the recovery or reimbursement of long-term incentive compensation awards from any employee whose fraudulent or intentional misconduct materially affects the operations or financial results of the Company or its Subsidiaries.
Retention Rights:	Neither your restricted stock unit award nor this Award Agreement gives you any right to be retained by Sempra Energy or any of its Subsidiaries in any capacity and your employer reserves the right to terminate your employment at any time, with or without cause. The value of your award will not be included as compensation or earnings for purposes of any other benefit plan offered by Sempra Energy or any of its Subsidiaries.

3

Change in Control:	In the event of a Change in Control, the following terms shall apply: §If (i) you have achieved age 55 and have completed at least five years of continuous service with Sempra Energy and its Subsidiaries as of the date of a Change in Control and your restricted stock units have not been forfeited prior to the Change in Control, (ii) your outstanding restricted stock units as of the date of a Change in Control are not subject to a “substantial risk of forfeiture” within the meaning of Code Section 409A and/or (iii) your outstanding restricted stock units are not assumed or substituted with one or more Replacement Awards (as defined in the Plan), then in each case your outstanding restricted stock units and any associated dividend equivalents will vest immediately prior to the Change in Control. If the foregoing terms apply, immediately prior to the date of the Change in Control you will receive a number of shares of Common Stock equal to the number of your restricted stock units and dividend equivalents that have vested. §If your outstanding restricted stock awards are assumed or substituted with one or more Replacement Awards, then, except as provided otherwise in an individual severance agreement or employment agreement to which you are a party, the terms set forth in the Plan shall apply with respect to such Replacement Award following the Change in Control. If the foregoing terms apply and the Replacement Award vests upon your separation from service or death, on such date, you will receive a number of shares or other property in settlement of the Replacement Awards.
Further Actions:	You agree to take all actions and execute all documents appropriate to carry out the provisions of this Award Agreement. You shall be deemed to have accepted this award unless you affirmatively reject it in writing addressed to the Corporate Secretary of the Company no later than March 31, <YEAR>; provided, however, that you shall not be deemed to have accepted this award if you fail to execute the Arbitration Agreement, if any, provided to you in connection with this award. You also appoint as your attorney-in-fact each individual who at the time of so acting is the Secretary or an Assistant Secretary of Sempra Energy with full authority to effect any transfer of any shares of Common Stock distributable to you, including any transfer to pay withholding taxes, that is authorized by this Award Agreement.
Applicable Law:	This Award Agreement will be interpreted and enforced under the laws of the State of California.
Disputes:	Any and all disputes between you and the Company relating to or arising out of the Plan or your restricted stock unit award shall be subject to the Arbitration Agreement, if any, provided with this Award Agreement, including, but not limited to, any disputes referenced in the applicable provisions of the Plan.
Other Agreements:	In the event of any conflict between the terms of this Award Agreement and any written employment, severance or other employment-related agreement between you and Sempra Energy, the terms of this Award Agreement, or the terms of such other agreement, whichever are more favorable to you, shall prevail, provided that in each case a conflict shall be resolved in a manner consistent with the intent that your restricted stock units comply with Code Section 409A. In the event of a conflict between the terms of this Award Agreement and the Plan, the Plan document shall prevail.

By your acceptance of this award, you agree to all of the terms and conditions set forth in the Cover Page/Summary, this Award Agreement and the Plan. You will be deemed to have accepted this award unless you affirmatively reject the award in accordance with the procedures described herein or unless you fail to execute the Arbitration Agreement, if any, provided to you in connection with this award.

4

EX-10.8

Exhibit 10.8

***Text omitted pursuant to

Item 601(a)(6) of Regulation S-K.

SEVERANCE AGREEMENT AND MUTUAL RELEASE

This Severance Agreement and Mutual Release (“Agreement”) is made by and between P. Kevin Chase (“Chase”) and San Diego Gas & Electric Company (“SDG&E”) and Southern California Gas Company (“SoCalGas”) (collectively referred to as “Companies”). Chase and the Companies will at times be referred to collectively as the “Parties” and may individually be referred to as the “party.”

RECITALS

A.Chase’s employment with San Diego Gas & Electric Company as a shared officer for the Companies ended on April 2, 2019.

B.The Parties disagree on the issue of Chase’s entitlement to benefits under the Severance Pay Agreement between Chase and Sempra Energy dated March 4, 2017 (“Severance Pay Agreement”).

C.The Parties now mutually desire to fully settle and finally resolve any and all claims the Parties have, or could have had, or may have had, with respect to Chase’s employment with the Companies and his separation from employment with the Companies.

D.The Parties understand that they are waiving legal rights or claims by signing this Agreement and further acknowledge that they each are voluntarily entering into this Agreement with a full and complete understanding of its terms and with the full intent to be bound thereby.

THEREFORE, in consideration of the promises, covenants, representations, and warranties contained herein, and for good and valuable consideration given hereunder, the adequacy of which is hereby acknowledged, the Parties hereby agree as follows:

AGREEMENTS

1.Benefits Payable: In exchange for Chase entering into this Agreement and for the covenants and releases contained herein, the Companies will pay to Chase the following amounts, hereinafter referred to as “Severance Payment”:

1.1.A lump sum payment of one million three hundred sixty-three thousand seven hundred twenty-five dollars ($1,363,725.00), less applicable payroll tax withholdings, which is equal to the amount Chase would be entitled to pursuant to sections 4 and 5 of the Severance Pay Agreement. Provided Chase has executed and not revoked this Agreement, this sum will be paid by check to Chase on or before October 2, 2019 by delivering the check to his attorney’s office at Haeggquist & Eck, LLP, Re: Kevin Chase Payment, 225 Broadway, Suite 2050, San Diego, CA 92101.

1.2.A lump sum payment of seven hundred seventy-one thousand eight hundred thirty-seven dollars and eighty-four cents ($771,837.84), less any applicable payroll deductions, which equals the value of the time-based restricted stock units (“RSUs”) granted under the Company’s Long Term Incentive Plan (“LTIP”) calculated using the April 2, 2019 closing price of

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Sempra Energy common stock. This cash payment will be paid by check to Chase on the 10th business day after the Company receives Chase’s signature on this Agreement, provided Chase has not revoked it, and the check will be delivered to Chase at his attorney’s office at Haeggquist & Eck, LLP, Re: Kevin Chase Payment, 225 Broadway, Suite 2050, San Diego, CA 92101.

1.3.Chase will receive separate notification of his right to extend his Company provided healthcare benefits through COBRA with a copy of this notification to be sent to Chase’s attorney’s office at Haeggquist & Eck, LLP, Re: Kevin Chase Payment, 225 Broadway, Suite 2050, San Diego, CA 92101. As further consideration for this Agreement, should Chase elect to continue his healthcare benefits through COBRA, the Companies will pay for such extension for eighteen (18) months (or, if less, the period that the extended coverage under COBRA is in effect). The Companies will make 100% of the premium payments directly to Chase’s insurer for up to eighteen (18) months of extended coverage.

1.4.The Companies further agree to provide to Chase outplacement assistance with Lee Hecht Harrison for twenty four (24) months, the cost to the Companies for which shall not to exceed fifty thousand dollars ($50,000.00), and which shall cease upon Chase’s acceptance of employment with a subsequent employer, not including any interim work Chase may engage as an independent contractor or any new start-up companies Chase may form during the next twenty four (24) months; and financial advice planning services with The Ayco Company for twenty four (24) months, the cost to the Companies of which shall not exceed twenty five thousand dollars ($25,000.00) per year. The value of the outplacement and financial planning services shall not be subject to liquidation or exchange for any other benefit.

2.Reason for Termination. The Companies agree to characterize the termination of Chase’s employment as a resignation. In this regard, the Companies agree as follows:

2.1.Within ten (10) days of Chase signing this Agreement, the Companies will destroy and otherwise strike from the Companies’ records, including without limitation, from Chase’s personnel file, any information stating that the termination was other than a resignation.

2.2.Within two (2) business days of Chase signing this Agreement, the Companies shall send an email from Scott Drury, SDG&E President, and Bret Lane, SoCalGas CEO, to: (a) all employees of Companies in the entire information technology department supporting both SDG&E and SoCalGas as well as all Sempra Energy Employees in the entire cybersecurity department at Sempra Energy; (b) all officers of SDG&E and SoCalGas; and (c) the Company’s assigned account executive(s) at PWC, Accenture, Deloitte, E&Y, KPMG, Dell/EMC, WWT, CapGemini, HCL, SAP Microsoft, IBM, B&V, and Osceola, consisting of the following language:

We have received some inquiries regarding Kevin Chase’s departure as SVP, CIO & Chief Digital Officer for SDG&E and SoCalGas. Kevin would like you to know that his decision was difficult, but after much consideration, the best course for Mr. Chase was to resign so he could pursue other career opportunities that he has been contemplating recently. Kevin expressed his heartfelt warm wishes for everyone at Sempra Energy, SDG&E and SoCalGas, noting that he is extremely proud of the entire technology organization and its strategic vendors for all the positive change

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that has occurred over the past two years under his leadership. The executive teams at SDG&E and SoCalGas look forward to building on the successful strategies Mr. Chase implemented. We have wished Kevin only the best in his future endeavors.

The Companies shall forward to Chase at [***]@gmail.com a copy of the email that was sent within twenty-four (24) hours of its issuance to the relevant individuals.

2.3.The Companies agree that in responding to any inquiries from prospective employers, persons, and/or entities inquiring about the status, terms, and/or performance of Chase’s employment with the Companies that the Companies shall only disclose the beginning and ending dates of Chase’s employment and last position held at the Companies. The Companies shall further advise that its policies restrict the Companies from disclosing any additional information than that set forth in this subsection 2.3.

3.Termination of Employment and Payment of Wages. Chase agrees that his employment with the Companies terminated on April 2, 2019, (“Termination Date”). Chase acknowledges that on the Termination Date, Chase received his final paycheck, including all wages owed to Chase through April 1, 2019, and any unused vacation time and personal days accrued through that date, plus two-weeks’ pay in lieu of notice. Chase further acknowledges that he received a second check for waged earned on April 2, 2019. Chase acknowledges that no part of the Severance Payment consists of wages owed to Chase for his employment through the Termination Date.

4.Mutual Release and Wavier of all Claims. Except as provided for in this Agreement, the Parties agree to the following releases and waivers of all claims:

4.1.Chase releases the Companies, their current or former parents, subsidiaries, and affiliates, and their current or former employees or agents, and related parties, (“Releasees”) from all known or unknown claims arising out of Chase’s employment with, or separation from, the Companies that he may presently have or which may accrue at any time before this Agreement becomes irrevocable by Chase. The claims Chase is releasing include, for example, but are not limited to, the following: claims under any express or implied contract including the Severance Pay Agreement between Chase and Sempra Energy dated March 4, 2017 (“Severance Pay Agreement”), the Civil Rights Acts of 1866 and 1964, the Americans with Disabilities Act, the California Fair Employment and Housing Act (FEHA), the Age Discrimination in Employment Act (ADEA), the Older Workers Benefits Protection Act (OWBPA), state and federal laws regarding whistleblowing or otherwise prohibiting retaliation, or any other federal, state, or local common law, statute, regulation, or law of any other type. Chase will never file any lawsuit based on any such claim, and Chase will withdraw with prejudice any such lawsuit that may already be pending. This release also includes any claim for attorneys’ fees. This subsection 4.1 does not apply to Workers’ Compensation claims or to any claims that cannot be waived as a matter of law. Chase agrees to refrain from pursuing or escalating his concerns related to the assessment conducted by PwC in 2017. The Parties understand that nothing in this Agreement prohibits Chase’s participation in any investigation by a state, federal, or local agency or as otherwise required by law, such as pursuant to a subpoena or other valid legal process.

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4.2.The Companies, their Parents, subsidiaries and/or Affiliates, release Chase and his agents, attorneys, representatives, successors, heirs, executors, administrators, assigns and related parties (“Chase Releasees”), from all known and unknown claims, losses, liabilities, charges, demands, and causes of action, arising directly or indirectly out of or in any way connected with Chase’s employment with, or separation from, the Companies, that the Companies or any of its current or former parents, subsidiaries, affiliates, and current or former employees or agents, may presently have or which may accrue at any time before this Agreement becomes irrevocable by Chase. This release is intended to have the broadest possible application and includes, but is not limited to, any and all tort, contract, common law, constitutional, or other statutory claims, and any and all claims for attorney’s fees, costs and expenses. The claims the Company and its current or former parents, subsidiaries, affiliates, and current or former employees or agents are releasing include, for example, but are not limited to, the following: claims under any express or implied contract, including, without limitation, the January 24, 2017 offer letter and the Severance Pay Agreement, violation of any of Sempra Energy/Companies’ policies, practices, or procedures, all applicable anti-bribery and anti-corruption laws and regulations, and/or any other federal, state, or local common law, statute, regulation, or law of any other type. This subsection 4.2 does not apply to any claims that cannot be waived as a matter of law. The Parties understand that this Agreement does not prohibit its participation in any investigation by a state, federal, or local agency.

4.3. Waiver of California Civil Code Section 1542. The Parties expressly waive and relinquish all rights and benefits afforded by any statute (including, but not limited to, Section 1542 of the Civil Code of the State of California) which limits the effect of a release with respect to unknown claims. The Parties do so understanding and acknowledging the significance of their release of unknown claims and their waiver of statutory protection against a release of unknown claims. Section 1542 of the Civil Code of the State of California states as follows:

A GENERAL RELEASE DOES NOT EXTEND TO CLAIMS THAT THE CREDITOR OR RELEASING PARTY DOES NOT KNOW OR SUSPECT TO EXIST IN HIS OR HER FAVOR AT THE TIME OF EXECUTING THE RELEASE, AND THAT, IF KNOWN BY HIM OR HER WOULD HAVE MATERIALLY AFFECTED HIS OR HER SETTLEMENT WITH THE DEBTOR OR RELEASED PARTY.

Thus, notwithstanding the provisions of Section 1542 or of any similar statute, and for the purpose of implementing a full and complete release and discharge of the Releasees and Chase Releasees, the Parties expressly acknowledge that this Agreement is intended to include in its effect, without limitation, all Claims which are known to the Parties and all Claims which the Parties do not know or suspect to exist in their respective favor at the time of execution of this Agreement and that this Agreement contemplates the extinguishment of all such Claims.

5.Confidential Information. Chase acknowledges that by reason of his position with the Companies that he had access to information of a confidential or sensitive nature. Chase represents that he held all such information confidential and will continue to do so, except as required by subpoena or other valid legal process, provided he give the Companies sufficient notice to contest the subpoena or other legal process. In view of the nature of his employment, Chase agrees that the

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Companies would be irreparably harmed by any violation or threatened violation of this paragraph. The undertakings set forth in this paragraph shall survive the termination of benefits under this Agreement. However, this Agreement shall in no way be interpreted to restrain Chase from engaging in lawful profession, trade, or business of any kind within the meaning of California Business & Professions Code §16600. The Parties understand and agree that nothing in this Agreement is intended to interfere with or discourage Chase’s good-faith disclosure to any governmental entity related to a reasonably suspected violation of the law. The Parties further understand and agree that Chase cannot and will not be held criminally or civilly liable under any federal or state trade secret law for disclosing otherwise protected trade secrets and/or confidential or proprietary information so long as the disclosure is made in: (1) to a federal, state, or local government official, directly or indirectly, or to an attorney and solely for the purpose of reporting or investigating a suspected violation of law; (2) a complaint or other document filed in a lawsuit or other proceeding; and/or (3) as otherwise allowed by law. The Parties also agree that the Companies will not retaliate against Chase in any way for a disclosure made pursuant to this paragraph.

6.Mutual Non-Disparagement.

6.1.Chase agrees as of the date he signs this Agreement to not disparage, defame, or otherwise detrimentally comment upon the Companies, their parents, subsidiaries, and/or Affiliates, and/or any of their respective officers, directors or board members, financial condition, business, capabilities, and/or the ability to perform its business obligations, unless pursuant to a subpoena or court process. As used herein, the term “Affiliate” means any corporation, partnership, limited liability company, joint venture, or other entity of which an aggregate of twenty-five percent (25%) or more of the issued and outstanding capital stock or other equity interests is owned by the Companies.

6.2.The Companies agree that from the date on which this Agreement is fully executed, they will take reasonable steps to ensure that the following individuals: Dawn Andrews, Joyce Rowland, Patti Wagner, Deborah Martin, Randall Clark, Gillian Wright, Kevin Sagara, Scott Drury, Caroline Winn, David Geier, Scott Crider, Diana Day, Eugene “Mitch” Mitchell, Dan Skopec, Mike Schneider, Bruce Folkmann, Kendall Helm, John Jenkins, Angelica Espinosa, Estela De Llanos, Bret Lane, Jimmie Cho, Maryam Brown, Rodger Schweke, David Barrett, Paul Goldstein, Denita Willoughby, David Buczkowski, Gina Orozco, Neal Navin, Jawad Malik, Jeff Walker, Sandra Hrna, Sharon Tomkins, Joe Householder, Jeff Martin, Dennis Arrioloa, Trevor Mihalik, Peter Wall, Amy Chiu, Emily Shults, Karen Sedgwick, Gary Perlmutter, Janette Piankoff, Laura Georgantos, Ben Gordon, Dawn Welch, Andrew Raines, Chris Olmsted, Laura Atkinson, Gavin Worden, Tia Ballard, Jamie Exon, David Gillespie, Joe Shoffner, Charlie Snyder and Eric Trapp, will not disparage, defame, or otherwise detrimentally comment upon Chase.

7.Return of Companies Property. By signing this Agreement, Chase represents and agrees that he has returned or will immediately return or destroy all documents and information belonging to Companies that is not routinely given to all employees, whether the documents are on hard copy, tape, disk, or other method of storage. For any documents maintained electronically, Chase agrees to destroy any such documents and confirm destruction. Additionally, Chase represents and agrees that he has returned or will immediately return all memoranda, records, other documents, and

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physical or personal property, including identification and credit cards which he received from the Companies and which are the property of the Companies.

8.Arbitration of Disputes. This Agreement is entered in California and shall be governed by substantive California law, except as provided in this section. If any dispute arises between Chase and the Companies, including, but not limited to, disputes relating to this Agreement, or if the Parties prosecute a claim the party purported to release by means of this Agreement (“Arbitrable Dispute”), Chase and the Companies agree to resolve that Arbitrable Dispute through final and binding arbitration under this Section 8. The Parties also agree to arbitrate any Arbitrable Dispute which also involves any other released party who offers or agrees to arbitrate the dispute under this section. The Parties agreement to arbitrate applies, for example, to disputes about the validity, interpretation, or effect of this Agreement or alleged violations of it, claims of discrimination under federal or state law, or other statutory violation claims.

8.1.Arbitration shall take place in San Diego, California under the employment dispute resolution rules of the Judicial Arbitration and Mediation Service before an experienced employment arbitrator selected in accordance with those rules. The arbitrator may not modify or change this Agreement in any way. The Companies will be responsible for paying any filing fee and the fees and costs of the Arbitrator; provided, however, that if Chase is the party initiating the claim, he will contribute an amount equal to the filing fee to initiate a claim in the court of general jurisdiction in the state in which Chase was employed by the Companies. Each party shall pay for its own costs and attorneys’ fees, if any. However if any party prevails on a statutory claim which affords the prevailing party attorneys’ fees and costs, or if there is a written agreement providing for attorneys’ fees and/or costs, the Arbitrator may award reasonable attorneys’ fees and/or costs to the prevailing party, applying the same standards a court would apply under the law applicable to the claim. The Arbitrator shall apply the Federal Rules of Evidence and shall have the authority to entertain a motion to dismiss or a motion for summary judgment by any party and shall apply the standards governing such motions under the Federal Rules of Civil Procedure. The Federal Arbitration Act shall govern the arbitration and shall govern the interpretation or enforcement of this section or any arbitration award.

8.2.To the extent that the Federal Arbitration Act is inapplicable, California law pertaining to arbitration agreements shall apply. Arbitration in this manner shall be the exclusive remedy for any Arbitrable Dispute. Except as prohibited by the ADEA, should Chase or the Companies attempt to resolve an Arbitrable Dispute by any method other than arbitration pursuant to this section, the responding party will be entitled to recover from the initiating party all damages, expenses, and attorneys’ fees incurred as a result of this breach. This Section 8 supersedes any existing arbitration agreement between the Companies and Chase as to any Arbitrable Dispute. Notwithstanding anything in this Section 8 to the contrary, a claim for benefits under an ERISA-covered plan shall not be an Arbitrable Dispute.

9.Non-Publicity: As of the date signed by the Parties, the Parties agree that they will not publicize the terms of this Agreement, including by going to the press, posting on social media or websites, or otherwise advertising or marketing the terms of this Agreement in any manner, medium, and/or forum. The Parties agree and acknowledge this provision is a material term of the Agreement,

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the absence of which would have resulted in the other party refusing to enter into this Agreement. The Companies shall in no way be deemed to have breached this provision by communicating this Agreement to their Boards of Directors and/or by including it in any securities filings (including as an exhibit) deemed necessary given Chase’s status as a Named Executive Officer of the Companies under applicable securities laws and regulations. Nor shall Companies be deemed to have breached this provision by communicating to the individuals named in Section 6.2 that they have an obligation not to disparage, defame, or otherwise detrimentally comment upon Chase.

10.Future Issues. This Agreement shall not in any way be construed as an admission by the Companies, their Parents, and/or Affiliates that they or their employees, officers, or directors have acted wrongfully with respect to Chase or any other person, or that Chase has any rights whatsoever against the Companies, and the Companies specifically disclaim any liability to or wrongful acts against Chase or any other person, on the part of themselves, their employees, or their agents. This Agreement shall not in any way be construed as an admission by Chase that he acted wrongfully with respect to the Companies, or that he failed to perform his duties or negligently performed or breached his duties in any way, and Chase specifically disclaims any liability or wrongful acts against the Companies or any other person on the part of himself or his agents.

10.1.If Chase is a party or is threatened to be made a party to any proceeding by reason of the fact that Chase was an officer or director of the Companies, the Companies shall indemnify Chase against any expenses (including reasonable attorneys’ fees; provided, that counsel has been approved by the Companies prior to retention, which approval shall not be unreasonably withheld), judgments, fines, settlements, and other amounts actually or reasonably incurred by Chase in connection with that proceeding; provided, further, that Chase acted in good faith and in a manner Chase reasonably believed to be in the best interest of the Companies. The limitations of Section 317 of the Corporations Code of the State of California shall apply to this assurance of indemnification. For avoidance of any doubt, Chase’s current legal counsel at Haeggquist & Eck, LLP (offices located at 225 Broadway, Suite 2050, San Diego, CA 92101) is pre-approved by Companies to represent Chase on any future matters as outlined in this section provided no currently unknown conflicts exist or arise that would preclude such representation.

10.2.Chase agrees to cooperate with the Companies and their designated attorneys, representatives, and agents in connection with any actual or threatened judicial, administrative, or other legal or equitable proceeding in which the Companies are or may become involved. Upon reasonable notice, Chase agrees to meet with and provide to the Companies or their designated attorneys, representatives, or agents all information and knowledge Chase has relating to the subject matter of any such proceeding. The Companies agree to reimburse Chase for any reasonable costs incurred in providing such cooperation.

11.Integration. Except as set forth in the Employment, Confidential Information, and Invention Assignment Agreement signed by Chase on January 26, 2017, the Confidentiality Agreement signed by Chase on March 6, 2017, and the Confidential Information and Invention Assignment Agreement signed by Chase on June 18, 2018, the Parties agree that this Agreement contains their entire agreement and supersedes all other agreements and understandings, whether written or oral, covering the subject matter hereof. The Parties warrant that there were no

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representations, agreements, arrangements, or understandings, whether written or oral, between them relating to the subject matter contained in this Agreement which are not fully expressed herein. No modification, amendment, or waiver of any of the provisions contained in this Agreement, or any future presentations, promises, or conditions in connection with the subject matter of this Agreement, shall be binding upon any party to this Agreement unless made in writing and signed by all Parties to this Agreement.

12.Review and Revocation Periods. Chase understands that he should take this Agreement home, read it, and carefully consider all its terms before signing it. The Companies gave Chase twenty-one (21) days in which to consider this Agreement. Chase waives any right he might have to additional time beyond this consideration period within which to consider this Agreement. Chase further understands that the Companies advised him to discuss this agreement with his own attorney (at his own expense) during this period if he wished to do so. Chase understands that he may revoke this Agreement within seven (7) days after he signs it by delivering a written notice of revocation to Scott Drury at San Diego Gas & Electric Company, 8330 Century Park Court, San Diego, CA 92123-1530 or sdrury@semprautilities.com, in which case Chase will not receive the Severance Payment.

THE PARTIES, WITH THE BENEFIT OF REPRESENTATION AND ADVICE OF COUNSEL, HAVE READ THIS AGREEMENT AND FULLY UNDERSTAND EACH AND EVERY PROVISION CONTAINED IN IT. THE PARTIES ARERECEIVING VALUABLE CONSIDERATION IN EXCHANGE FOR THEIREXECUTION OF THIS AGREEMENT THAT THEY WOULD NOT OTHERWISE BE ENTITLED TO RECEIVE.

APPROVED AND ACCEPTED:

Date:	April 19, 2019	By: /s/ P. Kevin Chase
		P. Kevin Chase
Date:	April 19, 2019	By: /s/ Scott D. Drury
		Scott D. Drury, President San Diego Gas & Electric Company
Date:	April 19, 2019	By: /s/ J. Bret Lane
		J. Bret Lane, CEO Southern California Gas Company

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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.

May 7, 2019	/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.

May 7, 2019	/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, Kevin C. Sagara, 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.

May 7, 2019	/s/  Kevin C. Sagara
	Kevin C. Sagara
	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.

May 7, 2019	/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, J. Bret Lane, 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.

May 7, 2019	/s/  J. Bret Lane
	J. Bret Lane
	Chief Executive Officer

EX-31.6

EXHIBIT 31.6

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 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.

May 7, 2019	/s/  Bruce A. Folkmann
	Bruce A. Folkmann
	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 March 31, 2019 (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.

May 7, 2019	/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 March 31, 2019 (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.

May 7, 2019	/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 March 31, 2019 (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.

May 7, 2019	/s/  Kevin C. Sagara
	Kevin C. Sagara
	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 March 31, 2019 (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.

May 7, 2019	/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 March 31, 2019 (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.

May 7, 2019	/s/  J. Bret Lane
	J. Bret Lane
	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 March 31, 2019 (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.

May 7, 2019	/s/  Bruce A. Folkmann
	Bruce A. Folkmann
	Chief Financial Officer

XML

DOCUMENT AND ENTITY INFORMATION - shares	3 Months Ended
	Mar. 31, 2019	May 02, 2019
Document And Entity Information [Abstract]
Entity Registrant Name	Sempra Energy
Document Type	10-Q
Document Period End Date	Mar. 31, 2019
Amendment Flag	false
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Shares Outstanding		274,388,245
Entity Central Index Key	0001032208

XML

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
REVENUES
Utilities operating revenue	$ 2,515	$ 2,190
Energy-related businesses	383	346
Total revenues	2,898	2,536
Operating expenses
Operation and maintenance	(832)	(741)
Depreciation and amortization	(383)	(372)
Franchise fees and other taxes	(130)	(117)
Operating expenses
Other income, net	82	152
Interest income	21	29
Interest expense	(260)	(206)
Income from continuing operations before income taxes and equity earnings (losses) of unconsolidated entities	501	593
Income tax expense	(42)	(242)
Equity earnings (losses)	101	(21)
Income from continuing operations, net of income tax	560	330
(Loss) income from discontinued operations, net of income tax	(42)	28
Net income	518	358
(Earnings) losses attributable to noncontrolling interest	(41)	17
Mandatory convertible preferred stock dividends	(36)	(28)
Earnings attributable to common shares	$ 441	$ 347
Basic earnings (losses) per common share:
Earnings from continuing operations attributable to common shares (in usd per share)	$ 1.79	$ 1.26
(Losses) earnings from discontinued operations attributable to common shares (in usd per share)	(0.19)	0.08
Earnings attributable to common shares (in usd per share)	$ 1.60	$ 1.34
Weighted-average common shares outstanding	274,674	257,932
Earnings Per Share, Diluted [Abstract]
Earnings from continuing operations attributable to common shares (in usd per share)	$ 1.78	$ 1.25
(Losses) earnings from discontinued operations attributable to common shares (in usd per share)	(0.19)	0.08
Earnings from continuing operations attributable to common shares (n usd per share)	$ 1.59	$ 1.33
Weighted-average common share outstanding, diluted	277,228	259,490
Natural gas [Member]
Operating expenses
Operating expenses	$ (531)	$ (348)
Electric fuel and purchased power [Member]
Operating expenses
Operating expenses	(256)	(271)
Energy-related businesses [Member]
Operating expenses
Operating expenses	(108)	(69)
San Diego Gas and Electric Company [Member]
REVENUES
Electric	940	884
Natural gas	205	171
Utilities operating revenue	1,145	1,055
Operating expenses
Cost of electric fuel and purchased power	258	274
Cost of natural gas	79	50
Operation and maintenance	286	248
Depreciation and amortization	186	166
Franchise fees and other taxes	74	69
Total operating expenses	883	807
Operating income	262	248
Other income, net	22	28
Interest income	1	1
Interest expense	(103)	(52)
Income from continuing operations before income taxes and equity earnings (losses) of unconsolidated entities	182	225
Income tax expense	(5)	(56)
Net income	177	169
(Earnings) losses attributable to noncontrolling interest	(1)	1
Earnings attributable to common shares	176	170
Southern California Gas Company [Member]
REVENUES
Utilities operating revenue	1,361	1,126
Operating expenses
Cost of natural gas	455	289
Operation and maintenance	410	384
Depreciation and amortization	147	135
Franchise fees and other taxes	48	40
Total operating expenses	1,060	848
Operating income	301	278
Other income, net	16	33
Interest expense	(34)	(27)
Income from continuing operations before income taxes and equity earnings (losses) of unconsolidated entities	283	284
Income tax expense	(19)	(59)
Net income	264	225
Earnings attributable to common shares	$ 264	$ 225

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Net income (loss)	$ 518	$ 358
Other comprehensive income (loss):
Total other comprehensive (loss) income	(11)	99
Pretax amount [Member]
Net income (loss)	670	664
Other comprehensive income (loss):
Foreign currency translation adjustments	32	24
Financial instruments	(68)	88
Pension and other postretirement benefits	4	3
Total other comprehensive (loss) income	(32)	115
Comprehensive income (loss)	638	779
Income tax (expense) benefit [Member]
Net income (loss)	(193)	(289)
Other comprehensive income (loss):
Foreign currency translation adjustments	0	0
Financial instruments	22	(30)
Pension and other postretirement benefits	(1)	(1)
Total other comprehensive (loss) income	21	(31)
Comprehensive income (loss)	(172)	(320)
Net-of-tax amount [Member]
Net income (loss)	477	375
Other comprehensive income (loss):
Foreign currency translation adjustments	32	24
Financial instruments	(46)	58
Pension and other postretirement benefits	3	2
Total other comprehensive (loss) income	(11)	84
Comprehensive income (loss)	466	459
Noncontrolling Interests (after-tax) [Member]
Net income (loss)	41	(17)
Other comprehensive income (loss):
Foreign currency translation adjustments	4	5
Financial instruments	(4)	10
Pension and other postretirement benefits	0	0
Total other comprehensive (loss) income	0	15
Comprehensive income (loss)	41	(2)
Total [Member]
Net income (loss)	518	358
Other comprehensive income (loss):
Foreign currency translation adjustments	36	29
Financial instruments	(50)	68
Pension and other postretirement benefits	3	2
Total other comprehensive (loss) income	(11)	99
Comprehensive income (loss)	507	457
San Diego Gas and Electric Company [Member]
Net income (loss)	177	169
Other comprehensive income (loss):
Total other comprehensive (loss) income	1	4
San Diego Gas and Electric Company [Member] | Pretax amount [Member]
Net income (loss)	181	226
Other comprehensive income (loss):
Financial instruments	0	0
Total other comprehensive (loss) income	0	0
Comprehensive income (loss)	181	226
San Diego Gas and Electric Company [Member] | Income tax (expense) benefit [Member]
Net income (loss)	(5)	(56)
Other comprehensive income (loss):
Financial instruments	0	0
Total other comprehensive (loss) income	0	0
Comprehensive income (loss)	(5)	(56)
San Diego Gas and Electric Company [Member] | Net-of-tax amount [Member]
Net income (loss)	176	170
Other comprehensive income (loss):
Financial instruments	0	0
Total other comprehensive (loss) income	0	0
Comprehensive income (loss)	176	170
San Diego Gas and Electric Company [Member] | Noncontrolling Interests (after-tax) [Member]
Net income (loss)	1	(1)
Other comprehensive income (loss):
Financial instruments	1	4
Total other comprehensive (loss) income	1	4
Comprehensive income (loss)	2	3
San Diego Gas and Electric Company [Member] | Total [Member]
Net income (loss)	177	169
Other comprehensive income (loss):
Financial instruments	1	4
Total other comprehensive (loss) income	1	4
Comprehensive income (loss)	178	173
Southern California Gas Company [Member]
Net income (loss)	264	225
Southern California Gas Company [Member] | Pretax amount [Member]
Other comprehensive income (loss):
Comprehensive income (loss)	283	284
Southern California Gas Company [Member] | Income tax (expense) benefit [Member]
Other comprehensive income (loss):
Comprehensive income (loss)	(19)	(59)
Southern California Gas Company [Member] | Net-of-tax amount [Member]
Other comprehensive income (loss):
Comprehensive income (loss)	$ 264	$ 225

XML

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($)	Mar. 31, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 78,000,000	$ 102,000,000	[1]
Restricted cash	41,000,000	35,000,000	[1]
Accounts receivable – trade, net	1,222,000,000	1,215,000,000	[1]
Accounts receivable – other, net	320,000,000	320,000,000	[1]
Due from unconsolidated affiliates	50,000,000	37,000,000	[1]
Income taxes receivable	121,000,000	60,000,000	[1]
Inventories	189,000,000	258,000,000	[1]
Regulatory assets	87,000,000	138,000,000	[1]
Greenhouse gas allowances	61,000,000	59,000,000	[1]
Other	262,000,000	249,000,000	[1]
Total current assets	3,262,000,000	3,645,000,000	[1]
Other assets:
Restricted cash	21,000,000	21,000,000	[1]
Due from unconsolidated affiliates	668,000,000	644,000,000	[1]
Regulatory assets	1,838,000,000	1,589,000,000	[1]
Nuclear decommissioning trusts	1,037,000,000	974,000,000	[1]
Investment in Oncor Holdings	9,748,000,000	9,652,000,000	[1]
Other investments	2,290,000,000	2,320,000,000	[1]
Goodwill	1,602,000,000	1,602,000,000	[1]
Other intangible assets	222,000,000	224,000,000	[1]
Dedicated assets in support of certain benefit plans	413,000,000	416,000,000	[1]
Insurance receivable for Aliso Canyon costs	477,000,000	461,000,000	[1]
Deferred income taxes	139,000,000	141,000,000	[1]
Greenhouse gas allowances	353,000,000	289,000,000	[1]
Right-of-use assets – operating leases	612,000,000
Assets held for sale in discontinued operations	3,388,000,000	3,259,000,000	[1]
Sundry	850,000,000	962,000,000	[1]
Total other assets	23,658,000,000	22,554,000,000	[1]
Property, plant and equipment:
Property, plant and equipment	47,105,000,000	46,615,000,000	[1]
Less accumulated depreciation and amortization	(12,407,000,000)	(12,176,000,000)	[1]
Property, plant and equipment, net	34,698,000,000	34,439,000,000	[1]
Total assets	61,618,000,000	60,638,000,000	[1]
Current liabilities:
Short-term debt	2,523,000,000	2,024,000,000	[1]
Accounts payable – trade	989,000,000	1,160,000,000	[1]
Accounts payable – other	166,000,000	138,000,000	[1]
Due to unconsolidated affiliates	10,000,000	10,000,000	[1]
Dividends and interest payable	496,000,000	480,000,000	[1]
Accrued compensation and benefits	264,000,000	440,000,000	[1]
Regulatory liabilities	523,000,000	105,000,000	[1]
Current portion of long-term debt and finance leases	2,152,000,000	1,644,000,000	[1]
Reserve for Aliso Canyon costs	60,000,000	160,000,000	[1]
Greenhouse gas obligations	61,000,000	59,000,000	[1]
Liabilities held for sale in discontinued operations	375,000,000	368,000,000	[1]
Other	993,000,000	935,000,000	[1]
Total current liabilities	8,612,000,000	7,523,000,000	[1]
Long-term debt and finance leases	19,738,000,000	20,903,000,000	[1]
Deferred credits and other liabilities:
Due to unconsolidated affiliates	38,000,000	37,000,000	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	1,155,000,000	1,143,000,000	[1]
Deferred income taxes	2,622,000,000	2,321,000,000	[1]
Deferred investment tax credits	23,000,000	24,000,000	[1]
Regulatory liabilities	3,996,000,000	4,016,000,000	[1]
Asset retirement obligations	2,795,000,000	2,786,000,000	[1]
Greenhouse gas obligations	174,000,000	131,000,000	[1]
Liabilities held for sale in discontinued operations	1,046,000,000	1,013,000,000	[1]
Deferred credits and other	1,949,000,000	1,493,000,000	[1]
Total deferred credits and other liabilities	13,798,000,000	12,964,000,000	[1]
Commitments and contingencies (Note 11)			[1]
Equity:
Common stock	5,568,000,000	5,540,000,000	[1]
Retained earnings	10,337,000,000	10,104,000,000	[1]
Accumulated other comprehensive income (loss)	(817,000,000)	(764,000,000)	[1]
Total shareholders’ equity	17,346,000,000	17,138,000,000	[1]
Preferred stock of subsidiary	20,000,000	20,000,000	[1]
Other noncontrolling interests	2,104,000,000	2,090,000,000	[1]
Total equity	19,470,000,000	19,248,000,000	[1]
Total liabilities and equity	61,618,000,000	60,638,000,000	[1]
San Diego Gas and Electric Company [Member]
Current assets:
Cash and cash equivalents	10,000,000	8,000,000	[1]
Restricted cash	21,000,000	11,000,000	[1]
Accounts receivable – trade, net	390,000,000	368,000,000	[1]
Accounts receivable – other, net	96,000,000	106,000,000	[1]
Inventories	99,000,000	102,000,000	[1]
Prepaid expenses	53,000,000	74,000,000	[1]
Regulatory assets	71,000,000	123,000,000	[1]
Fixed-price contracts and other derivatives	66,000,000	82,000,000	[1]
Greenhouse gas allowances	15,000,000	15,000,000	[1]
Other	26,000,000	5,000,000	[1]
Total current assets	847,000,000	894,000,000	[1]
Other assets:
Restricted cash	18,000,000	18,000,000	[1]
Regulatory assets	467,000,000	454,000,000	[1]
Nuclear decommissioning trusts	1,037,000,000	974,000,000	[1]
Greenhouse gas allowances	169,000,000	155,000,000	[1]
Right-of-use assets – operating leases	135,000,000
Sundry	421,000,000	420,000,000	[1]
Total other assets	2,247,000,000	2,021,000,000	[1]
Property, plant and equipment:
Property, plant and equipment	21,950,000,000	21,662,000,000	[1]
Less accumulated depreciation and amortization	(5,486,000,000)	(5,352,000,000)	[1]
Property, plant and equipment, net	16,464,000,000	16,310,000,000	[1]
Total assets	19,558,000,000	19,225,000,000	[1]
Current liabilities:
Short-term debt	238,000,000	291,000,000	[1]
Accounts payable	360,000,000	439,000,000	[1]
Due to unconsolidated affiliates	63,000,000	61,000,000	[1]
Accrued compensation and benefits	52,000,000	117,000,000	[1]
Accrued franchise fees	60,000,000	64,000,000	[1]
Regulatory liabilities	47,000,000	53,000,000	[1]
Current portion of long-term debt and finance leases	89,000,000	81,000,000	[1]
Customer deposits	70,000,000	70,000,000	[1]
Greenhouse gas obligations	15,000,000	15,000,000	[1]
Asset retirement obligations	93,000,000	96,000,000	[1]
Other	280,000,000	141,000,000	[1]
Total current liabilities	1,367,000,000	1,428,000,000	[1]
Long-term debt and finance leases	6,113,000,000	6,138,000,000	[1]
Deferred credits and other liabilities:
Pension and other postretirement benefit plan obligations, net of plan assets	217,000,000	212,000,000	[1]
Deferred income taxes	1,653,000,000	1,616,000,000	[1]
Deferred investment tax credits	15,000,000	16,000,000	[1]
Regulatory liabilities	2,470,000,000	2,404,000,000	[1]
Asset retirement obligations	777,000,000	778,000,000	[1]
Greenhouse gas obligations	43,000,000	30,000,000	[1]
Deferred credits and other	610,000,000	488,000,000	[1]
Total deferred credits and other liabilities	5,785,000,000	5,544,000,000	[1]
Commitments and contingencies (Note 11)			[1]
Equity:
Preferred stock	0	0	[1]
Common stock	1,338,000,000	1,338,000,000	[1]
Retained earnings	4,865,000,000	4,687,000,000	[1]
Accumulated other comprehensive income (loss)	(12,000,000)	(10,000,000)	[1]
Total shareholders’ equity	6,191,000,000	6,015,000,000	[1]
Other noncontrolling interests	102,000,000	100,000,000	[1]
Total equity	6,293,000,000	6,115,000,000	[1]
Total liabilities and equity	19,558,000,000	19,225,000,000	[1]
Southern California Gas Company [Member]
Current assets:
Cash and cash equivalents	3,000,000	18,000,000	[1]
Accounts receivable – trade, net	674,000,000	634,000,000	[1]
Accounts receivable – other, net	91,000,000	97,000,000	[1]
Due from unconsolidated affiliates	15,000,000	7,000,000	[1]
Inventories	58,000,000	134,000,000	[1]
Regulatory assets	11,000,000	12,000,000	[1]
Greenhouse gas allowances	39,000,000	37,000,000	[1]
Other	39,000,000	31,000,000	[1]
Total current assets	930,000,000	970,000,000	[1]
Other assets:
Regulatory assets	1,286,000,000	1,051,000,000	[1]
Insurance receivable for Aliso Canyon costs	477,000,000	461,000,000	[1]
Greenhouse gas allowances	164,000,000	116,000,000	[1]
Right-of-use assets – operating leases	110,000,000
Sundry	356,000,000	352,000,000	[1]
Total other assets	2,393,000,000	1,980,000,000	[1]
Property, plant and equipment:
Property, plant and equipment	18,347,000,000	18,138,000,000	[1]
Less accumulated depreciation and amortization	(5,766,000,000)	(5,699,000,000)	[1]
Property, plant and equipment, net	12,581,000,000	12,439,000,000	[1]
Total assets	15,904,000,000	15,389,000,000	[1]
Current liabilities:
Short-term debt	190,000,000	256,000,000	[1]
Accounts payable – trade	427,000,000	556,000,000	[1]
Accounts payable – other	98,000,000	93,000,000	[1]
Due to unconsolidated affiliates	42,000,000	34,000,000	[1]
Accrued compensation and benefits	101,000,000	159,000,000	[1]
Regulatory liabilities	476,000,000	52,000,000	[1]
Current portion of long-term debt and finance leases	3,000,000	3,000,000	[1]
Customer deposits	71,000,000	101,000,000	[1]
Reserve for Aliso Canyon costs	60,000,000	160,000,000	[1]
Greenhouse gas obligations	39,000,000	37,000,000	[1]
Asset retirement obligations	90,000,000	90,000,000	[1]
Other	333,000,000	217,000,000	[1]
Total current liabilities	1,930,000,000	1,758,000,000	[1]
Long-term debt and finance leases	3,429,000,000	3,427,000,000	[1]
Deferred credits and other liabilities:
Pension obligation, net of plan assets	773,000,000	760,000,000	[1]
Deferred income taxes	1,204,000,000	1,177,000,000	[1]
Deferred investment tax credits	8,000,000	8,000,000	[1]
Regulatory liabilities	1,526,000,000	1,612,000,000	[1]
Asset retirement obligations	1,982,000,000	1,973,000,000	[1]
Greenhouse gas obligations	110,000,000	86,000,000	[1]
Deferred credits and other	422,000,000	330,000,000	[1]
Total deferred credits and other liabilities	6,025,000,000	5,946,000,000	[1]
Commitments and contingencies (Note 11)			[1]
Equity:
Preferred stock	22,000,000	22,000,000	[1]
Common stock	866,000,000	866,000,000	[1]
Retained earnings	3,656,000,000	3,390,000,000	[1]
Accumulated other comprehensive income (loss)	(24,000,000)	(20,000,000)	[1]
Total shareholders’ equity	4,520,000,000	4,258,000,000	[1]
Total equity	4,520,000,000	4,258,000,000
Total liabilities and equity	15,904,000,000	15,389,000,000	[1]
Convertible Preferred Stock Series A [Member]
Equity:
Preferred stock	1,693,000,000	1,693,000,000	[1]
Convertible Preferred Stock Series B [Member]
Equity:
Preferred stock	565,000,000	565,000,000	[1]
Disposal Group Held-for-sale [Member]
Current assets:
Assets held for sale in discontinued operations	374,000,000	713,000,000	[1]
Disposal Group Held-for-sale [Member]
Current assets:
Assets held for sale in discontinued operations	$ 457,000,000	$ 459,000,000	[1]

[1] Derived from audited financial statements.

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CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
Current portion of long-term debt and finance leases	$ 2,152	$ 1,644	[1]
Property, plant and equipment, net	34,698	34,439	[1]
Long-term debt and finance leases	$ 19,738	$ 20,903	[1]
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)	274,000,000	274,000,000
Otay Mesa VIE [Member]
Current portion of long-term debt and finance leases	$ 36	$ 28
Property, plant and equipment, net	287	295
Long-term debt and finance leases	182	190
San Diego Gas and Electric Company [Member]
Current portion of long-term debt and finance leases	89	81	[1]
Property, plant and equipment, net	16,464	16,310	[1]
Long-term debt and finance leases	$ 6,113	$ 6,138	[1]
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
San Diego Gas and Electric Company [Member] | Otay Mesa VIE [Member]
Current portion of long-term debt and finance leases	$ 36	$ 28
Property, plant and equipment, net	287	295
Long-term debt and finance leases	182	190
Southern California Gas Company [Member]
Current portion of long-term debt and finance leases	3	3	[1]
Property, plant and equipment, net	12,581	12,439	[1]
Long-term debt and finance leases	$ 3,429	$ 3,427	[1]
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	11,000,000	11,000,000
Preferred stock, shares issued (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, Dividend Rate, Percentage	6.00%	6.00%
Preferred stock, shares issued (in shares)	17,250,000	17,250,000
Preferred stock, shares outstanding (in shares)	17,250,000	17,250,000
Convertible Preferred Stock Series B [Member]
Stockholders' Equity Attributable to Parent [Abstract]
Preferred Stock, Dividend Rate, Percentage	6.75%	6.75%
Preferred stock, shares issued (in shares)	5,750,000	5,750,000
Preferred stock, shares outstanding (in shares)	5,750,000	5,750,000

[1] Derived from audited financial statements.

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 518,000,000	$ 358,000,000
Loss (income) from discontinued operations, net of income tax	42,000,000	(28,000,000)
Income from continuing operations, net of income tax	560,000,000	330,000,000
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	383,000,000	372,000,000
Deferred income taxes and investment tax credits	24,000,000	202,000,000
Equity (earnings) losses	(101,000,000)	21,000,000
Share-based compensation expense	21,000,000	15,000,000
Fixed-price contracts and other derivatives	(27,000,000)	(35,000,000)
Other	13,000,000	7,000,000
Intercompany activities with discontinued operations, net	31,000,000	0
Net change in other working capital components	169,000,000	101,000,000
Insurance receivable for Aliso Canyon costs	(16,000,000)	(29,000,000)
Changes in other noncurrent assets and liabilities, net	(199,000,000)	(94,000,000)
Net cash provided by continuing operations	858,000,000	890,000,000
Net cash provided by discontinued operations	93,000,000	76,000,000
Net cash provided by operating activities	951,000,000	966,000,000
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(783,000,000)	(979,000,000)
Expenditures for investments and acquisitions, net of cash and cash equivalents acquired	(94,000,000)	(9,617,000,000)
Proceeds from sale of assets	327,000,000	0
Purchases of nuclear decommissioning trust assets	(225,000,000)	(210,000,000)
Proceeds from sales by nuclear decommissioning trusts	225,000,000	210,000,000
Advances to unconsolidated affiliates	0	(81,000,000)
Repayments of advances to unconsolidated affiliates	3,000,000	1,000,000
Intercompany activities with discontinued operations, net	0	(3,000,000)
Other	7,000,000	35,000,000
Net cash used in continuing operations	(540,000,000)	(10,644,000,000)
Net cash used in discontinued operations	(70,000,000)	(58,000,000)
Net cash used in investing activities	(610,000,000)	(10,702,000,000)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(232,000,000)	(194,000,000)
Preferred dividends paid	(36,000,000)	0
Issuances of mandatory convertible preferred stock, net of $32 in offering costs	0	1,693,000,000
Issuances of common stock, net of $24 in offering costs in 2018	11,000,000	1,278,000,000
Repurchases of common stock	(14,000,000)	(19,000,000)
Issuances of debt (maturities greater than 90 days)	304,000,000	5,949,000,000
Payments on debt (maturities greater than 90 days) and finance leases	(837,000,000)	(154,000,000)
Payments on finance leases	(5,000,000)
Increase (decrease) in short-term debt, net	497,000,000	1,149,000,000
Purchases of and distributions to noncontrolling interests	(27,000,000)	(3,000,000)
Intercompany activities with discontinued operations, net	(2,000,000)	67,000,000
Other	0	(82,000,000)
Net cash (used in) provided by continuing operations	(336,000,000)	9,684,000,000
Net cash used in discontinued operations	(45,000,000)	(6,000,000)
Net cash (used in) provided by financing activities	(381,000,000)	9,678,000,000
Effect of exchange rate changes in continuing operations	0	1,000,000
Effect of exchange rate changes in discontinued operations	1,000,000	0
Effect of exchange rate changes on cash, cash equivalents and restricted cash	1,000,000	1,000,000
Increase (decrease) in cash, cash equivalents and restricted cash, including discontinued operations	(39,000,000)	(57,000,000)
Cash, cash equivalents and restricted cash, including discontinued operations, January 1	246,000,000	364,000,000
Cash, cash equivalents and restricted cash, including discontinued operations, March 31	207,000,000	307,000,000
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	257,000,000	108,000,000
Income tax payments, net of refunds	16,000,000	18,000,000
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Assets acquired	0	9,670,000,000
Liabilities assumed	0	(104,000,000)
Cash paid	0	9,566,000,000
Accrued capital expenditures	388,000,000	316,000,000
Accrued Merger-related transaction and financing costs	0	6,000,000
Increase in finance lease obligations for investment in property, plant and equipment	7,000,000	5,000,000
Common dividends issued in stock	13,000,000	13,000,000
Preferred stock [Member]
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends declared but not paid	36,000,000	28,000,000
Common Stock [Member]
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends declared but not paid	265,000,000	236,000,000
San Diego Gas and Electric Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	177,000,000	169,000,000
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	186,000,000	166,000,000
Deferred income taxes and investment tax credits	(28,000,000)	(11,000,000)
Other	1,000,000	3,000,000
Net change in other working capital components	96,000,000	102,000,000
Changes in other noncurrent assets and liabilities, net	11,000,000	(25,000,000)
Net cash provided by operating activities	443,000,000	404,000,000
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(356,000,000)	(475,000,000)
Purchases of nuclear decommissioning trust assets	(225,000,000)	(210,000,000)
Proceeds from sales by nuclear decommissioning trusts	225,000,000	210,000,000
Net cash used in investing activities	(356,000,000)	(475,000,000)
CASH FLOWS FROM FINANCING ACTIVITIES
Payments on debt (maturities greater than 90 days) and finance leases	(22,000,000)	(20,000,000)
Payments on finance leases	(4,000,000)
Increase (decrease) in short-term debt, net	(53,000,000)	87,000,000
Net cash (used in) provided by financing activities	(75,000,000)	67,000,000
Increase (decrease) in cash, cash equivalents and restricted cash, including discontinued operations	12,000,000	(4,000,000)
Cash, cash equivalents and restricted cash, including discontinued operations, January 1	37,000,000	29,000,000
Cash, cash equivalents and restricted cash, including discontinued operations, March 31	49,000,000	25,000,000
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	86,000,000	39,000,000
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	100,000,000	97,000,000
Increase in finance lease obligations for investment in property, plant and equipment	4,000,000	0
Southern California Gas Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	264,000,000	225,000,000
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	147,000,000	135,000,000
Deferred income taxes and investment tax credits	(65,000,000)	47,000,000
Other	5,000,000	21,000,000
Net change in other working capital components	287,000,000	76,000,000
Insurance receivable for Aliso Canyon costs	(16,000,000)	(29,000,000)
Changes in other noncurrent assets and liabilities, net	(246,000,000)	(56,000,000)
Net cash provided by operating activities	376,000,000	419,000,000
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(324,000,000)	(403,000,000)
Other	0	3,000,000
Net cash used in investing activities	(324,000,000)	(400,000,000)
CASH FLOWS FROM FINANCING ACTIVITIES
Payments on finance leases	(1,000,000)	0
Increase (decrease) in short-term debt, net	(66,000,000)	(16,000,000)
Net cash (used in) provided by financing activities	(67,000,000)	(16,000,000)
Increase (decrease) in cash, cash equivalents and restricted cash, including discontinued operations	(15,000,000)	3,000,000
Cash, cash equivalents and restricted cash, including discontinued operations, January 1	18,000,000	8,000,000
Cash, cash equivalents and restricted cash, including discontinued operations, March 31	3,000,000	11,000,000
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	26,000,000	18,000,000
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	163,000,000	159,000,000
Increase in finance lease obligations for investment in property, plant and equipment	$ 3,000,000	$ 5,000,000

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) $ in Millions	3 Months Ended
	Mar. 31, 2018 USD ($)
Convertible Preferred Stock [Member]
Offering costs	$ 32
Common Stock [Member]
Offering costs	$ 24

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CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total		Series A Preferred Stock [Member]	Series B Preferred Stock [Member]	Preferred stock [Member]	Preferred stock [Member] Series A Preferred Stock [Member]	Common Stock [Member]	Retained earnings [Member]	Retained earnings [Member] Series A Preferred Stock [Member]	Retained earnings [Member] Series B 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]	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]	San Diego Gas and Electric Company [Member] Noncontrolling Interest [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 adjustment from change in accounting principle	$ (1)							$ 2			$ (3)	$ (1)
Beginning Balance at Dec. 31, 2017	15,140				$ 0		$ 3,149	10,147			(626)	12,670			$ 2,470	$ 5,626		$ 1,338	$ 4,268	$ (8)	$ 5,598	$ 28	$ 3,907	$ 22	$ 866	$ 3,040	$ (21)
Net income (loss)	358							375				375			(17)	169			170		170	(1)	225			225
Other comprehensive (loss) income	99										84	84			15	4						4
Share-based compensation expense	15						15					15
Preferred stock dividends declared			$ (28)						$ (28)				$ (28)										0			0
Common stock dividends declared	(236)							(236)				(236)
Issuances of stock	1,291		1,693			$ 1,693	1,291					1,291	1,693
Repurchases of common stock	(19)						(19)					(19)
Noncontrolling interests activities: Distributions	(7)														(7)	(1)						(1)
Ending balance at Mar. 31, 2018	18,305				1,693		4,436	10,260			(545)	15,844			2,461	5,798		1,338	4,438	(8)	5,768	30	4,132	22	866	3,265	(21)
Cumulative-effect adjustment from change in accounting principle	15							57			(42)	15				0			2	(2)	0		(2)			2	(4)
Beginning Balance at Dec. 31, 2018	19,248	[1]			2,258		5,540	10,104			(764)	17,138			2,110	6,115	[1]	1,338	4,687	(10)	6,015	100	4,258	22	866	3,390	(20)
Net income (loss)	518							477				477			41	177			176		176	1	264			264
Other comprehensive (loss) income	(11)										(11)	(11)				1						1
Share-based compensation expense	21						21					21
Preferred stock dividends declared			$ (26)	$ (10)					$ (26)	$ (10)			$ (26)	$ (10)									0			0
Common stock dividends declared	(265)							(265)				(265)
Issuances of stock	24						24					24
Repurchases of common stock	(14)						(14)					(14)
Noncontrolling interests activities: Distributions	(4)														(4)
Noncontrolling interests activities: Purchase	(26)						(3)					(3)			(23)
Ending balance at Mar. 31, 2019	$ 19,470				$ 2,258		$ 5,568	$ 10,337			$ (817)	$ 17,346			$ 2,124	$ 6,293		$ 1,338	$ 4,865	$ (12)	$ 6,191	$ 102	$ 4,520	$ 22	$ 866	$ 3,656	$ (24)

[1] Derived from audited financial statements.

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CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Dividends declared per share of common stock (in dollars per share)	$ 0.97	$ 0.90
Southern California Gas Company [Member]
Dividends declared per share of preferred stock (in dollars per share)	0.38	0.38
Series A Preferred Stock [Member]
Dividends declared per share of preferred stock (in dollars per share)	1.5	$ 1.60
Series B Preferred Stock [Member]
Dividends declared per share of preferred stock (in dollars per share)	$ 1.69

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GENERAL INFORMATION AND OTHER FINANCIAL DATA

3 Months Ended

Mar. 31, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

GENERAL INFORMATION AND OTHER FINANCIAL DATA

GENERAL INFORMATION AND OTHER FINANCIAL DATA

PRINCIPLES OF CONSOLIDATION

Sempra Energy

Sempra Energy’s Condensed Consolidated Financial Statements include the accounts of Sempra Energy, a California-based Fortune 500 energy-services holding company, and its consolidated subsidiaries and VIEs. Sempra Global is the holding company for most of our subsidiaries that are not subject to California or Texas utility regulation. Sempra Energy’s businesses are managed within six separate reportable segments, which we discuss in Note 12. In the first quarter of 2019, our Sempra LNG & Midstream segment was renamed “Sempra LNG.” This segment name change had no impact on our historical position, results of operations, cash flow or segment level results previously reported. 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 Condensed Consolidated Financial Statements include its accounts and the accounts of a VIE of which SDG&E is the primary beneficiary, as we discuss below in “Variable Interest Entities.” SDG&E’s common stock is wholly owned by Enova Corporation, which is a wholly owned subsidiary of Sempra Energy.

SoCalGas

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

In this report, we refer to SDG&E and SoCalGas collectively as the California Utilities.

BASIS OF PRESENTATION

This is a combined report of Sempra Energy, SDG&E and SoCalGas. We provide separate information for SDG&E and SoCalGas as required. References in this report to “we,” “our” and “Sempra Energy Consolidated” are to Sempra Energy and its consolidated entities, unless otherwise indicated by the context. We have eliminated intercompany accounts and transactions within the consolidated financial statements of each reporting entity.

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 Energy and its subsidiaries and VIEs;

▪ the Condensed Consolidated Financial Statements and related Notes of SDG&E and its VIE; and

▪ the Condensed Financial Statements and related Notes of SoCalGas.

We have prepared the Condensed Consolidated Financial Statements in conformity with U.S. GAAP and in accordance with the interim-period-reporting requirements of Form 10-Q. Results of operations for interim periods are not necessarily indicative of results for the entire year. We evaluated events and transactions that occurred after March 31, 2019 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. These adjustments are only of a normal, recurring nature.

All December 31, 2018 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2018 Consolidated Financial Statements in the Annual Report, which for Sempra Energy has been retrospectively adjusted for discontinued operations, as we discuss below. 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 reporting purposes.

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

Discontinued Operations

On January 25, 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, as the planned sale represents a strategic shift that will have a major effect on our operations and financial results. Throughout this report, the financial information for all periods presented has been adjusted to reflect the presentation of these businesses as discontinued operations, which we discuss further in Note 5. 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 the effects of regulation and revenue recognition at our utilities in Notes 1 and 3 of the Notes to Consolidated Financial Statements in the Annual Report.

Our Sempra Texas Utility segment is comprised of our equity method investment in Oncor Holdings, which owns 80.25 percent of Oncor, as we discuss in Notes 5 and 6. Oncor is a regulated electric transmission and distribution utility and prepares its financial statements in accordance with the provisions of U.S. GAAP governing rate-regulated operations.

Our Sempra Mexico segment includes the operating companies of our subsidiary, IEnova. Certain business activities at IEnova are regulated by the Comisión Reguladora de Energía (Energy Regulatory Commission in Mexico) 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 the Condensed Consolidated Balance Sheets to the sum of such amounts reported on the 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)
	March 31,		December 31,
	2019		2018
Sempra Energy Consolidated:
Cash and cash equivalents	$	78	$	102
Restricted cash, current	41		35
Restricted cash, noncurrent	21		21
Cash, cash equivalents and restricted cash in discontinued operations	67		88
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	207	$	246
SDG&E:
Cash and cash equivalents	$	10	$	8
Restricted cash, current	21		11
Restricted cash, noncurrent	18		18
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	49	$	37

INVENTORIES

The following table presents the components of inventories by segment.

INVENTORY BALANCES
(Dollars in millions)
	Natural gas				LNG				Materials and supplies				Total
	March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018
SDG&E	$	—	$	—	$	—	$	—	$	99	$	102	$	99	$	102
SoCalGas	12		92		—		—		46		42		58		134
Sempra Mexico	—		—		7		4		16		15		23		19
Sempra LNG	9		3		—		—		—		—		9		3
Sempra Energy Consolidated	$	21	$	95	$	7	$	4	$	161	$	159	$	189	$	258

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 on 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 March 31,
	2019		2018
Sempra Energy Consolidated	$	47	$	49
SDG&E	17		24
SoCalGas	11		13

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 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 thereby Sempra Energy, is the primary beneficiary.

Tolling Agreements

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 we consider 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 we determine that SDG&E is the primary beneficiary, SDG&E and Sempra Energy consolidate the entity that owns the facility as a VIE.

Otay Mesa VIE

SDG&E has a tolling agreement to purchase power generated at OMEC, a 605-MW generating facility. Under the terms of a related agreement, OMEC LLC can require SDG&E to purchase the power plant (referred to as the put option) on or before October 3, 2019 for $280 million, subject to adjustments, or upon earlier termination of the PPA.

The facility owner, OMEC LLC, is a VIE, which we refer to as Otay Mesa VIE, of which SDG&E is the primary beneficiary. SDG&E has no OMEC LLC voting rights, holds no equity in OMEC LLC and does not operate OMEC. In addition to the risks absorbed under the tolling agreement, SDG&E absorbs separately through the put option a significant portion of the risk that the value of Otay Mesa VIE could decline. Accordingly, SDG&E and Sempra Energy consolidate Otay Mesa VIE. Otay Mesa VIE’s equity of $102 million at March 31, 2019 and $100 million at December 31, 2018 is included on the Condensed Consolidated Balance Sheets in Other Noncontrolling Interests for Sempra Energy and in Noncontrolling Interest for SDG&E.

In October 2018, SDG&E and OMEC LLC signed a resource adequacy capacity agreement for a term that would commence at the expiration of the current tolling agreement in October 2019 and end in August 2024. The capacity agreement was approved by OMEC LLC’s lenders and the CPUC in December 2018 and February 2019, respectively. However, given certain pending requests for rehearing of the CPUC’s decisions related to OMEC, on March 28, 2019, OMEC LLC exercised the put option requiring SDG&E to purchase the power plant by October 3, 2019. The outcome of these rehearing requests could impact the effectiveness of the resource adequacy capacity agreement and whether the OMEC facility is purchased by SDG&E.

OMEC LLC has a loan outstanding of $220 million at March 31, 2019, which we describe in Note 7 of the Notes to Consolidated Financial Statements in the Annual Report. SDG&E is not a party to the loan agreement and does not have any additional implicit or explicit financial responsibility to OMEC LLC, nor is SDG&E required to assume OMEC LLC’s loan under the put option.

The Condensed Consolidated Statements of Operations of Sempra Energy and SDG&E include the following amounts associated with Otay Mesa VIE. The amounts are net of eliminations of transactions between SDG&E and Otay Mesa VIE. The captions in the table below correspond to SDG&E’s Condensed Consolidated Statements of Operations.

AMOUNTS ASSOCIATED WITH OTAY MESA VIE
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Operating expenses
Cost of electric fuel and purchased power	$	(16	)	$	(16	)
Operation and maintenance	4			4
Depreciation and amortization	7			8
Total operating expenses	(5		)	(4		)
Operating income	5			4
Interest expense	(4		)	(5		)
Income (losses) before income taxes/Net income (loss)	1			(1		)
(Earnings) losses attributable to noncontrolling interest	(1		)	1
Earnings attributable to common shares	$	—		$	—

SDG&E has determined that no contracts, other than the one relating to Otay Mesa VIE described above, resulted in SDG&E being the primary beneficiary of a VIE at March 31, 2019. In addition to the tolling agreements described above, 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 that most significantly impact the economic performance of the other VIEs. In addition, SDG&E is not exposed to losses or gains as a result of these other VIEs, because all such variability would be recovered in rates. 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 Energy. We

provide additional information about PPAs with power plant facilities that are VIEs of which SDG&E is not the primary beneficiary in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report.

We provide additional information regarding Otay Mesa VIE in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

Sempra Texas Utility

On March 9, 2018, we completed the acquisition of an indirect, 100-percent interest in Oncor Holdings, a VIE that owns an 80.25-percent interest in Oncor. Sempra Energy is not the primary beneficiary of the 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 for additional information about our equity method investment in Oncor Holdings and restrictions on our ability to influence its activities. Our current maximum exposure to loss from our interest in Oncor Holdings does not exceed the carrying value of our investment, which was $9,748 million at March 31, 2019 and $9,652 million at December 31, 2018. Our maximum exposure will fluctuate over time, including as a result of our commitment to contribute an estimated $1,025 million in capital (excluding Sempra Energy’s share of approximately $40 million for a management agreement termination fee, as well as other customary transaction costs incurred by InfraREIT that would be borne by Oncor as part of the acquisition) to partially fund Oncor’s pending acquisition of InfraREIT, which we discuss in Note 5.

Sempra Renewables

Certain of Sempra Renewables’ wind and solar power generation projects were held by limited liability companies whose members were Sempra Renewables and financial institutions. We sold the solar entities in December 2018 and the wind entities in April 2019. The financial institutions are noncontrolling tax equity investors to which earnings, tax attributes and cash flows were allocated in accordance with the respective limited liability company agreements. These entities were VIEs and Sempra Energy was the primary beneficiary, generally due to Sempra Energy’s power as the operator of the renewable energy projects to direct the activities that most significantly impacted the economic performance of these VIEs. As the primary beneficiary of these tax equity limited liability companies, we consolidated them.

Sempra Energy’s Condensed Consolidated Balance Sheets include equity of $161 million at March 31, 2019 and $158 million at December 31, 2018 of Other Noncontrolling Interests associated with these entities. Sempra Energy’s Condensed Consolidated Statements of Operations include the following amounts associated with the tax equity limited liability companies, net of eliminations of transactions between Sempra Energy and these entities.

AMOUNTS ASSOCIATED WITH TAX EQUITY ARRANGEMENTS
(Dollars in millions)
	Three months ended March 31,
	2019			2018
REVENUES
Energy-related businesses	$	6		$	17
EXPENSES
Operation and maintenance	(2		)	(4		)
Depreciation and amortization	(3		)	(11		)
Income before income taxes	1			2
Income tax benefit (expense)	1			(5		)
Net income (loss)	2			(3		)
(Earnings) losses attributable to noncontrolling interests(1)	(3		)	21
(Losses) earnings attributable to common shares	$	(1	)	$	18

⁽¹⁾ Net income or loss attributable to NCI is computed using the HLBV method and is not based on ownership percentages.

We provide additional information regarding the tax equity limited liability companies in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

Sempra LNG

Cameron LNG JV is a VIE principally due to contractual provisions that transfer certain risks to customers. Sempra Energy is not the primary beneficiary of the VIE because we do not have the power to direct the most significant activities of Cameron LNG JV, and 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 $1,255 million at

March 31, 2019 and $1,271 million at December 31, 2018. Our current maximum exposure to loss, which fluctuates over time, includes the carrying value of our investment and the guarantees that we discuss in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.

Other Variable Interest Entities

Sempra Energy’s other businesses also enter into arrangements that could include variable interests. We evaluate these arrangements and applicable entities based on the qualitative and quantitative analyses described above. Certain of these entities are service or project companies that are VIEs because the total equity at risk is not sufficient for the entities to finance their activities without additional subordinated financial support. As the primary beneficiary of these companies, we consolidate them. The assets of these VIEs totaled approximately $502 million at March 31, 2019 and $286 million at December 31, 2018, and consisted primarily of PP&E and other long-term assets. Sempra Energy’s exposure to loss is equal to the carrying value of these assets. In all other cases, we have determined that these arrangements are not variable interests in a VIE and therefore are not subject to the U.S. GAAP requirements concerning the consolidation or disclosures of VIEs.PENSION AND OTHER POSTRETIREMENT BENEFITS

Net Periodic Benefit Cost

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

NET PERIODIC BENEFIT COST – SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	Three months ended March 31,
	2019			2018			2019			2018
Service cost	$	27		$	33		$	4		$	6
Interest cost	35			35			9			9
Expected return on assets	(36		)	(42		)	(18		)	(18		)
Amortization of:
Prior service cost	3			3			—			—
Actuarial loss (gain)	14			9			(2		)	(1		)
Settlement charges	—			14			—			—
Net periodic benefit cost (credit)	43			52			(7		)	(4		)
Regulatory adjustment	(36		)	(45		)	7			4
Total expense recognized	$	7		$	7		$	—		$	—

NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	Three months ended March 31,
	2019			2018			2019			2018
Service cost	$	8		$	8		$	1		$	1
Interest cost	9			9			2			2
Expected return on assets	(11		)	(13		)	(3		)	(3		)
Amortization of:
Prior service cost	1			—			1			1
Actuarial loss (gain)	4			1			(1		)	(1		)
Settlement charges	—			14			—			—
Net periodic benefit cost	11			19			—			—
Regulatory adjustment	(11		)	(19		)	—			—
Total expense recognized	$	—		$	—		$	—		$	—

NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	Three months ended March 31,
	2019			2018			2019			2018
Service cost	$	16		$	22		$	3		$	4
Interest cost	23			23			7			7
Expected return on assets	(24		)	(26		)	(14		)	(14		)
Amortization of:
Prior service cost (credit)	2			2			(1		)	(1		)
Actuarial loss (gain)	9			6			(2		)	—
Net periodic benefit cost (credit)	26			27			(7		)	(4		)
Regulatory adjustment	(25		)	(26		)	7			4
Total expense recognized	$	1		$	1		$	—		$	—

Benefit Plan Contributions

The following table shows our year-to-date contributions to pension and other postretirement benefit plans and the amounts we expect to contribute in 2019.

BENEFIT PLAN CONTRIBUTIONS
(Dollars in millions)
	Sempra Energy Consolidated		SDG&E		SoCalGas
Contributions through March 31, 2019:
Pension plans	$	9	$	—	$	1
Other postretirement benefit plans	2		—		—
Total expected contributions in 2019:
Pension plans	$	234	$	40	$	118
Other postretirement benefit plans	9		—		1

RABBI TRUSTIn support of its Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans, Sempra Energy maintains dedicated assets, including a Rabbi Trust and investments in life insurance contracts, which totaled $413 million and $416 million at March 31, 2019 and December 31, 2018, respectively.EARNINGS PER COMMON SHARE

The following table provides EPS computations for the three months ended March 31, 2019 and 2018. 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 March 31,
	2019			2018
Numerator for continuing operations:
Income from continuing operations, net of income tax	$	560		$	330
(Earnings) losses attributable to noncontrolling interests	(32		)	24
Mandatory convertible preferred stock dividends	(36		)	(28		)
Earnings from continuing operations attributable to common shares	$	492		$	326
Numerator for discontinued operations:
(Loss) income from discontinued operations, net of income tax	$	(42	)	$	28
Earnings attributable to noncontrolling interests	(9		)	(7		)
(Losses) earnings from discontinued operations attributable to common shares	$	(51	)	$	21
Numerator for earnings:
Earnings attributable to common shares	$	441		$	347
Denominator:
Weighted-average common shares outstanding for basic EPS(1)	274,674			257,932
Dilutive effect of stock options and RSUs(2)	969			933
Dilutive effect of common shares sold forward	1,585			625
Weighted-average common shares outstanding for diluted EPS	277,228			259,490
Basic EPS:
Earnings from continuing operations attributable to common shares	$	1.79		$	1.26
(Losses) earnings from discontinued operations attributable to common shares	$	(0.19	)	$	0.08
Earnings attributable to common shares	$	1.60		$	1.34
Diluted EPS:
Earnings from continuing operations attributable to common shares	$	1.78		$	1.25
(Losses) earnings from discontinued operations attributable to common shares	$	(0.19	)	$	0.08
Earnings attributable to common shares	$	1.59		$	1.33

⁽¹⁾ Includes 613 and 628 average fully vested RSUs held in our Deferred Compensation Plan for the three months ended March 31, 2019 and 2018, respectively. These fully vested RSUs are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

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

The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect. The computation of diluted EPS for the three months ended March 31, 2019 and 2018 excludes 316,385 and 80,449 potentially dilutive shares, respectively, because to include them would be antidilutive for the period. However, these shares could potentially dilute basic EPS in the future.

The potentially dilutive impact from the forward sale of our common stock pursuant to the forward sale agreements that we entered into in 2018 is reflected in our diluted EPS calculation using the treasury stock method. We anticipate there will be a dilutive effect on our EPS when the average market price of shares of our common stock is above the applicable adjusted forward sale price, subject to increase or decrease based on the overnight bank funding rate, less a spread, and subject to decrease by

amounts related to expected dividends on shares of our common stock during the term of the forward sale agreements. Additionally, if we decide to physically settle or net share settle the forward sale agreements, delivery of our shares to the forward purchasers on any such physical settlement or net share settlement of the forward sale agreements would result in dilution to our EPS.

The potentially dilutive impact from mandatory convertible preferred stock that we issued in 2018 is calculated under the if-converted method. The computation of diluted EPS for the three months ended March 31, 2019 and 2018 excludes 18,601,085 and 15,592,572 potentially dilutive shares, respectively, because to include them would be antidilutive for the period. However, these shares could potentially dilute basic EPS in the future.

Pursuant to our Sempra Energy share-based compensation plans, Sempra Energy’s Board of Directors granted 261,075 non-qualified stock options that are exercisable over a three-year period, 384,373 performance-based RSUs and 214,502 service-based RSUs in the three months ended March 31, 2019, primarily in January.

We discuss share-based compensation plans and related awards further in Note 10 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 March 31, 2019 and 2018
Sempra Energy Consolidated(2):
Balance as of December 31, 2018	$	(564	)	$	(82	)	$	(118	)	$	(764	)
Cumulative-effect adjustment from change in accounting principle	—			(25		)	(17		)	(42		)
OCI before reclassifications	32			(45		)	1			(12		)
Amounts reclassified from AOCI	—			(1		)	2			1
Net OCI	32			(46		)	3			(11		)
Balance as of March 31, 2019	$	(532	)	$	(153	)	$	(132	)	$	(817	)
Balance as of December 31, 2017	$	(420	)	$	(122	)	$	(84	)	$	(626	)
Cumulative-effect adjustment from change in accounting principle	—			(3		)	—			(3		)
OCI before reclassifications	24			66			—			90
Amounts reclassified from AOCI	—			(8		)	2			(6		)
Net OCI	24			58			2			84
Balance as of March 31, 2018	$	(396	)	$	(67	)	$	(82	)	$	(545	)
SDG&E:
Balance as of December 31, 2018							$	(10	)	$	(10	)
Cumulative-effect adjustment from change in accounting principle							(2		)	(2		)
Balance as of March 31, 2019							$	(12	)	$	(12	)
Balance as of December 31, 2017 and March 31, 2018							$	(8	)	$	(8	)
SoCalGas:
Balance as of December 31, 2018				$	(12	)	$	(8	)	$	(20	)
Cumulative-effect adjustment from change in accounting principle				(2		)	(2		)	(4		)
Balance as of March 31, 2019				$	(14	)	$	(10	)	$	(24	)
Balance as of December 31, 2017 and March 31, 2018				$	(13	)	$	(8	)	$	(21	)

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

⁽²⁾  Includes discontinued operations.

RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
Details about accumulated other comprehensive income (loss) components	Amounts reclassified from accumulated other comprehensive income (loss)						Affected line item on Condensed Consolidated Statements of Operations
	Three months ended March 31,
	2019			2018
Sempra Energy Consolidated:
Financial instruments:
Interest rate and foreign exchange instruments(1)	$	1		$	(2	)	Interest Expense
	(3		)	(18		)	Other Income, Net
Interest rate and foreign exchange instruments	1			4			Equity Earnings (Losses)
Foreign exchange instruments	1			—			Revenues: Energy-Related Businesses
Total before income tax	—			(16		)
	—			3			Income Tax Expense
Net of income tax	—			(13		)
	(1		)	5			(Earnings) Losses Attributable to Noncontrolling Interests
	$	(1	)	$	(8	)
Pension and other postretirement benefits:
Amortization of actuarial loss(2)	$	2		$	3		Other Income, Net
Amortization of prior service cost(2)	1			—			Other Income, Net
Total before income tax	3			3
	(1		)	(1		)	Income Tax Expense
Net of income tax	$	2		$	2
Total reclassifications for the period, net of tax	$	1		$	(6	)
SDG&E:
Financial instruments:
Interest rate instruments(1)	$	1		$	3		Interest Expense
	(1		)	(3		)	(Earnings) Losses Attributable to Noncontrolling Interest
Total reclassifications for the period, net of tax	$	—		$	—

⁽¹⁾  Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.

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

For the three months ended March 31, 2019 and 2018, reclassifications out of AOCI to net income were negligible for SoCalGas.SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS

Sempra Energy Mandatory Convertible Preferred Stock Offerings

In January 2018, we issued 17,250,000 shares of our series A preferred stock in a registered public offering resulting in net proceeds of approximately $1.69 billion. In July 2018, we issued 5,750,000 shares of our series B preferred stock in a registered public offering resulting in net proceeds of approximately $565 million. Each share of series A preferred stock and series B preferred stock has a liquidation value of $100.00. We discuss the preferred stock offerings in Note 13 of the Notes to Consolidated Financial Statements in the Annual Report.

Sempra Energy Common Stock Offerings

In January 2018, we completed the offering of 26,869,158 shares of our common stock, no par value, in a registered public offering at $107.00 per share (approximately $105.07 per share after deducting underwriting discounts), pursuant to forward sale agreements. We received net proceeds totaling approximately $1.27 billion from the sale of shares in the January 2018 offering (including $367 million to cover overallotments) and from the settlement of forward sales in the first quarter of 2018 under the forward sale agreements. We received net proceeds of approximately $800 million from the settlement of forward sales in the second quarter of 2018 under the forward sale agreements. In July 2018, we completed the offering of 11,212,500 shares of our

common stock, no par value, in a registered public offering at $113.75 per share (approximately $111.87 per share after deducting underwriting discounts), pursuant to forward sale agreements. We received net proceeds of approximately $164 million from the sale of shares in the July 2018 offering to cover overallotments. We discuss the common stock offerings in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report.

As of May 7, 2019, a total of 16,906,185 shares of Sempra Energy common stock remain subject to future settlement under these forward sale agreements, which may be settled on one or more dates specified by us occurring no later than December 15, 2019, which is the final settlement date under the agreements. Although we expect to settle the forward sale agreements entirely by the physical delivery of shares of our common stock in exchange for cash proceeds, we may, subject to certain conditions, elect cash settlement or net share settlement for all or a portion of our obligations under the forward sale agreements. The forward sale agreements are also subject to acceleration by the forward purchasers upon the occurrence of certain events.

SoCalGas Preferred Stock

The preferred stock at SoCalGas is presented at Sempra Energy as a noncontrolling interest. Sempra Energy records charges against income related to NCI for preferred stock dividends declared by SoCalGas. We provide additional information regarding preferred stock in Note 13 of the Notes to Consolidated Financial Statements in the Annual Report.

Other Noncontrolling Interests

Ownership interests that are held by owners other than Sempra Energy and SDG&E in subsidiaries or entities consolidated by them are accounted for and reported as NCI.

Sempra Mexico

In the first quarter of 2019, IEnova repurchased 1,600,000 shares of its outstanding common stock held by NCI for approximately $6 million, resulting in an increase in Sempra Energy’s ownership interest in IEnova from 66.5 percent at December 31, 2018 to 66.6 percent at March 31, 2019.

Sempra Renewables

As we discuss in Note 5, in April 2019, Sempra Renewables sold its remaining wind assets and investments, which included its wind tax equity arrangements. The remaining ownership interest in PXiSE Energy Solutions, LLC was subsumed into Parent and other.

Sempra LNG

On February 7, 2019, Sempra LNG purchased for $20 million the 9.1-percent minority interest in Bay Gas immediately prior to the sale of 100 percent of Bay Gas, which we discuss in Note 5.

The following table provides information on noncontrolling ownership interests held by others (not including preferred shareholders) in Other Noncontrolling Interests in Total Equity on Sempra Energy’s Condensed Consolidated Balance Sheets.

OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
	Percent ownership held by noncontrolling interests				Equity (deficit) held by noncontrolling interests
	March 31, 2019		December 31, 2018		March 31, 2019			December 31, 2018
SDG&E:
Otay Mesa VIE	100	%	100	%	$	102		$	100
Sempra Mexico:
IEnova	33.4		33.5		1,611			1,592
IEnova subsidiaries(1)	10.0 – 47.6		10.0 – 49.0		13			13
Sempra Renewables:
Tax equity arrangements – wind(2)	NA		NA		161			158
PXiSE Energy Solutions, LLC	11.1		11.1		—			1
Sempra LNG:
Bay Gas	—		9.1		—			18
Liberty Gas Storage, LLC	24.6		24.6		(12		)	(12		)
Discontinued Operations:
Chilquinta Energía subsidiaries(1)	19.7 – 43.4		19.7 – 43.4		24			23
Luz del Sur	16.4		16.4		201			193
Tecsur	9.8		9.8		4			4
Total Sempra Energy					$	2,104		$	2,090

⁽¹⁾  IEnova and Chilquinta Energía have subsidiaries with NCI held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.

⁽²⁾ 

Net income or loss attributable to NCI is computed using the HLBV method and is not based on ownership percentages.TRANSACTIONS WITH AFFILIATES

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

AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	March 31, 2019			December 31, 2018
Sempra Energy Consolidated:
Total due from various unconsolidated affiliates – current	$	50		$	37
Sempra Mexico(1):
IMG – Note due March 15, 2022(2)	$	668		$	641
Energía Sierra Juárez – Note(3)	—			3
Total due from unconsolidated affiliates – noncurrent	$	668		$	644
Total due to various unconsolidated affiliates – current	$	(10	)	$	(10	)
Sempra Mexico(1):
Total due to unconsolidated affiliates – noncurrent – TAG – Note due December 20, 2021(4)	$	(38	)	$	(37	)
SDG&E:
Sempra Energy	$	(37	)	$	(43	)
SoCalGas	(14		)	(6		)
Various affiliates	(12		)	(12		)
Total due to unconsolidated affiliates – current	$	(63	)	$	(61	)
Income taxes due (to) from Sempra Energy(5)	$	(29	)	$	5
SoCalGas:
SDG&E	$	14		$	6
Various affiliates	1			1
Total due from unconsolidated affiliates – current	$	15		$	7
Sempra Energy	$	(39	)	$	(34	)
Various affiliates	(3		)	—
Total due to unconsolidated affiliates – current	$	(42	)	$	(34	)
Income taxes due to Sempra Energy(5)	$	(88	)	$	(4	)

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

⁽²⁾  Mexican peso-denominated revolving line of credit for up to 14.2 billion Mexican pesos or approximately $729 million U.S. dollar-equivalent, at a variable interest rate based on the 91-day Interbank Equilibrium Interest Rate plus 220 bps (10.69 percent at March 31, 2019), to finance construction of the natural gas marine pipeline.

⁽³⁾  U.S. dollar-denominated loan, at a variable interest rate based on the 30-day LIBOR plus 637.5 bps (8.89 percent at December 31, 2018).

⁽⁴⁾  U.S. dollar-denominated loan, at a variable interest rate based on the 6-month LIBOR plus 290 bps (5.54 percent at March 31, 2019).

⁽⁵⁾  SDG&E and SoCalGas are included in the consolidated income tax return of Sempra Energy and are allocated income tax expense from Sempra Energy in an amount equal to that which would result from each company having always filed a separate return.

The following table summarizes revenues and cost of sales from unconsolidated affiliates.

REVENUES AND COST OF SALES FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended March 31,
	2019		2018
Revenues:
Sempra Energy Consolidated	$	14	$	16
SDG&E	1		2
SoCalGas	17		17
Cost of Sales:
Sempra Energy Consolidated	$	14	$	12
SDG&E	20		19
SoCalGas	4		—

Guarantees

Sempra Energy has provided guarantees to certain of its JVs, including guarantees related to the financing of the Cameron LNG JV project, as we discuss in Note 6 below and in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.OTHER INCOME, NET

Other Income, Net on the Condensed Consolidated Statements of Operations consisted of the following:

OTHER INCOME, NET
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Sempra Energy Consolidated:
Allowance for equity funds used during construction	$	21		$	27
Investment gains (losses)(1)	26			(1		)
Gains on interest rate and foreign exchange instruments, net	13			62
Foreign currency transaction gains, net(2)	7			30
Non-service component of net periodic benefit credit	24			32
Penalties related to billing practices OII	(8		)	—
Interest on regulatory balancing accounts, net	(1		)	—
Sundry, net	—			2
Total	$	82		$	152
SDG&E:
Allowance for equity funds used during construction	$	12		$	18
Non-service component of net periodic benefit credit	9			9
Sundry, net	1			1
Total	$	22		$	28
SoCalGas:
Allowance for equity funds used during construction	$	8		$	9
Non-service component of net periodic benefit credit	18			25
Penalties related to billing practices OII	(8		)	—
Interest on regulatory balancing accounts, net	(1		)	—
Sundry, net	(1		)	(1		)
Total	$	16		$	33

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

⁽²⁾ 

Includes gains of $10 million and $39 million in the three months ended March 31, 2019 and 2018, respectively, from translation to U.S. dollars of a Mexican peso-denominated loan to the IMG JV, which are offset by corresponding amounts included in Equity Earnings (Losses) on the Condensed Consolidated Statements of Operations.INCOME TAXES

We provide our calculations of ETRs in the following table.

INCOME TAX EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Sempra Energy Consolidated:
Income tax expense from continuing operations	$	42		$	242
Income from continuing operations before income taxes
and equity earnings (losses) of unconsolidated entities	$	501		$	593
Equity earnings, before income tax(1)	5			5
Pretax income	$	506		$	598
Effective income tax rate	8		%	40		%
SDG&E:
Income tax expense	$	5		$	56
Income before income taxes	$	182		$	225
Effective income tax rate	3		%	25		%
SoCalGas:
Income tax expense	$	19		$	59
Income before income taxes	$	283		$	284
Effective income tax rate	7		%	21		%

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

Sempra Energy, 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; and

▪ 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. Such effects are partially mitigated by net gains (losses) from foreign currency derivatives that are hedging Sempra Mexico parent’s exposure to movements in the Mexico peso from its controlling interest in IEnova.

In the three months ended March 31, 2019, SDG&E and SoCalGas recorded income tax benefits of $31 million and $35 million, respectively, from the release of a regulatory liability established in connection with 2017 tax reform for excess deferred income tax balances that the CPUC directed be allocated to shareholders in a January 2019 decision.

Discontinued Operations

On January 25, 2019, our board of directors approved a plan to sell our South American businesses, as we discuss in Note 5. Prior to this decision, our repatriation estimate excluded post-2017 earnings and other basis differences related to our South American

businesses. Because of our decision to sell our South American businesses, we no longer assert indefinite reinvestment of these basis differences and have recorded the following in discontinued operations in the three months ended March 31, 2019:

▪ $103 million income tax expense related to outside basis differences existing as of the January 25, 2019 approval of our plan to sell our South American businesses; and

▪ $13 million income tax expense related to the increase in outside basis differences from 2019 earnings since January 25, 2019.

We have not changed our indefinite reinvestment assertion or repatriation plan for our continuing international operations.

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NEW ACCOUNTING STANDARDS

3 Months Ended

Mar. 31, 2019

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 2016-02, “Leases,” ASU 2018-01, “Land Easement Practical Expedient for Transition to Topic 842,” ASU 2018-10, “Codification Improvements to Topic 842, Leases,” ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” ASU 2018-20, “Narrow-Scope Improvements for Lessors” and ASU 2019-01, “Leases (Topic 842): Codification Improvements” (collectively referred to as the “lease standard”): In 2016, the FASB began issuing the first in a series of ASUs intended to increase transparency and comparability among organizations with leasing activities. The most significant provision of the lease standard is the requirement that lessees recognize operating lease ROU assets and lease liabilities on the balance sheet.

We adopted the lease standard on January 1, 2019, using the optional transition method to apply the new guidance prospectively as of January 1, 2019, rather than as of the earliest period presented. We elected the package of practical expedients that permits us to not reassess (a) whether a contract is or contains a lease, (b) lease classification or (c) determination of initial direct costs, which allows us to carry forward accounting conclusions under previous U.S. GAAP on contracts that commenced prior to adoption of the lease standard. We also elected the land easement practical expedient, which allows us to continue to account for pre-existing land easements under our accounting policy that existed before adoption of the lease standard. We did not elect the practical expedient to use hindsight in making judgments when determining the lease term.

The adoption of the lease standard did not change our previously reported financial statements. However, in accordance with the lease standard, on a prospective basis, a significant portion of finance lease costs for PPAs that have historically been presented in Cost of Electric Fuel and Purchased Power are now presented in Depreciation and Amortization Expense and Interest Expense on Sempra Energy’s and SDG&E’s statements of operations. Additionally, the adoption of the lease standard had a material impact on our balance sheets at January 1, 2019 due to the initial recognition of ROU assets and lease liabilities for operating leases. Our finance leases were already included on our balance sheets prior to adoption of the lease standard, consistent with previous U.S. GAAP for capital leases.

The following table shows the initial (decreases) increases on our balance sheets at January 1, 2019 from adoption of the lease standard.

IMPACT FROM ADOPTION OF THE LEASE STANDARD
(Dollars in millions)
	Sempra Energy Consolidated			SDG&E		SoCalGas
Assets held for sale	$	13		$	—	$	—
Sundry	(71		)	—		—
Property, plant and equipment, net	(147		)	—		—
Right-of-use assets – operating leases	603			130		116
Deferred income tax assets	(3		)	—		—
Other current liabilities	80			20		23
Long-term debt	(138		)	—		—
Deferred credits and other	436			110		93
Retained earnings	17			—		—

As a result of the adoption of the lease standard, we derecognized our corporate headquarters building lease in accordance with the transition provisions for build-to-suit arrangements. On a prospective basis, we will account for the corporate headquarters building lease as an operating lease. The initial impact is included in the above table.

We include additional disclosures about our leases in Note 11.

ASU 2016-13, “Measurement of Credit Losses on Financial Instruments”: ASU 2016-13 changes how entities will measure credit losses for most financial assets and certain other instruments. The standard introduces an “expected credit loss” impairment model that requires immediate recognition of estimated credit losses expected to occur over the remaining life of most financial assets measured at amortized cost, including trade and other receivables, loan commitments and financial guarantees. ASU 2016-13 also requires use of an allowance to record estimated credit losses on available-for-sale debt securities and expands disclosure requirements regarding an entity’s assumptions, models and methods for estimating the credit losses.

For public entities, ASU 2016-13 is effective for fiscal years beginning after December 15, 2019, including interim periods therein, with early adoption permitted for fiscal years beginning after December 15, 2018. The amendments are to be applied using a modified retrospective approach through a cumulative-effect adjustment to retained earnings at the beginning of the first reporting period in the year of adoption. We are currently evaluating the impact of the standard on our ongoing financial reporting and plan to adopt the standard on January 1, 2020.

ASU 2017-04, “Simplifying the Test for Goodwill Impairment”: ASU 2017-04 removes the second step of the goodwill impairment test, which requires a hypothetical purchase price allocation. An entity will be required to apply a one-step quantitative test and record the amount of goodwill impairment as the excess of a reporting unit’s carrying amount over its fair value, not to exceed the carrying amount of goodwill. For public entities, ASU 2017-04 is effective for annual or interim goodwill impairment tests in fiscal years beginning after December 15, 2019, with early adoption permitted. The amendments are to be applied on a prospective basis. We plan to adopt the standard on January 1, 2020.

ASU 2018-02, “Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income”: ASU 2018-02 contains amendments that allow a reclassification from AOCI to retained earnings for stranded tax effects resulting from the TCJA. Under ASU 2018-02, an entity is required to provide certain disclosures regarding stranded tax effects, including its accounting policy related to releasing the income tax effects from AOCI. The amendments in this update can be applied either as of the beginning of the period of adoption or retrospectively as of the date of enactment of the TCJA and to each period in which the effect of the TCJA is recognized. We adopted ASU 2018-02 on January 1, 2019 and reclassified the income tax effects of the TCJA from AOCI to retained earnings.

The impact from adoption of ASU 2018-02 on January 1, 2019 was as follows:

▪ Sempra Energy: increase of $40 million to beginning Retained Earnings, $2 million to noncurrent Regulatory Liabilities and $42 million to Accumulated Other Comprehensive Loss;

▪ SDG&E: increase of $2 million to beginning Retained Earnings and Accumulated Other Comprehensive Loss; and

▪

SoCalGas: increase of $2 million to beginning Retained Earnings, $2 million to noncurrent Regulatory Liabilities and $4 million to Accumulated Other Comprehensive Loss.

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REVENUES

3 Months Ended

Mar. 31, 2019

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)
	Three months ended March 31, 2019
	SDG&E			SoCalGas			Sempra Mexico		Sempra Renewables		Sempra LNG		Consolidating adjustments			Sempra Energy Consolidated
By major service line:
Utilities	$	1,236		$	1,528		$	27	$	—	$	—	$	(18	)	$	2,773
Midstream	—			—			171		—		67		(59		)	179
Renewables	—			—			20		4		—		—			24
Other	—			—			66		—		1		—			67
Revenues from contracts with customers	$	1,236		$	1,528		$	284	$	4	$	68	$	(77	)	$	3,043
By market:
Electric	$	997		$	—		$	86	$	4	$	1	$	(1	)	$	1,087
Gas	239			1,528			198		—		67		(76		)	1,956
Revenues from contracts with customers	$	1,236		$	1,528		$	284	$	4	$	68	$	(77	)	$	3,043
Revenues from contracts with customers	$	1,236		$	1,528		$	284	$	4	$	68	$	(77	)	$	3,043
Utilities regulatory revenues	(91		)	(167		)	—		—		—		—			(258		)
Other revenues	—			—			99		3		73		(62		)	113
Total revenues	$	1,145		$	1,361		$	383	$	7	$	141	$	(139	)	$	2,898
	Three months ended March 31, 2018
By major service line:
Utilities	$	1,131		$	1,081		$	28	$	—	$	—	$	(19	)	$	2,221
Midstream	—			—			143		—		54		(21		)	176
Renewables	—			—			22		11		1		(1		)	33
Other	—			—			41		—		2		(2		)	41
Revenues from contracts with customers	$	1,131		$	1,081		$	234	$	11	$	57	$	(43	)	$	2,471
By market:
Electric	$	963		$	—		$	62	$	11	$	2	$	(4	)	$	1,034
Gas	168			1,081			172		—		55		(39		)	1,437
Revenues from contracts with customers	$	1,131		$	1,081		$	234	$	11	$	57	$	(43	)	$	2,471
Revenues from contracts with customers	$	1,131		$	1,081		$	234	$	11	$	57	$	(43	)	$	2,471
Utilities regulatory revenues	(76		)	45			—		—		—		—			(31		)
Other revenues	—			—			74		14		47		(39		)	96
Total revenues	$	1,055		$	1,126		$	308	$	25	$	104	$	(82	)	$	2,536

Remaining Performance Obligations    

For contracts greater than one year, at March 31, 2019, we expect to recognize revenue related to the fixed fee component of the consideration as shown below. SoCalGas did not have any such remaining performance obligations at March 31, 2019.

REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra Energy Consolidated		SDG&E
2019 (excluding first three months of 2019)	$	384	$	2
2020	512		3
2021	513		3
2022	515		3
2023	509		3
Thereafter	2,784		52
Total revenues to be recognized	$	5,217	$	66

⁽¹⁾ Excludes intercompany transactions.

Contract Balances from Revenues from Contracts with Customers

Activities within Sempra Energy’s contract liabilities are presented below. There were no contract liabilities at SDG&E or SoCalGas for the three months ended March 31, 2019 and 2018.

CONTRACT LIABILITIES
(Dollars in millions)
Balance at January 1, 2019	$	(70	)
Revenue from performance obligations satisfied during reporting period	1
Payments received in advance	(2		)
Balance at March 31, 2019(1)	$	(71	)
Balance at January 1, 2018	$	—
Adoption of ASC 606 adjustment	(61		)
Revenue from performance obligations satisfied during reporting period	5
Payments received in advance	(7		)
Balance at March 31, 2018	$	(63	)

⁽¹⁾ Includes a negligible amount in Other Current Liabilities and $71 million in Deferred Credits and Other on the Sempra Energy Condensed Consolidated Balance Sheet.

Receivables from Revenues from Contracts with Customers

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

RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS
(Dollars in millions)
	March 31, 2019		December 31, 2018
Sempra Energy Consolidated:
Accounts receivable – trade, net	$	1,145	$	1,106
Accounts receivable – other, net	14		11
Due from unconsolidated affiliates – current(1)	6		4
Assets held for sale	1		6
Total	$	1,166	$	1,127
SDG&E:
Accounts receivable – trade, net	$	390	$	368
Accounts receivable – other, net	12		6
Due from unconsolidated affiliates – current(1)	3		3
Total	$	405	$	377
SoCalGas:
Accounts receivable – trade, net	$	674	$	634
Accounts receivable – other, net	2		5
Total	$	676	$	639

⁽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

3 Months Ended

Mar. 31, 2019

Regulated Operations [Abstract]

Regulatory Matters

REGULATORY MATTERS

We discuss regulatory matters in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report, and provide updates to those discussions and information about new regulatory matters below.

REGULATORY ASSETS AND LIABILITIES

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

REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	March 31, 2019			December 31, 2018
SDG&E:
Fixed-price contracts and other derivatives	$	(144	)	$	(150	)
Deferred income taxes refundable in rates	(171		)	(236		)
Pension and other postretirement benefit plan obligations	190			186
Removal obligations	(1,946		)	(1,848		)
Unamortized loss on reacquired debt	6			7
Environmental costs	27			28
Sunrise Powerlink fire mitigation	121			120
Regulatory balancing accounts(1)
Commodity – electric	60			(8		)
Gas transportation	13			45
Safety and reliability	77			70
Public purpose programs	(80		)	(62		)
Other balancing accounts	67			145
Other regulatory liabilities, net(2)	(199		)	(177		)
Total SDG&E	(1,979		)	(1,880		)
SoCalGas:
Pension and other postretirement benefit plan obligations	479			470
Employee benefit costs	49			49
Removal obligations	(804		)	(833		)
Deferred income taxes refundable in rates	(248		)	(336		)
Unamortized loss on reacquired debt	6			7
Environmental costs	32			28
Workers’ compensation	9			9
Regulatory balancing accounts(1)
Commodity – gas, including transportation	16			196
Safety and reliability	348			332
Public purpose programs	(289		)	(325		)
Other balancing accounts	(143		)	(68		)
Other regulatory liabilities, net(2)	(160		)	(130		)
Total SoCalGas	(705		)	(601		)
Sempra Mexico:
Deferred income taxes recoverable in rates	81			81
Other regulatory assets	9			6
Total Sempra Energy Consolidated	$	(2,594	)	$	(2,394	)

⁽¹⁾  At March 31, 2019 and December 31, 2018, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $84 million and $78 million, respectively, and for SoCalGas was $405 million and $185 million, respectively. 

⁽²⁾   Includes regulatory assets earning a rate of return.

CALIFORNIA UTILITIES

CPUC General Rate Case

The CPUC uses a GRC proceeding to set sufficient rates to allow the California Utilities to recover their reasonable cost of O&M and to provide the opportunity to realize their authorized rates of return on their investment.

2019 General Rate Case

On October 6, 2017, SDG&E and SoCalGas filed their 2019 GRC applications requesting CPUC approval of test year revenue requirements for 2019 and attrition year adjustments for 2020 through 2022. SDG&E and SoCalGas are seeking revenue requirements for 2019 of $2.203 billion and $2.937 billion, respectively, which is an increase of $221 million and $481 million

over their respective 2018 revenue requirements (the 2019 proposed and 2018 actual revenue requirements reflect the impact of various updates made during the course of the proceeding). The California Utilities are proposing post-test year revenue requirement annual attrition percentages that are estimated to result in annual increases of approximately 5 percent to 7 percent at SDG&E and approximately 6 percent to 8 percent at SoCalGas. The original GRC applications filed in October 2017 did not reflect the impact of the TCJA, which we discuss in “2016 General Rate Case” below and in Note 8 of the Notes to Consolidated Financial Statements in the Annual Report. In April 2018, SDG&E and SoCalGas updated their applications to reflect the impact of the TCJA and filed a joint proposal to address the impacts. The TCJA impact to SDG&E is a reduction of approximately $58 million to its 2019 test year revenue requirement; however, SDG&E’s 2019 requested revenue requirement is unchanged as we evaluate potentially higher costs associated with mitigating wildfire risks. The TCJA impact to SoCalGas’ 2019 requested revenue requirement is a reduction of approximately $58 million, which is reflected in its updated request.

During the course of the proceeding, Cal PA recommended 2019 revenue requirements of $1.918 billion and $2.695 billion for SDG&E and SoCalGas, respectively, which is a net decrease of $64 million for SDG&E and a net increase of $239 million for SoCalGas compared to the 2018 revenue requirements. Cal PA proposes a three-year annual attrition percentage of 4 percent for SDG&E and a range of 4 percent to 5 percent for SoCalGas. Cal PA recommends addressing SDG&E’s potential ownership of OMEC in a separate proceeding. As a result, Cal PA’s proposed 2019 revenue requirement does not include the estimated $68 million included in SDG&E’s GRC application associated with owning and operating the generating facility. As we discuss in Note 1, on March 28, 2019, OMEC LLC exercised the put option requiring SDG&E to purchase the power plant by October 3, 2019, which is subject to the results of rehearing requests. TURN and other intervenors oppose various components of our revenue requests in the 2019 GRC applications.

The results of the rate case may materially and adversely differ from what is contained in the GRC applications.

We expect a preliminary decision from the CPUC in mid-2019.

2016 General Rate Case

As we discuss in Notes 4 and 8 of the Notes to Consolidated Financial Statements in the Annual Report, the 2016 GRC FD required SDG&E and SoCalGas to each establish a two-way income tax expense memorandum account to track certain revenue variances resulting from certain differences between the income tax expense forecasted in the GRC and the income tax expense incurred from 2016 through 2018. At March 31, 2019, the recorded regulatory liability associated with these tracked amounts totaled $90 million and $95 million for SDG&E and SoCalGas, respectively. The recorded liability is primarily related to lower income tax expense incurred than was forecasted in the GRC relating to tax repairs deductions, self-developed software deductions and certain book-over-tax depreciation. The tracking accounts will remain open until the CPUC decides to close the accounts, which we expect will be reviewed in the 2019 GRC proceedings.

The 2016 GRC FD revenue requirement was authorized using a federal income tax rate of 35 percent. As a result of the TCJA, the federal income tax rate of 21 percent became effective January 1, 2018. Since SDG&E and SoCalGas continue to collect authorized revenues based on a 35 percent tax rate, SDG&E and SoCalGas are recording revenue deferrals, aligned with authorized seasonality factors, that reflect the estimated reduction in the revenue requirement. As of March 31, 2019, SDG&E and SoCalGas recorded regulatory liabilities of $95 million and $91 million, respectively, in anticipation of amounts that will benefit customers in future rates. SDG&E also recorded a $85 million regulatory liability at March 31, 2019, relating to its FERC jurisdictional rates, in anticipation of amounts that will benefit customers in future rates for the decrease in the federal income tax rate.

CPUC Cost of Capital

In April 2019, SDG&E and SoCalGas filed separate applications with the CPUC to update their cost of capital effective January 1, 2020. SDG&E proposed to adjust its authorized capital structure by increasing the amount of its common equity from 52 percent to 56 percent. SDG&E also proposed to increase its authorized ROE from 10.2 percent to 14.3 percent, including a premium for wildfire risk of 3.4 percent, and to increase its authorized return on rate base from 7.55 percent to 10.03 percent. SoCalGas proposed to adjust its authorized capital structure by increasing the amount of its common equity from 52 percent to 56 percent. SoCalGas also proposed to increase its authorized ROE from 10.05 percent to 10.7 percent and to increase its authorized return on rate base from 7.34 percent to 7.85 percent.

SOCALGAS

Billing Practices OII

In May 2017, the CPUC issued an OII to determine whether SoCalGas violated any provisions of the California Public Utilities Code, General Orders, CPUC decisions, or other requirements pertaining to billing practices from 2014 through 2016. The CPUC examined the timeliness of monthly bills, extending the billing period for customers, and issuing estimated bills, including an examination of SoCalGas’ gas tariff rules. In January 2019, the CPUC ordered SoCalGas to pay $8 million in penalties, including $3 million payable to California’s general fund and $5 million to be credited to customers that received delayed bills (greater than 45 days) in the form of a $100 bill credit. SoCalGas filed an appeal of the CPUC’s conclusions in the order, which, in April 2019, the CPUC denied.SAN ONOFRE NUCLEAR GENERATING STATION

We provide below updates to ongoing matters related to SONGS, a nuclear generating facility near San Clemente, California that ceased operations in June 2013, and in which SDG&E has a 20-percent 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. 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 majority of the dismantlement work is expected to take 10 years. 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 percent of the total contract price.

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. The NDT assets are presented on the Sempra Energy 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. SDG&E has received authorization from the CPUC to access NDT funds of up to $455 million for 2013 through 2019 (2019 forecasted) SONGS decommissioning costs. This includes up to $93 million authorized by the CPUC in January 2019 to be withdrawn from the NDT for forecasted 2019 SONGS Units 2 and 3 costs as decommissioning costs are incurred.

In December 2016, the IRS and the U.S. Department of the Treasury issued proposed regulations that clarify the definition of “nuclear decommissioning costs,” which are costs that may be paid for or reimbursed from a qualified trust fund. The proposed regulations state that costs related to the construction and maintenance of independent spent fuel management installations are included in the definition of “nuclear decommissioning costs.” The proposed regulations will be effective prospectively once they are finalized; however, the IRS has stated that it will not challenge taxpayer positions consistent with the proposed regulations for taxable years ending on or after the date the proposed regulations were issued. SDG&E is awaiting the adoption of, or additional refinement to, the proposed regulations before determining whether the proposed regulations will allow SDG&E to access the NDT funds for reimbursement or payment of the spent fuel management costs incurred in 2017 and subsequent years. Further clarification of the proposed regulations could enable SDG&E to access the NDT to recover spent fuel management costs before Edison reaches final settlement with the DOE regarding the DOE’s reimbursement of these costs. Historically, the DOE’s reimbursements of spent fuel storage costs have not resulted in timely or complete recovery of these costs. We discuss the DOE’s responsibility for spent nuclear fuel below. The IRS held public hearings on the proposed regulations in October 2017. It is unclear when clarification of the proposed regulations might be provided or when the proposed regulations will be finalized.

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 March 31, 2019:
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies(1)	$	48	$	—	$	—		$	48
Municipal bonds(2)	271		8		—			279
Other securities(3)	236		3		(1		)	238
Total debt securities	555		11		(1		)	565
Equity securities	166		299		(6		)	459
Cash and cash equivalents	13		—		—			13
Total	$	734	$	310	$	(7	)	$	1,037
At December 31, 2018:
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies	$	52	$	1	$	—		$	53
Municipal bonds	266		4		(1		)	269
Other securities	238		1		(5		)	234
Total debt securities	556		6		(6		)	556
Equity securities	168		253		(10		)	411
Cash and cash equivalents	7		—		—			7
Total	$	731	$	259	$	(16	)	$	974

⁽¹⁾  Maturity dates are 2019-2049.

⁽²⁾  Maturity dates are 2019-2056.

⁽³⁾  Maturity dates are 2019-2064.

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 March 31,
	2019			2018
Proceeds from sales	$	225		$	210
Gross realized gains	5			4
Gross realized losses	(2		)	(3		)

Net unrealized gains and losses, as well as realized gains and losses that are reinvested in the NDT, are included in noncurrent Regulatory Liabilities on Sempra Energy’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

SDG&E’s ARO related to decommissioning costs for the SONGS units was $620 million at March 31, 2019. 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 2018 dollars is approximately $810 million.

U.S. DEPARTMENT OF ENERGY NUCLEAR FUEL DISPOSAL

Spent nuclear fuel from SONGS is currently stored on-site in an ISFSI licensed by the Nuclear Regulatory Commission or temporarily in spent fuel pools. In October 2015, the California Coastal Commission approved Edison’s application for the proposed expansion of the ISFSI at SONGS. The ISFSI expansion began construction in 2016 and the transfer of the spent nuclear fuel from Units 2 and 3 to the ISFSI began in 2018. Edison suspended this transfer on August 3, 2018 due to an incident that occurred when a spent fuel canister was getting loaded into the ISFSI. The incident did not result in any harm to the public or workers and the canister was subsequently safely loaded into the IFSFI. Edison has not resumed spent fuel transfer operations at SONGS, but has publicly stated that it will resume operations once it is satisfied all corrective actions are in place and proven effective and the NRC has completed its on-site inspection activities. The ISFSI will operate until 2049, when it is assumed that the DOE will have taken custody of all the SONGS spent fuel. The ISFSI would then be decommissioned, and the site restored to its original environmental state. Until then, SONGS owners are responsible for interim storage of spent nuclear fuel at SONGS.

The Nuclear Waste Policy Act of 1982 made the DOE responsible for accepting, transporting, and disposing of spent nuclear fuel. However, it is uncertain when the DOE will begin accepting spent nuclear fuel from SONGS. This delay will lead to increased costs for spent fuel storage. SDG&E will continue to support Edison in its pursuit of claims on behalf of the SONGS co-owners against the DOE for its failure to timely accept the spent nuclear fuel. However, it is unclear whether Edison will enter into a new settlement with the DOE or pursue litigation claims for spent fuel management costs incurred on or after January 1, 2017.

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 owners, including SDG&E, also maintain nuclear property damage insurance at $1.5 billion, with a $500 million property damage sublimit on the ISFSI, which exceeds the minimum federal requirements of $1.06 billion. This insurance coverage is provided through NEIL. The NEIL policies have specific exclusions and limitations that can result in reduced or eliminated 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 $10.4 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

3 Months Ended

Mar. 31, 2019

Business Combinations [Abstract]

ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS

ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS

We consolidate assets acquired and liabilities assumed as of the purchase date and include earnings from acquisitions in consolidated earnings after the purchase date.

ACQUISITIONS

Sempra Texas Utility

On March 9, 2018, Sempra Energy completed the acquisition of an indirect, 100-percent interest in Oncor Holdings, which owned 80.03 percent of Oncor, and other EFH assets and liabilities unrelated to Oncor, pursuant to the Merger Agreement with EFH. Under the Merger Agreement, we paid Merger Consideration of $9.45 billion in cash and an additional $31 million representing an adjustment for dividends and payments pursuant to a tax sharing agreement with Oncor and Oncor Holdings. Also on March 9, 2018, in a separate transaction, Sempra Energy, through its interest in Oncor Holdings, acquired an additional 0.22 percent of the outstanding membership interests in Oncor from OMI for approximately $26 million in cash, bringing Sempra Energy’s indirect ownership in Oncor to 80.25 percent. TTI, an investment vehicle indirectly owned by third parties unaffiliated with Oncor Holdings or Sempra Energy, continues to own 19.75 percent of Oncor’s outstanding membership interests.

We discuss this acquisition, including the purchase price allocation, in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report.

Sempra South American Utilities

Compañía Transmisora del Norte Grande S.A.

On December 18, 2018, Chilquinta Energía acquired a 100-percent interest in Compañía Transmisora del Norte Grande S.A. through a sales and purchase agreement with AES Gener S.A. and its subsidiary Sociedad Eléctrica Angamos S.A. We completed the acquisition for a purchase price of $226 million and paid $208 million (net of $18 million cash acquired) with available cash on hand at Sempra South American Utilities.

We accounted for this business combination using the acquisition method of accounting. We allocated the $208 million in cash paid ($226 million purchase price less $18 million of cash acquired) to the identifiable assets acquired and liabilities assumed based on their respective fair values, with the excess recognized as goodwill, which is included in assets held for sale in discontinued operations. There were no measurement period adjustments related to this acquisition during the three months ended March 31, 2019. At March 31, 2019, the purchase price allocation was preliminary and subject to completion. Adjustments to the fair value estimates may occur as the process conducted for various valuations and assessments is finalized, primarily related to deferred income taxes.

We discuss this acquisition, including the purchase price allocation, in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report.

PENDING ACQUISITIONS

Sempra Texas Utility

On October 18, 2018, Oncor entered into the InfraREIT Merger Agreement, whereby Oncor has agreed to acquire 100 percent of the issued and outstanding shares of InfraREIT and 100 percent of the limited partnership units of its subsidiary, InfraREIT Partners, for approximately $1,275 million, or $21 per share and unit, plus approximately $40 million for a management

agreement termination fee, as well as other customary transaction costs incurred by InfraREIT that would be borne by Oncor as part of the acquisition. In addition, the transaction includes InfraREIT’s outstanding debt, which as of March 31, 2019 was approximately $946 million. Consummation of the InfraREIT Merger Agreement is subject to the satisfaction of certain closing conditions, including the substantially concurrent consummation of the transactions contemplated by the Asset Exchange Agreement and Securities Purchase Agreement, discussed below.

On October 18, 2018, Oncor entered into the Asset Exchange Agreement, whereby SDTS has agreed to accept and assume certain assets and liabilities of SU in exchange for certain SDTS assets. As currently contemplated, SDTS would receive certain real property and other assets used in the electric transmission and distribution business in Central, North and West Texas, as well as the equity interests in GS Project Entity, LLC (a wholly owned subsidiary of SU) and SU would receive certain real property and other assets that are near the Texas-Mexico border. Immediately prior to completing the exchange, SDTS would become a wholly owned, indirect subsidiary of InfraREIT Partners. Consummation of the Asset Exchange Agreement is subject to the satisfaction of certain closing conditions, including the substantially concurrent consummation of the transactions contemplated by the Securities Purchase Agreement, discussed below.

On October 18, 2018, Sempra Energy entered into the Securities Purchase Agreement, whereby Sempra Texas Utilities Holdings I, LLC (a wholly owned subsidiary of Sempra Energy in our Sempra Texas Utility reportable segment) has agreed to acquire a 50-percent economic interest in Sharyland Holdings, LP for approximately $98 million, subject to customary closing adjustments. In connection with and prior to the consummation of the Securities Purchase Agreement, Sharyland Holdings, LP would own 100- percent of the membership interests in SU and SU would convert into a limited liability company, which is expected to be named Sharyland Utilities, LLC. Upon consummation of the Securities Purchase Agreement, Sempra Texas Utilities Holdings I, LLC would indirectly own and account for its 50-percent membership interest in Sharyland Utilities, LLC as an equity method investment. Consummation of the Securities Purchase Agreement is subject to the satisfaction of certain closing conditions, including the substantially concurrent consummation of the transactions contemplated by the InfraREIT Merger Agreement and the Asset Exchange Agreement.

For Oncor to fund its acquisition of interests in InfraREIT, Sempra Energy and certain indirect equity holders of TTI have committed to make capital contributions proportionate to their respective ownership interest in Oncor, with the amount estimated to be contributed by Sempra Energy equal to approximately $1,025 million, excluding Sempra Energy’s share of approximately $40 million for a management agreement termination fee, as well as other customary transaction costs incurred by InfraREIT that would be borne by Oncor as part of the acquisition. We expect to fund our capital contribution to Oncor and to purchase the 50-percent limited-partner interest in Sharyland Holdings, LP by utilizing a portion of the proceeds received from the sales of Sempra Renewables’ assets. The capital contributions are contingent on the satisfaction of customary conditions, including the substantially simultaneous closing of the transactions contemplated by the InfraREIT Merger Agreement, but are not a condition to the transactions contemplated therein.

The transactions are subject to the satisfaction of certain closing conditions, including approval by the PUCT. In December 2018, early termination of the 30-day waiting period required by the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, was granted. In March 2019, we received approval from the FERC and clearance from the Committee on Foreign Investment in the United States. In addition, the acquisition of InfraREIT was approved by the InfraREIT stockholders on February 7, 2019. We expect that the transactions will close in mid-2019.

DIVESTITURES

Sempra LNG

On February 7, 2019, Sempra LNG completed the sale of its non-utility natural gas storage assets in the southeast U.S. (comprised of Mississippi Hub and Bay Gas), which we classified as held for sale at December 31, 2018, to an affiliate of ArcLight Capital Partners and received cash proceeds of $322 million (subject to working capital adjustments), net of transaction costs. In January 2019, Sempra LNG completed the sale of other non-utility assets for $5 million.

ASSETS HELD FOR SALE

We classify assets as held for sale when management approves and commits to a formal plan to actively market an asset for sale and we expect the sale to close within the next 12 months. Upon classifying an asset as held for sale, we record the asset at the lower of its carrying value or its estimated fair value reduced for selling costs.

Sempra Renewables

On February 12, 2019, Sempra Renewables entered into an agreement with American Electric Power Company, Inc. (AEP) to sell its remaining wind assets and investments. On April 22, 2019, Sempra Renewables completed the sale to AEP for $584 million in cash, subject to working capital and other customary adjustments. Upon completion of the sale, remaining nominal business activities at Sempra Renewables were subsumed into Parent and other and the Sempra Renewables segment ceased to exist.

The following table summarizes the carrying amounts of the major classes of assets and related liabilities classified as held for sale.

ASSETS HELD FOR SALE
(Dollars in millions)
	Sempra Renewables’ wind assets
	At March 31, 2019
Cash and cash equivalents	$	4
Accounts receivable – trade, net	2
Other current assets	2
Property, plant and equipment, net	366
Total assets held for sale	$	374
Accounts payable – trade	$	1
Asset retirement obligations	6
Total liabilities held for sale(1)	$	7

⁽¹⁾  Included in Other Current Liabilities on Sempra Energy’s Condensed Consolidated Balance Sheet.

Sempra Renewables’ wind equity method investments totaling $290 million at March 31, 2019, which are included in the sale to AEP, were classified as Other Investments on Sempra Energy’s Condensed Consolidated Balance Sheet.DISCONTINUED OPERATIONS

On January 25, 2019, our board of directors approved a plan to sell our South American businesses. We launched a formal process to sell our South American businesses and expect to complete the sale by the end of 2019. We determined that these businesses, which previously constituted the Sempra South American Utilities segment, and certain activities associated with those businesses, met the held-for-sale criteria. These businesses are presented as discontinued operations, as the planned sale represents a strategic shift that will have a major effect on our operations and financial results. We do not plan to have significant continuing involvement in or be able to exercise significant influence on the operating or financial policies of these operations after they are sold. Accordingly, the results of operations, financial position and cash flows for these businesses have been reclassified to discontinued operations for all periods presented.

Discontinued operations that were previously in the Sempra South American Utilities segment include our 100-percent interest in Chilquinta Energía in Chile, our 83.6-percent interest in Luz del Sur in Peru and our 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. 

Summarized results from discontinued operations were as follows:

DISCONTINUED OPERATIONS
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Revenues	$	421		$	426
Cost of sales	(265		)	(293		)
Operating expenses	(45		)	(54		)
Interest and other	(3		)	(5		)
Income before income taxes and equity earnings of unconsolidated entities	108			74
Income tax expense	(151		)	(47		)
Equity earnings	1			1
(Loss) income from discontinued operations, net of income tax	(42		)	28
Earnings attributable to noncontrolling interests	(9		)	(7		)
(Losses) earnings from discontinued operations attributable to common shares	$	(51	)	$	21

The following table summarizes the carrying amounts of the major classes of assets and related liabilities classified as held for sale in discontinued operations.

ASSETS HELD FOR SALE IN DISCONTINUED OPERATIONS
(Dollars in millions)
	March 31, 2019		December 31, 2018
Cash and cash equivalents	$	67	$	88
Accounts receivable, net	331		315
Due from unconsolidated affiliates	3		2
Inventories	41		38
Other current assets	15		16
Current assets	$	457	$	459
Due from unconsolidated affiliates	$	46	$	44
Goodwill and other intangible assets	834		819
Property, plant and equipment, net	2,459		2,357
Other noncurrent assets	49		39
Noncurrent assets	$	3,388	$	3,259
Short-term debt	$	46	$	55
Accounts payable	188		176
Current portion of long-term debt and finance leases	22		29
Other current liabilities	119		108
Current liabilities	$	375	$	368
Long-term debt and finance leases	$	721	$	708
Deferred income taxes	263		250
Other noncurrent liabilities	62		55
Noncurrent liabilities	$	1,046	$	1,013

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INVESTMENTS IN UNCONSOLIDATED ENTITIES

3 Months Ended

Mar. 31, 2019

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 (Losses) on the Condensed Consolidated Statements of Operations. 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.

Our equity method investments include various domestic and foreign entities. Our foreign equity method investees are corporations whose operations are generally taxable on a stand alone basis in the countries in which they operate, and we recognize our equity in such income or loss net of investee income tax.

Oncor is a domestic partnership for U.S. federal income tax purposes and is not included in the consolidated income tax return of Sempra Energy. Rather, only our equity earnings from our investment in Oncor Holdings (a disregarded entity for tax purposes) are included in our consolidated income tax return. A tax sharing agreement with TTI, Oncor Holdings and Oncor provides for the calculation of an income tax liability substantially as if Oncor Holdings and Oncor were taxed as corporations, and requires tax payments determined on that basis. While partnerships are not subject to income taxes, in consideration of the tax sharing agreement and Oncor being subject to the provisions of U.S. GAAP governing rate-regulated operations, Oncor recognizes amounts determined under cost-based regulatory rate-setting processes (with such costs including income taxes), as if it were taxed as a corporation. As a result, since Oncor Holdings consolidates Oncor, we recognize equity earnings from our investment in Oncor Holdings net of its recorded income tax.

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

SEMPRA TEXAS UTILITY

We account for our 100-percent ownership interest in Oncor Holdings as an equity method investment. Due to the ring-fencing measures, governance mechanisms, and commitments in effect following the Merger, 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 each of the first quarter of 2019 and the second quarter of 2019 through May 7, 2019, Sempra Energy contributed $56 million to Oncor, and Oncor Holdings distributed to Sempra Energy $54 million in dividends and $3 million in tax sharing payments.

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

SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS
(Dollars in millions)
	Three months ended March 31, 2019			March 9 - March 31, 2018
Operating revenues	$	1,016		$	236
Operating expense	(775		)	(185		)
Income from operations	241			51
Interest expense	(86		)	(22		)
Income tax expense	(23		)	(7		)
Net income	114			19
Noncontrolling interest held by TTI	(23		)	(4		)
Earnings attributable to Sempra Energy(1)	91			15

⁽¹⁾  Earnings at Oncor Holdings differ from earnings at the Sempra Texas Utility segment due to amortization of a tax sharing liability associated with a tax sharing arrangement and basis differences in AOCI.

SEMPRA MEXICO

Sempra Mexico invested cash of $25 million in the IMG JV in the three months ended March 31, 2018.

SEMPRA RENEWABLES

As we discuss in Note 5, in February 2019, Sempra Renewables entered into an agreement to sell its remaining wind assets and investments. At March 31, 2019, the wind investments had a carrying value of $290 million and were included in Other

Investments on Sempra Energy’s Condensed Consolidated Balance Sheets. We completed the sale in April 2019, as we discuss in Note 5.

SEMPRA LNG

Sempra LNG capitalized $13 million and $11 million of interest in the three months ended March 31, 2019 and 2018, respectively, related to its investment in Cameron LNG JV, which has not commenced planned principal operations. In the three months ended March 31, 2019 and 2018, Sempra LNG invested cash of $25 million and $29 million, respectively, in this unconsolidated JV.

GUARANTEES

At March 31, 2019, we had outstanding guarantees aggregating a maximum of $4.2 billion with an aggregate carrying value of $10 million. We discuss these guarantees in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.

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DEBT AND CREDIT FACILITIES

3 Months Ended

Mar. 31, 2019

Debt Disclosure [Abstract]

Debt and Credit Facilities

DEBT AND CREDIT FACILITIES

LINES OF CREDIT

Primary U.S. Committed Lines of Credit

At March 31, 2019, Sempra Energy Consolidated had an aggregate of approximately $5.4 billion in three primary U.S. committed lines of credit for Sempra Energy, Sempra Global and the California Utilities to provide liquidity and to support commercial paper. The principal terms of these committed lines of credit, which expire in October 2020, 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)
	March 31, 2019
	Total facility			Commercial paper outstanding(1)			Available unused credit
Sempra Energy(2)	$	1,250		$	—		$	1,250
Sempra Global(3)	3,185			(1,289		)	1,896
California Utilities(4):
SDG&E	750			(238		)	512
SoCalGas	750			(190		)	560
Less: subject to a combined limit of $1 billion for both utilities	(500		)	—			(500		)
	1,000			(428		)	572
Total	$	5,435		$	(1,717	)	$	3,718

⁽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⁾  The facility also provides for issuance of up to $400 million of letters of credit on behalf of Sempra Energy with the amount of borrowings otherwise available under the facility reduced by the amount of outstanding letters of credit. No letters of credit were outstanding at March 31, 2019.

⁽³⁾  Commercial paper outstanding is before reductions of unamortized discount of $2 million. Sempra Energy guarantees Sempra Global’s obligations under the credit facility.

⁽⁴⁾  The facility also provides for the issuance of letters of credit on behalf of each utility, subject to a combined letter of credit commitment of $250 million for both utilities. The amount of borrowings otherwise available under the facility is reduced by the amount of outstanding letters of credit. No letters of credit were outstanding at March 31, 2019.

Sempra Energy, SDG&E and SoCalGas must maintain a ratio of indebtedness to total capitalization (as defined in each of the applicable credit facilities) of no more than 65 percent at the end of each quarter. At March 31, 2019, each entity was in compliance with this and all other financial covenants under its respective credit facility.

Foreign Committed Lines of Credit

In February 2019, IEnova revised the terms of its five-year revolving credit facility by increasing the amount available under the facility from $1.17 billion to $1.5 billion, extending the expiration of the facility from August 2020 to February 2024 and increasing the syndicate of lenders from eight to 10. At March 31, 2019, available unused credit on this line was approximately $692 million.

On April 11, 2019, IEnova entered into a three-year, $100 million revolving credit agreement with Scotiabank Inverlat, S.A. Under the agreement, withdrawals may be made for up to one year in either U.S. dollars or Mexican pesos.

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 March 31, 2019, we had approximately $611 million in standby letters of credit outstanding under these agreements.

WEIGHTED-AVERAGE INTEREST RATES

The weighted-average interest rates on total short-term debt at Sempra Energy Consolidated were 3.07 percent and 2.99 percent at March 31, 2019 and December 31, 2018, respectively. The weighted-average interest rates on total short-term debt at SDG&E were 2.80 percent and 2.97 percent at March 31, 2019 and December 31, 2018, respectively. The weighted-average interest rates on total short-term debt at SoCalGas were 2.49 percent and 2.58 percent at March 31, 2019 and December 31, 2018, respectively.

INTEREST RATE SWAPS

In February 2019, Sempra Energy entered into floating-to-fixed interest rate swaps to hedge interest payments on the $850 million of variable rate notes issued in October 2017 and maturing in March 2021, resulting in an all-in fixed rate of 3.069 percent. We discuss our interest rate swaps to hedge cash flows in Note 8.

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DERIVATIVE FINANCIAL INSTRUMENTS

3 Months Ended

Mar. 31, 2019

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 our asset values may fall or our liabilities 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 designate each derivative as (1) a cash flow hedge, (2) a fair value hedge, 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 hedge), on the balance sheet (fair value hedges and regulatory offsets), or recognized in earnings. 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, Sempra LNG and Sempra Renewables may use natural gas and electricity derivatives, as appropriate, 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 or in Cost of Sales on the Condensed Consolidated Statements of Operations. Certain of these derivatives may also be designated as cash flow hedges. Sempra Mexico may also use natural gas energy derivatives with the objective of managing price risk and lowering natural gas prices at its distribution operations. These derivatives, which are recorded as commodity costs that are offset by regulatory account balances and recovered in rates, are recognized in Cost of Natural Gas on the Condensed Consolidated Statements of Operations.

▪ 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 GHG allowances.

The following table summarizes net energy derivative volumes.

NET ENERGY DERIVATIVE VOLUMES
(Quantities in millions)
Commodity	Unit of measure	March 31, 2019	December 31, 2018
Sempra Energy Consolidated:
Natural gas	MMBtu	33	35
Electricity	MWh	2	2
Congestion revenue rights	MWh	50	52
SDG&E:
Natural gas	MMBtu	32	33
Electricity	MWh	2	2
Congestion revenue rights	MWh	50	52

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 Energy 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. Separately, Otay Mesa VIE has entered into interest rate swap agreements, designated as cash flow hedges, to moderate its exposure to interest rate changes.

The following table presents the net notional amounts of our interest rate derivatives, excluding JVs.

INTEREST RATE DERIVATIVES
(Dollars in millions)
	March 31, 2019			December 31, 2018
	Notional debt		Maturities	Notional debt		Maturities
Sempra Energy Consolidated:
Cash flow hedges(1)	$	1,430	2019-2032	$	594	2019-2032
SDG&E:
Cash flow hedge(1)	142		2019	142		2019

⁽¹⁾  Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE. In December 2018, OMEC LLC entered into new floating-to-fixed interest rate swaps with notional amounts of $159 million effective April 30, 2019 through October 31, 2019, and a swaption with a notional amount of $142 million effective October 31, 2019 through October 31, 2023.

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 utilize foreign currency derivatives as a means to manage the risk of exposure to significant fluctuations in our income tax expense and equity earnings from these impacts; however, we generally do not hedge our deferred income tax assets and liabilities or for inflation.

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

FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	March 31, 2019			December 31, 2018
	Notional amount		Maturities	Notional amount		Maturities
Sempra Energy Consolidated:
Cross-currency swaps	$	306	2019-2023	$	306	2019-2023
Other foreign currency derivatives	1,084		2019-2020	1,158		2019-2020

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, as the cash collateral was in excess of liability positions.

DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	March 31, 2019
	Current assets: Other(1)			Other assets: Sundry			Current liabilities: Other			Deferred credits and other liabilities: Deferred credits and other
Sempra Energy Consolidated:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments(2)	$	—		$	—		$	(5	)	$	(146	)
Derivatives not designated as hedging instruments:
Foreign exchange instruments	12			—			—			—
Commodity contracts not subject to rate recovery	58			6			(65		)	(5		)
Associated offsetting commodity contracts	(47		)	(2		)	47			2
Commodity contracts subject to rate recovery	50			236			(41		)	(65		)
Associated offsetting commodity contracts	(5		)	(2		)	5			2
Associated offsetting cash collateral	—			—			3			3
Net amounts presented on the balance sheet	68			238			(56		)	(209		)
Additional cash collateral for commodity contracts not subject to rate recovery	25			—			—			—
Additional cash collateral for commodity contracts subject to rate recovery	26			—			—			—
Total(3)	$	119		$	238		$	(56	)	$	(209	)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	45		$	234		$	(37	)	$	(65	)
Associated offsetting commodity contracts	(5		)	(2		)	5			2
Associated offsetting cash collateral	—			—			3			3
Net amounts presented on the balance sheet	40			232			(29		)	(60		)
Additional cash collateral for commodity contracts subject to rate recovery	25			—			—			—
Total(3)	$	65		$	232		$	(29	)	$	(60	)
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	5		$	2		$	(4	)	$	—
Net amounts presented on the balance sheet	5			2			(4		)	—
Additional cash collateral for commodity contracts subject to rate recovery	1			—			—			—
Total	$	6		$	2		$	(4	)	$	—

 

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

⁽²⁾ Includes a negligible amount for Otay Mesa VIE.

⁽³⁾ Normal purchase contracts previously measured at fair value are excluded.

DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	December 31, 2018
	Current assets: Other(1)			Other assets: Sundry			Current liabilities: Other			Deferred credits and other liabilities: Deferred credits and other
Sempra Energy Consolidated:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments(2)	$	2		$	—		$	(3	)	$	(147	)
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	153			7			(164		)	(6		)
Associated offsetting commodity contracts	(133		)	(3		)	133			3
Commodity contracts subject to rate recovery	64			233			(42		)	(72		)
Associated offsetting commodity contracts	(6		)	(2		)	6			2
Associated offsetting cash collateral	—			—			—			2
Net amounts presented on the balance sheet	80			235			(70		)	(218		)
Additional cash collateral for commodity contracts not subject to rate recovery	19			—			—			—
Additional cash collateral for commodity contracts subject to rate recovery	33			—			—			—
Total(3)	$	132		$	235		$	(70	)	$	(218	)
SDG&E:
Derivatives designated as hedging instruments:
Interest rate instruments(2)	$	—		$	—		$	(1	)	$	—
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	60			233			(37		)	(72		)
Associated offsetting commodity contracts	(6		)	(2		)	6			2
Associated offsetting cash collateral	—			—			—			2
Net amounts presented on the balance sheet	54			231			(32		)	(68		)
Additional cash collateral for commodity contracts subject to rate recovery	28			—			—			—
Total(3)	$	82		$	231		$	(32	)	$	(68	)
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	4		$	—		$	(5	)	$	—
Net amounts presented on the balance sheet	4			—			(5		)	—
Additional cash collateral for commodity contracts subject to rate recovery	5			—			—			—
Total	$	9		$	—		$	(5	)	$	—

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

⁽²⁾ Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE.

⁽³⁾ Normal purchase contracts previously measured at fair value are excluded.

The table below 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 March 31,							Three months ended March 31,
	2019			2018			Location	2019			2018
Sempra Energy Consolidated:
Interest rate and foreign exchange instruments(1)	$	(3	)	$	54		Interest Expense	$	(1	)	$	2
							Other Income, Net	3			18
Interest rate and foreign exchange instruments	(68		)	70			Equity Earnings (Losses)	(1		)	(4		)
Foreign exchange instruments	(3		)	(7		)	Revenues: Energy- Related Businesses	(1		)	—
Total	$	(74	)	$	117			$	—		$	16
SDG&E:
Interest rate instruments(1)	$	—		$	1		Interest Expense	$	(1	)	$	(3	)

⁽¹⁾  Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.

For Sempra Energy Consolidated, we expect that net gains of $5 million, which are net of income tax expense, that are currently recorded in AOCI (including $1 million of losses in NCI related to Otay Mesa VIE at SDG&E) related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. SoCalGas expects that $1 million of losses, net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. Actual amounts ultimately reclassified into earnings depend on the interest rates in effect when derivative contracts mature.

For all forecasted transactions, the maximum remaining term over which we are hedging exposure to the variability of cash flows at March 31, 2019 is approximately 13 years and less than one year for Sempra Energy Consolidated and SDG&E, respectively. The maximum remaining term for which we are hedging exposure to the variability of cash flows at our equity method investees is 15 years.

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

UNDESIGNATED DERIVATIVE IMPACTS
(Dollars in millions)
		Pretax gain (loss) on derivatives recognized in earnings
		Three months ended March 31,
	Location	2019		2018
Sempra Energy Consolidated:
Foreign exchange instruments	Other Income, Net	$	10	$	44
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	—		(9		)
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	2		2
Commodity contracts subject to rate recovery	Cost of Natural Gas	2		1
Total		$	14	$	38
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	2	$	2
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas	$	2	$	1

CONTINGENT FEATURES

For Sempra Energy Consolidated, 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 Energy Consolidated, the total fair value of this group of derivative instruments in a net liability position at March 31, 2019 and December 31, 2018 was $14 million and $16 million, respectively. For SoCalGas, the total fair value of this group of derivative instruments in a net liability position at March 31, 2019 and December 31, 2018 was $4 million and $5 million, respectively. At March 31, 2019, if the credit ratings of Sempra Energy or SoCalGas were reduced below investment grade, $15 million and $4 million, respectively, of additional assets could be required to be posted as collateral for these derivative contracts.

For Sempra Energy Consolidated, 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

3 Months Ended

Mar. 31, 2019

Fair Value Disclosures [Abstract]

Fair Value Measurements

FAIR VALUE MEASUREMENTS

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

RECURRING FAIR VALUE MEASURES

The three tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis at March 31, 2019 and December 31, 2018. 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 value 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, 2018.

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 (other than a $7 million investment at March 31, 2019 measured at net asset value):

▪ Nuclear decommissioning trusts reflect the assets of SDG&E’s NDT, excluding cash balances. 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.”

▪ 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 March 31, 2019 and December 31, 2018.

RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
	Fair value at March 31, 2019
	Level 1			Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	454		$	5	$	—	$	459
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies	39			9		—		48
Municipal bonds	—			279		—		279
Other securities	—			238		—		238
Total debt securities	39			526		—		565
Total nuclear decommissioning trusts(1)	493			531		—		1,024
Interest rate and foreign exchange instruments	—			12		—		12
Commodity contracts not subject to rate recovery	—			15		—		15
Effect of netting and allocation of collateral(2)	25			—		—		25
Commodity contracts subject to rate recovery	—			8		271		279
Effect of netting and allocation of collateral(2)	21			—		5		26
Total	$	539		$	566	$	276	$	1,381
Liabilities:
Interest rate and foreign exchange instruments	$	—		$	151	$	—	$	151
Commodity contracts not subject to rate recovery	—			21		—		21
Commodity contracts subject to rate recovery	6			4		89		99
Effect of netting and allocation of collateral(2)	(6		)	—		—		(6		)
Total	$	—		$	176	$	89	$	265
	Fair value at December 31, 2018
	Level 1			Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	407		$	4	$	—	$	411
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies	43			10		—		53
Municipal bonds	—			269		—		269
Other securities	—			234		—		234
Total debt securities	43			513		—		556
Total nuclear decommissioning trusts(1)	450			517		—		967
Interest rate and foreign exchange instruments	—			2		—		2
Commodity contracts not subject to rate recovery	—			24		—		24
Effect of netting and allocation of collateral(2)	19			—		—		19
Commodity contracts subject to rate recovery	2			9		278		289
Effect of netting and allocation of collateral(2)	28			—		5		33
Total	$	499		$	552	$	283	$	1,334
Liabilities:
Interest rate and foreign exchange instruments	$	—		$	150	$	—	$	150
Commodity contracts not subject to rate recovery	—			34		—		34
Commodity contracts subject to rate recovery	2			5		99		106
Effect of netting and allocation of collateral(2)	(2		)	—		—		(2		)
Total	$	—		$	189	$	99	$	288

⁽¹⁾  Excludes cash balances and cash equivalents.

⁽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 March 31, 2019
	Level 1			Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	454		$	5	$	—	$	459
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies	39			9		—		48
Municipal bonds	—			279		—		279
Other securities	—			238		—		238
Total debt securities	39			526		—		565
Total nuclear decommissioning trusts(1)	493			531		—		1,024
Commodity contracts subject to rate recovery	—			1		271		272
Effect of netting and allocation of collateral(2)	20			—		5		25
Total	$	513		$	532	$	276	$	1,321
Liabilities:
Commodity contracts subject to rate recovery	$	6		$	—	$	89	$	95
Effect of netting and allocation of collateral(2)	(6		)	—		—		(6		)
Total	$	—		$	—	$	89	$	89
	Fair value at December 31, 2018
	Level 1			Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	407		$	4	$	—	$	411
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies	43			10		—		53
Municipal bonds	—			269		—		269
Other securities	—			234		—		234
Total debt securities	43			513		—		556
Total nuclear decommissioning trusts(1)	450			517		—		967
Commodity contracts subject to rate recovery	1			6		278		285
Effect of netting and allocation of collateral(2)	23			—		5		28
Total	$	474		$	523	$	283	$	1,280
Liabilities:
Interest rate instruments	$	—		$	1	$	—	$	1
Commodity contracts subject to rate recovery	2			—		99		101
Effect of netting and allocation of collateral(2)	(2		)	—		—		(2		)
Total	$	—		$	1	$	99	$	100

⁽¹⁾  Excludes cash balances and cash equivalents.

⁽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 March 31, 2019
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	—	$	7	$	—	$	7
Effect of netting and allocation of collateral(1)	1		—		—		1
Total	$	1	$	7	$	—	$	8
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	4	$	—	$	4
Total	$	—	$	4	$	—	$	4
	Fair value at December 31, 2018
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	1	$	3	$	—	$	4
Effect of netting and allocation of collateral(1)	5		—		—		5
Total	$	6	$	3	$	—	$	9
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	5	$	—	$	5
Total	$	—	$	5	$	—	$	5

⁽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

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 Energy Consolidated and SDG&E.

LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Balance at January 1	$	179		$	(28	)
Realized and unrealized gains	5			4
Allocated transmission instruments	—			3
Settlements	(2		)	(19		)
Balance at March 31	$	182		$	(40	)
Change in unrealized gains (losses) relating to instruments still held at March 31	$	13		$	(8	)

⁽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
2019	$	(8.57	)	to	$	35.21	$	(2.94	)
2018	(7.25		)	to	11.99		0.09

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 were as follows:

LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS
Settlement year		Price per MWh					Weighted-average price per MWh
2019	$	23.25	to	$	81.75	$	42.49
2018		20.00	to		47.65		35.42

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

Realized gains and losses associated with CRRs and long-term 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 Instruments

The fair values of certain of our financial instruments (cash, accounts and notes 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.

FAIR VALUE OF FINANCIAL INSTRUMENTS
(Dollars in millions)
	March 31, 2019
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
Sempra Energy Consolidated:
Long-term amounts due from unconsolidated affiliates	$	668	$	—	$	689	$	—	$	689
Long-term amounts due to unconsolidated affiliates	38		—		37		—		37
Total long-term debt(1)(2)	20,814		—		20,598		248		20,846
SDG&E:
Total long-term debt(2)(3)	$	4,978	$	—	$	4,918	$	220	$	5,138
SoCalGas:
Total long-term debt(4)	$	3,459	$	—	$	3,595	$	—	$	3,595
	December 31, 2018
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
Sempra Energy Consolidated:
Long-term amounts due from unconsolidated affiliates	$	644	$	—	$	648	$	4	$	652
Long-term amounts due to unconsolidated affiliates	37		—		35		—		35
Total long-term debt(2)(5)	21,340		—		20,616		247		20,863
SDG&E:
Total long-term debt(6)	$	4,996	$	—	$	4,897	$	220	$	5,117
SoCalGas:
Total long-term debt(7)	$	3,459	$	—	$	3,505	$	—	$	3,505

⁽¹⁾  Before reductions of unamortized discount and debt issuance costs of $201 million and excluding finance lease obligations of $1,277 million.

⁽²⁾  Level 3 instruments includes $220 million at both March 31, 2019 and December 31, 2018 related to Otay Mesa VIE.

⁽³⁾  Before reductions of unamortized discount and debt issuance costs of $48 million and excluding finance lease obligations of $1,272 million.

⁽⁴⁾  Before reductions of unamortized discount and debt issuance costs of $32 million and excluding finance lease obligations of $5 million.

⁽⁵⁾  Before reductions of unamortized discount and debt issuance costs of $206 million and excluding build-to-suit and capital lease obligations of $1,413 million.

⁽⁶⁾  Before reductions of unamortized discount and debt issuance costs of $49 million and excluding capital lease obligations of $1,272 million.

⁽⁷⁾  Before reductions of unamortized discount and debt issuance costs of $32 million and excluding capital lease obligations of $3 million.

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

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SAN ONOFRE NUCLEAR GENERATING STATION

3 Months Ended

Mar. 31, 2019

Regulated Operations [Abstract]

San Onofre Nuclear Generating Station (SONGS)

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.

REGULATORY ASSETS AND LIABILITIES

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

REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	March 31, 2019			December 31, 2018
SDG&E:
Fixed-price contracts and other derivatives	$	(144	)	$	(150	)
Deferred income taxes refundable in rates	(171		)	(236		)
Pension and other postretirement benefit plan obligations	190			186
Removal obligations	(1,946		)	(1,848		)
Unamortized loss on reacquired debt	6			7
Environmental costs	27			28
Sunrise Powerlink fire mitigation	121			120
Regulatory balancing accounts(1)
Commodity – electric	60			(8		)
Gas transportation	13			45
Safety and reliability	77			70
Public purpose programs	(80		)	(62		)
Other balancing accounts	67			145
Other regulatory liabilities, net(2)	(199		)	(177		)
Total SDG&E	(1,979		)	(1,880		)
SoCalGas:
Pension and other postretirement benefit plan obligations	479			470
Employee benefit costs	49			49
Removal obligations	(804		)	(833		)
Deferred income taxes refundable in rates	(248		)	(336		)
Unamortized loss on reacquired debt	6			7
Environmental costs	32			28
Workers’ compensation	9			9
Regulatory balancing accounts(1)
Commodity – gas, including transportation	16			196
Safety and reliability	348			332
Public purpose programs	(289		)	(325		)
Other balancing accounts	(143		)	(68		)
Other regulatory liabilities, net(2)	(160		)	(130		)
Total SoCalGas	(705		)	(601		)
Sempra Mexico:
Deferred income taxes recoverable in rates	81			81
Other regulatory assets	9			6
Total Sempra Energy Consolidated	$	(2,594	)	$	(2,394	)

⁽¹⁾  At March 31, 2019 and December 31, 2018, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $84 million and $78 million, respectively, and for SoCalGas was $405 million and $185 million, respectively. 

⁽²⁾   Includes regulatory assets earning a rate of return.

CALIFORNIA UTILITIES

CPUC General Rate Case

The CPUC uses a GRC proceeding to set sufficient rates to allow the California Utilities to recover their reasonable cost of O&M and to provide the opportunity to realize their authorized rates of return on their investment.

2019 General Rate Case

On October 6, 2017, SDG&E and SoCalGas filed their 2019 GRC applications requesting CPUC approval of test year revenue requirements for 2019 and attrition year adjustments for 2020 through 2022. SDG&E and SoCalGas are seeking revenue requirements for 2019 of $2.203 billion and $2.937 billion, respectively, which is an increase of $221 million and $481 million

over their respective 2018 revenue requirements (the 2019 proposed and 2018 actual revenue requirements reflect the impact of various updates made during the course of the proceeding). The California Utilities are proposing post-test year revenue requirement annual attrition percentages that are estimated to result in annual increases of approximately 5 percent to 7 percent at SDG&E and approximately 6 percent to 8 percent at SoCalGas. The original GRC applications filed in October 2017 did not reflect the impact of the TCJA, which we discuss in “2016 General Rate Case” below and in Note 8 of the Notes to Consolidated Financial Statements in the Annual Report. In April 2018, SDG&E and SoCalGas updated their applications to reflect the impact of the TCJA and filed a joint proposal to address the impacts. The TCJA impact to SDG&E is a reduction of approximately $58 million to its 2019 test year revenue requirement; however, SDG&E’s 2019 requested revenue requirement is unchanged as we evaluate potentially higher costs associated with mitigating wildfire risks. The TCJA impact to SoCalGas’ 2019 requested revenue requirement is a reduction of approximately $58 million, which is reflected in its updated request.

During the course of the proceeding, Cal PA recommended 2019 revenue requirements of $1.918 billion and $2.695 billion for SDG&E and SoCalGas, respectively, which is a net decrease of $64 million for SDG&E and a net increase of $239 million for SoCalGas compared to the 2018 revenue requirements. Cal PA proposes a three-year annual attrition percentage of 4 percent for SDG&E and a range of 4 percent to 5 percent for SoCalGas. Cal PA recommends addressing SDG&E’s potential ownership of OMEC in a separate proceeding. As a result, Cal PA’s proposed 2019 revenue requirement does not include the estimated $68 million included in SDG&E’s GRC application associated with owning and operating the generating facility. As we discuss in Note 1, on March 28, 2019, OMEC LLC exercised the put option requiring SDG&E to purchase the power plant by October 3, 2019, which is subject to the results of rehearing requests. TURN and other intervenors oppose various components of our revenue requests in the 2019 GRC applications.

The results of the rate case may materially and adversely differ from what is contained in the GRC applications.

We expect a preliminary decision from the CPUC in mid-2019.

2016 General Rate Case

As we discuss in Notes 4 and 8 of the Notes to Consolidated Financial Statements in the Annual Report, the 2016 GRC FD required SDG&E and SoCalGas to each establish a two-way income tax expense memorandum account to track certain revenue variances resulting from certain differences between the income tax expense forecasted in the GRC and the income tax expense incurred from 2016 through 2018. At March 31, 2019, the recorded regulatory liability associated with these tracked amounts totaled $90 million and $95 million for SDG&E and SoCalGas, respectively. The recorded liability is primarily related to lower income tax expense incurred than was forecasted in the GRC relating to tax repairs deductions, self-developed software deductions and certain book-over-tax depreciation. The tracking accounts will remain open until the CPUC decides to close the accounts, which we expect will be reviewed in the 2019 GRC proceedings.

The 2016 GRC FD revenue requirement was authorized using a federal income tax rate of 35 percent. As a result of the TCJA, the federal income tax rate of 21 percent became effective January 1, 2018. Since SDG&E and SoCalGas continue to collect authorized revenues based on a 35 percent tax rate, SDG&E and SoCalGas are recording revenue deferrals, aligned with authorized seasonality factors, that reflect the estimated reduction in the revenue requirement. As of March 31, 2019, SDG&E and SoCalGas recorded regulatory liabilities of $95 million and $91 million, respectively, in anticipation of amounts that will benefit customers in future rates. SDG&E also recorded a $85 million regulatory liability at March 31, 2019, relating to its FERC jurisdictional rates, in anticipation of amounts that will benefit customers in future rates for the decrease in the federal income tax rate.

CPUC Cost of Capital

In April 2019, SDG&E and SoCalGas filed separate applications with the CPUC to update their cost of capital effective January 1, 2020. SDG&E proposed to adjust its authorized capital structure by increasing the amount of its common equity from 52 percent to 56 percent. SDG&E also proposed to increase its authorized ROE from 10.2 percent to 14.3 percent, including a premium for wildfire risk of 3.4 percent, and to increase its authorized return on rate base from 7.55 percent to 10.03 percent. SoCalGas proposed to adjust its authorized capital structure by increasing the amount of its common equity from 52 percent to 56 percent. SoCalGas also proposed to increase its authorized ROE from 10.05 percent to 10.7 percent and to increase its authorized return on rate base from 7.34 percent to 7.85 percent.

SOCALGAS

Billing Practices OII

In May 2017, the CPUC issued an OII to determine whether SoCalGas violated any provisions of the California Public Utilities Code, General Orders, CPUC decisions, or other requirements pertaining to billing practices from 2014 through 2016. The CPUC examined the timeliness of monthly bills, extending the billing period for customers, and issuing estimated bills, including an examination of SoCalGas’ gas tariff rules. In January 2019, the CPUC ordered SoCalGas to pay $8 million in penalties, including $3 million payable to California’s general fund and $5 million to be credited to customers that received delayed bills (greater than 45 days) in the form of a $100 bill credit. SoCalGas filed an appeal of the CPUC’s conclusions in the order, which, in April 2019, the CPUC denied.SAN ONOFRE NUCLEAR GENERATING STATION

We provide below updates to ongoing matters related to SONGS, a nuclear generating facility near San Clemente, California that ceased operations in June 2013, and in which SDG&E has a 20-percent 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. 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 majority of the dismantlement work is expected to take 10 years. 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 percent of the total contract price.

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. The NDT assets are presented on the Sempra Energy 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. SDG&E has received authorization from the CPUC to access NDT funds of up to $455 million for 2013 through 2019 (2019 forecasted) SONGS decommissioning costs. This includes up to $93 million authorized by the CPUC in January 2019 to be withdrawn from the NDT for forecasted 2019 SONGS Units 2 and 3 costs as decommissioning costs are incurred.

In December 2016, the IRS and the U.S. Department of the Treasury issued proposed regulations that clarify the definition of “nuclear decommissioning costs,” which are costs that may be paid for or reimbursed from a qualified trust fund. The proposed regulations state that costs related to the construction and maintenance of independent spent fuel management installations are included in the definition of “nuclear decommissioning costs.” The proposed regulations will be effective prospectively once they are finalized; however, the IRS has stated that it will not challenge taxpayer positions consistent with the proposed regulations for taxable years ending on or after the date the proposed regulations were issued. SDG&E is awaiting the adoption of, or additional refinement to, the proposed regulations before determining whether the proposed regulations will allow SDG&E to access the NDT funds for reimbursement or payment of the spent fuel management costs incurred in 2017 and subsequent years. Further clarification of the proposed regulations could enable SDG&E to access the NDT to recover spent fuel management costs before Edison reaches final settlement with the DOE regarding the DOE’s reimbursement of these costs. Historically, the DOE’s reimbursements of spent fuel storage costs have not resulted in timely or complete recovery of these costs. We discuss the DOE’s responsibility for spent nuclear fuel below. The IRS held public hearings on the proposed regulations in October 2017. It is unclear when clarification of the proposed regulations might be provided or when the proposed regulations will be finalized.

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 March 31, 2019:
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies(1)	$	48	$	—	$	—		$	48
Municipal bonds(2)	271		8		—			279
Other securities(3)	236		3		(1		)	238
Total debt securities	555		11		(1		)	565
Equity securities	166		299		(6		)	459
Cash and cash equivalents	13		—		—			13
Total	$	734	$	310	$	(7	)	$	1,037
At December 31, 2018:
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies	$	52	$	1	$	—		$	53
Municipal bonds	266		4		(1		)	269
Other securities	238		1		(5		)	234
Total debt securities	556		6		(6		)	556
Equity securities	168		253		(10		)	411
Cash and cash equivalents	7		—		—			7
Total	$	731	$	259	$	(16	)	$	974

⁽¹⁾  Maturity dates are 2019-2049.

⁽²⁾  Maturity dates are 2019-2056.

⁽³⁾  Maturity dates are 2019-2064.

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 March 31,
	2019			2018
Proceeds from sales	$	225		$	210
Gross realized gains	5			4
Gross realized losses	(2		)	(3		)

Net unrealized gains and losses, as well as realized gains and losses that are reinvested in the NDT, are included in noncurrent Regulatory Liabilities on Sempra Energy’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

SDG&E’s ARO related to decommissioning costs for the SONGS units was $620 million at March 31, 2019. 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 2018 dollars is approximately $810 million.

U.S. DEPARTMENT OF ENERGY NUCLEAR FUEL DISPOSAL

Spent nuclear fuel from SONGS is currently stored on-site in an ISFSI licensed by the Nuclear Regulatory Commission or temporarily in spent fuel pools. In October 2015, the California Coastal Commission approved Edison’s application for the proposed expansion of the ISFSI at SONGS. The ISFSI expansion began construction in 2016 and the transfer of the spent nuclear fuel from Units 2 and 3 to the ISFSI began in 2018. Edison suspended this transfer on August 3, 2018 due to an incident that occurred when a spent fuel canister was getting loaded into the ISFSI. The incident did not result in any harm to the public or workers and the canister was subsequently safely loaded into the IFSFI. Edison has not resumed spent fuel transfer operations at SONGS, but has publicly stated that it will resume operations once it is satisfied all corrective actions are in place and proven effective and the NRC has completed its on-site inspection activities. The ISFSI will operate until 2049, when it is assumed that the DOE will have taken custody of all the SONGS spent fuel. The ISFSI would then be decommissioned, and the site restored to its original environmental state. Until then, SONGS owners are responsible for interim storage of spent nuclear fuel at SONGS.

The Nuclear Waste Policy Act of 1982 made the DOE responsible for accepting, transporting, and disposing of spent nuclear fuel. However, it is uncertain when the DOE will begin accepting spent nuclear fuel from SONGS. This delay will lead to increased costs for spent fuel storage. SDG&E will continue to support Edison in its pursuit of claims on behalf of the SONGS co-owners against the DOE for its failure to timely accept the spent nuclear fuel. However, it is unclear whether Edison will enter into a new settlement with the DOE or pursue litigation claims for spent fuel management costs incurred on or after January 1, 2017.

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 owners, including SDG&E, also maintain nuclear property damage insurance at $1.5 billion, with a $500 million property damage sublimit on the ISFSI, which exceeds the minimum federal requirements of $1.06 billion. This insurance coverage is provided through NEIL. The NEIL policies have specific exclusions and limitations that can result in reduced or eliminated 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 $10.4 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

3 Months Ended

Mar. 31, 2019

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 applicable insurance coverage and could materially adversely affect our business, cash flows, results of operations, financial condition and prospects. Unless otherwise indicated, we are unable to estimate reasonably possible losses in excess of any amounts accrued.

At March 31, 2019, loss contingency accruals for legal matters, including associated legal fees, that are probable and estimable were $104 million for Sempra Energy Consolidated, including $54 million for SoCalGas. Amounts for Sempra Energy and SoCalGas include $53 million for matters related to the Aliso Canyon natural gas storage facility gas leak, which we discuss below.

SDG&E

2007 Wildfire Litigation and Net Cost Recovery Status

SDG&E has resolved all civil litigation associated with three wildfires that occurred in October 2007.

As a result of a CPUC decision denying SDG&E’s request to recover wildfire costs, SDG&E wrote off the wildfire regulatory asset, resulting in a charge of $351 million ($208 million after-tax) in the third quarter of 2017. SDG&E continues to vigorously pursue recovery of these costs, which were incurred through settling claims brought under the doctrine of inverse condemnation. SDG&E applied to the CPUC for rehearing of its decision on January 2, 2018. On July 12, 2018, the CPUC adopted a decision denying the rehearing requests filed by SDG&E and other parties. On August 3, 2018, SDG&E filed an appeal with the California Court of Appeal seeking to reverse the CPUC’s decision. The filing also asked the court to direct the CPUC to award SDG&E recovery for payments made to settle inverse condemnation claims and limit any reasonableness review to the amounts of those payments. On November 13, 2018, the California Court of Appeal denied SDG&E’s petition. On November 26, 2018, SDG&E filed an appeal with the California Supreme Court seeking to reverse the decisions of the CPUC and the California Court of Appeal. In January 2019, the California Supreme Court denied SDG&E’s petition. On April 30, 2019, SDG&E filed an appeal with the U.S. Supreme Court seeking to reverse the CPUC’s decision.

SoCalGas

Aliso Canyon Natural Gas Storage Facility Gas Leak

On October 23, 2015, SoCalGas discovered a leak at one of its injection-and-withdrawal wells, SS25, at its Aliso Canyon natural gas storage facility, located in the northern part of the San Fernando Valley in Los Angeles County. The Aliso Canyon natural gas storage facility has been operated by SoCalGas since 1972. SS25 is one of more than 100 injection-and-withdrawal wells at the storage facility. SoCalGas worked closely with several of the world’s leading experts to stop the Leak, and on February 18, 2016, DOGGR confirmed that the well was permanently sealed. SoCalGas calculated that approximately 4.62 Bcf of natural gas was released from the Aliso Canyon natural gas storage facility as a result of the Leak.

As discussed in “Cost Estimates and Accounting Impact” below, SoCalGas incurred significant costs for temporary relocation, to control the well and to stop the Leak, as well as to purchase natural gas to replace that lost through the Leak. As discussed in “Local Community Mitigation Efforts” below, during the Leak and in the months following the sealing of the well, SoCalGas provided support to nearby residents who wished to temporarily relocate as a result of the Leak. These programs ended in July 2016.

SoCalGas has additionally incurred significant costs 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 an independent

third party to conduct a root cause analysis to investigate the technical cause of the Leak; to respond to various government and agency investigations regarding the Leak, and to comply with increased regulation imposed as a result of the Leak. As further described below in “Civil and Criminal Litigation,” “Regulatory Proceedings” and “Governmental Investigations and Orders and Additional Regulation,” these activities are ongoing and SoCalGas anticipates that it will incur additional such costs, which may also be significant.

Local Community Mitigation Efforts. Pursuant to a directive by the DPH and orders by the LA Superior Court, SoCalGas provided temporary relocation support to residents in the nearby community who requested it. Following the permanent sealing of the well, the DPH conducted testing in certain homes in the Porter Ranch community and concluded that indoor conditions did not present a long-term health risk and that it was safe for those residents to return home.

In May 2016, the DPH also issued a directive that SoCalGas additionally professionally clean the homes of all residents located within the Porter Ranch Neighborhood Council boundary, or who participated in the relocation program, or who are located within a five-mile radius of the Aliso Canyon natural gas storage facility and experienced symptoms from the Leak (the Directive). SoCalGas disputed the Directive as invalid and unenforceable, and filed a petition for writ of mandate to set aside the Directive. The Directive was settled and SoCalGas’ petition was dismissed pursuant to the Government Plaintiffs Settlement that we discuss below in “Civil and Criminal Litigation.”

The costs incurred to remediate and stop the Leak and to mitigate local community impacts have been significant and may increase, and we may be subject to potentially significant damages, restitution, and civil, administrative and criminal fines, penalties and other costs. If any of these costs are not covered by insurance (including any costs in excess of applicable policy limits), if there are significant 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 could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

Civil and Criminal Litigation. As of May 2, 2019, 394 lawsuits, including approximately 48,500 plaintiffs, are pending against SoCalGas, some of which have also named Sempra Energy. All these cases, other than a matter brought by the Los Angeles County District Attorney and the federal securities class action discussed below, are coordinated before a single court in the LA Superior Court for pretrial management (the Coordination Proceeding).

Pursuant to the Coordination Proceeding, in November 2017, the individuals and business entities asserting tort and Proposition 65 claims filed a Third Amended Consolidated Master Case Complaint for Individual Actions, through which their separate lawsuits will be 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, with certain causes also naming Sempra Energy. 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 (including penalties associated with Proposition 65 claims alleging violation of requirements for warning about certain chemical exposures), and attorneys’ fees.

In January 2017, pursuant to the Coordination Proceeding, two consolidated class action complaints were filed against SoCalGas and Sempra Energy, 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). Both complaints assert claims for strict liability for ultra-hazardous activities, negligence and violation of the California Unfair Competition Law. The Property Class Action also asserts claims for negligence per se, trespass, permanent and continuing public and private nuisance, and inverse condemnation. The Business Class Action also asserts a claim for negligent interference with prospective economic advantage. Both complaints seek compensatory, statutory and punitive damages, injunctive relief and attorneys’ fees. In December 2017, the California Court of Appeal, Second Appellate District ruled that the purely economic damages alleged in the Business Class Action are not recoverable under the law. In February 2018, the California Supreme Court granted a petition filed by the plaintiffs to review that ruling, and oral argument on the appeal was heard in March 2019.

Complaints by property developers were filed in 2017 and 2018 against SoCalGas and Sempra Energy 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. These claims are also joined in the Coordination Proceeding.

In addition to the lawsuits described above, in October 2018 and January 2019, complaints were filed on behalf of 51 plaintiffs who are firefighters stationed near the Aliso Canyon natural gas storage facility and allege they were injured by exposure to chemicals released during the Leak. The complaints against SoCalGas and Sempra Energy 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 attorney’s fees. These claims are also joined in the Coordination Proceeding.

In addition, a federal securities class action alleging violation of the federal securities laws has been filed against Sempra Energy and certain of its officers and certain of its directors in the SDCA. In March 2018, the court dismissed the action with prejudice, and in December 2018 the court denied the plaintiffs’ request for reconsideration of that order. The plaintiffs have filed a notice of appeal of the dismissal.

Five shareholder derivative actions are also pending in the Coordination Proceeding alleging breach of fiduciary duties against certain officers and certain directors of Sempra Energy and/or SoCalGas, four of which were joined in a Consolidated Shareholder Derivative Complaint in August 2017.

Three actions by public entities were filed in the Coordination Proceeding, including complaints by the County of Los Angeles, on behalf of itself and the people of the State of California, the California Attorney General, acting in an independent capacity and on behalf of the people of the State of California and the CARB, and the Los Angeles City Attorney alleging public nuisance, unfair competition, and violations of California Health and Safety Code provisions regarding discharge of contaminants, among other things, which sought injunctive relief, abatement, civil penalties and damages.

Additionally, the County of Los Angeles filed a petition against DOGGR and its State Oil and Gas Supervisor and the CPUC and its Executive Director, as to which SoCalGas is the real party in interest, alleging that they failed to comply with the provisions of SB 380 in authorizing the resumption of injections of natural gas at the Aliso Canyon natural gas storage facility, and seeking a writ of mandate requiring DOGGR and the State Oil and Gas Supervisor to comply with SB 380 and CEQA, as well as declaratory and injunctive relief against any authorization to inject natural gas and attorneys’ fees.

In August 2018, SoCalGas entered into a settlement agreement with the Los Angeles City Attorney’s Office, the County of Los Angeles, the California Office of the Attorney General and CARB (collectively, the Government Plaintiffs) to settle the three public entity actions and the Directive for payments and funding for environmental projects totaling $120 million, including $21 million in civil penalties (the Government Plaintiffs Settlement). Under the settlement agreement, SoCalGas also agreed to continue its fence-line methane monitoring program, establish a safety committee and hire an independent ombudsman to monitor and report on the safety at the facility. This settlement also fully resolves SoCalGas’ commitment to mitigate the actual natural gas released during the Leak and fulfills the requirements of the Governor’s Order, described below, for SoCalGas to pay for a mitigation program developed by CARB. The Government Plaintiffs Settlement was approved by the LA Superior Court in February 2019.

Separately, in February 2016, the Los Angeles County District Attorney’s Office filed a misdemeanor criminal complaint against SoCalGas seeking penalties and other remedies for alleged failure to provide timely notice of the Leak pursuant to California Health and Safety Code section 25510(a), Los Angeles County Code section 12.56.030, and Title 19 California Code of Regulations section 2703(a), and for allegedly violating California Health and Safety Code section 41700 prohibiting discharge of air contaminants that cause annoyance to the public. Pursuant to a settlement agreement with the Los Angeles County District Attorney’s Office, SoCalGas agreed to plead no contest to the notice charge under Health and Safety Code section 25510(a) and agreed to pay the maximum fine of $75,000, penalty assessments of approximately $233,500, and operational commitments estimated to cost approximately $6 million, reimbursements and assessments in exchange for the Los Angeles County District Attorney’s Office moving to dismiss the remaining counts at sentencing and settling the complaint (the District Attorney Settlement). In November 2016, SoCalGas completed the commitments and obligations under the District Attorney Settlement, and on November 29, 2016, the LA Superior Court approved the settlement and entered judgment on the notice charge. Certain individuals who object to the settlement have filed an appeal of the judgment, contending they should be granted restitution.

The costs of defending against these civil and criminal lawsuits, and any damages, restitution, and civil, administrative and criminal fines, penalties and other costs, if awarded or imposed, as well as the costs of mitigating the actual natural gas released, could be significant. If any of these costs are not covered by insurance (including any costs in excess of applicable policy limits), if there are significant 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 could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

Regulatory Proceedings. In February 2017, the CPUC opened a proceeding pursuant to SB 380 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. The CPUC indicated it intends to conduct the proceeding in two phases, with Phase 1 undertaking a comprehensive effort to develop the appropriate analyses and scenarios to evaluate the impact of reducing or eliminating the use

of the Aliso Canyon natural gas storage facility and Phase 2 using those analyses and scenarios to evaluate the impacts of reducing or eliminating the use of the Aliso Canyon natural gas storage facility.

The order establishing the scope of the proceeding expressly excludes issues with respect to air quality, public health, causation, culpability or cost responsibility regarding the Leak. In January 2019, the CPUC concluded Phase 1 of the proceeding by establishing 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 will evaluate 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. The CPUC has indicated that it expects to issue its report in 2020.

Governmental Investigations and Orders and Additional Regulation. Various governmental agencies, including DOE, DOGGR, DPH, SCAQMD, CARB, Los Angeles Regional Water Quality Control Board, California Division of Occupational Safety and Health, CPUC, PHMSA, EPA, Los Angeles County District Attorney’s Office and California Attorney General’s Office, have investigated or are investigating this incident. In January 2016, DOGGR and the CPUC selected Blade Energy Partners to conduct, under their supervision, an independent analysis of the technical root cause of the Leak, to be funded by SoCalGas. The independent root cause analysis is ongoing, and its timing is under the control of Blade Energy Partners, DOGGR and the CPUC. We expect the report will be issued in the second quarter of 2019.

In January 2016, the Governor of the State of California proclaimed a state of emergency in Los Angeles County due to the Leak. The proclamation ordered various actions with respect to the Leak, including: (1) applicable agencies must convene an independent panel of scientific and medical experts to review public health concerns stemming from the Leak and evaluate whether additional measures are needed to protect public health; (2) the CPUC must ensure that SoCalGas covers costs related to the Leak and its response while protecting ratepayers; (3) CARB must develop a program, to be funded by SoCalGas, to fully mitigate the Leak’s emissions of methane; and (4) DOGGR, CPUC, CARB and the CEC must submit to the Governor’s Office a report that assesses the long-term viability of natural gas storage facilities in California.

In March 2016, CARB issued its “Aliso Canyon Methane Leak Climate Impacts Mitigation Program” recommending a program to fully mitigate the emissions from the Leak. In October 2016, CARB issued a report concluding that SoCalGas should mitigate 109,000 metric tons of methane to fully mitigate the GHG impacts of the Leak. The Government Plaintiffs Settlement described above satisfies the mitigation requirement of the Governor’s emergency proclamation.

Cost Estimates and Accounting Impact. At March 31, 2019, SoCalGas estimates its costs related to the Leak are $1,071 million (the cost estimate), which includes $1,043 million of costs recovered or probable of recovery from insurance. Approximately 53 percent of the cost estimate is for the temporary relocation program (including cleaning costs and certain labor costs). The remaining portion of the cost estimate includes costs incurred to defend litigation, the costs of the government-ordered response to the Leak including the costs for an independent third party to conduct a root cause analysis, efforts to control the well, to mitigate the actual natural gas released, the cost of replacing the lost gas, and other costs, as well as the estimated costs to settle certain actions. SoCalGas adjusts the cost estimate as additional information becomes available. A substantial portion of the cost estimate has been paid, and $60 million is accrued as Reserve for Aliso Canyon Costs as of March 31, 2019 on SoCalGas’ and Sempra Energy’s Condensed Consolidated Balance Sheets.

As of March 31, 2019, we recorded the expected recovery of the cost estimate related to the Leak of $477 million as Insurance Receivable for Aliso Canyon Costs on SoCalGas’ and Sempra Energy’s Condensed Consolidated Balance Sheets. This amount is net of insurance retentions and $566 million of insurance proceeds we received through March 31, 2019. The Insurance Receivable for Aliso Canyon Costs and insurance proceeds received to date relate to portions of the cost estimate described above, including temporary relocation and associated processing costs, control-of-well expenses, costs of the government-ordered response for an independent third party to conduct a root cause analysis, the costs to settle certain claims as described above, the estimated costs to perform obligations pursuant to settlement of some of those claims, legal costs and lost gas. If we were to conclude that this receivable or a portion of it is no longer probable of recovery from insurers, some or all of this receivable would be charged against earnings, which could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

As described in “Civil and Criminal Litigation” above, the actions seek compensatory, statutory and punitive damages, restitution, and civil, administrative and criminal fines, penalties and other costs, which, except for the amounts paid or estimated to settle certain actions as described above, are not included in the cost estimate as it is not possible at this time to predict the outcome of these actions or reasonably estimate the amount of damages, restitution or civil, administrative or criminal fines, penalties or other costs that may be imposed. The recorded amounts above also do not include future legal costs necessary to defend litigation, and other potential costs that we currently do not anticipate incurring or that we cannot reasonably estimate. Furthermore, the cost estimate does not include certain other costs incurred by Sempra Energy associated with defending against shareholder derivative lawsuits.

Insurance. Excluding directors’ and officers’ liability insurance, we have at least four kinds of insurance policies that together we estimate provide between $1.2 billion to $1.4 billion in insurance coverage, depending on the nature of the claims. We cannot predict all of the potential categories of costs or the total amount of costs that we may incur as a result of the Leak. Subject to various policy limits, exclusions and conditions, based on what we know as of the filing date of this report, we believe that our insurance policies collectively should cover the following categories of costs: costs incurred for temporary relocation and associated processing costs (including cleaning costs and certain labor costs), costs to address the Leak and stop or reduce emissions, costs of the government-ordered response to the Leak including the costs for an independent third party to conduct a root cause analysis, the value of lost gas, costs incurred to mitigate the actual natural gas released, costs associated with litigation and claims by nearby residents and businesses, any costs to clean additional homes pursuant to the Directive, and, in some circumstances depending on their nature and manner of assessment, fines and penalties. We have been communicating with our insurance carriers and, as discussed above, we have received insurance payments for portions of the costs described above, including temporary relocation and associated processing costs, control-of-well expenses, legal costs and lost gas. We intend to pursue the full extent of our insurance coverage for the costs we have incurred or may incur. There can be no assurance that we will be successful in obtaining additional insurance recovery for these costs, and to the extent we are not successful in obtaining coverage or these costs exceed the amount of our coverage, such costs could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

At March 31, 2019, SoCalGas’ estimate of costs related to the Leak of $1,071 million include $1,043 million of costs recovered or probable of recovery from insurance. This estimate may rise significantly as more information becomes available. Costs not included in the $1,071 million cost estimate could be material. If any costs are not covered by insurance (including any costs in excess of applicable policy limits), if there are significant 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 could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

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 heating needs in the winter. The Aliso Canyon natural gas storage facility, with a capacity of 86 Bcf (representing 63 percent of SoCalGas’ natural gas storage capacity), is the largest SoCalGas storage facility and an important element of SoCalGas’ delivery system. As a result of the Leak, SoCalGas suspended injection of natural gas into the Aliso Canyon natural gas storage facility beginning in October 2015, and following a comprehensive safety review and authorization by DOGGR and the CPUC’s Executive Director, resumed limited injection operations in July 2017.

During the suspension period, SoCalGas advised the California ISO, CEC, CPUC and PHMSA of its concerns that the inability to inject natural gas into the Aliso Canyon natural gas storage facility posed a risk to energy reliability in Southern California. Following the resumption of injection operations, 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 to help ensure safety and reliability for the region and just and reasonable rates in California, the most recent of which, issued in July 2018, directed SoCalGas to maintain up to 34 Bcf of working gas. Limited withdrawals of natural gas from the facility were made in 2018 and 2019 to augment natural gas supplies during critical demand periods.

If the Aliso Canyon natural gas storage facility were to be permanently closed, or if future cash flows were otherwise insufficient to recover its carrying value, it could result in an impairment of the facility and significantly higher than expected operating costs and/or additional capital expenditures, and natural gas reliability and electric generation could be jeopardized. At March 31, 2019, the Aliso Canyon natural gas storage facility had a net book value of $741 million. Any significant impairment of this asset could have a material adverse effect on SoCalGas’ and Sempra Energy’s results of operations for the period in which it is recorded. Higher operating costs and additional capital expenditures incurred by SoCalGas may not be recoverable in customer rates, and could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

Sempra Mexico

Property Disputes and Permit Challenges

Energía Costa Azul. IEnova has been engaged in a long-running land dispute relating to property adjacent to its ECA LNG terminal near Ensenada, Mexico. A claimant to the adjacent property filed complaints in the federal Agrarian Court challenging the refusal of SEDATU in 2006 to issue a title to him for the disputed property. In November 2013, the federal Agrarian Court ordered that SEDATU issue the requested title and cause it to be registered. Both SEDATU and IEnova challenged the ruling, due to lack of notification of the underlying process. Both challenges are pending to be resolved by a Federal Court in Mexico. IEnova expects additional proceedings regarding the claims.

Several administrative challenges are pending in Mexico before the Mexican environmental protection agency and the Federal Tax and Administrative Courts seeking revocation of the environmental impact authorization issued to ECA 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.

Additionally, in August 2018, a claimant filed a challenge in the federal district court in Ensenada, Baja California in relation to the environmental and social impact permits issued to ECA in September 2017 and December 2017, respectively, to allow natural gas liquefaction activities at the ECA LNG terminal. The court issued a provisional injunction on September 28, 2018 and maintained that provisional injunction at an April 11, 2019 hearing. The provisional injunction has uncertain application and requires clarification by the court, which is being pursued through additional proceedings that are pending before the court. In December 2018, the relevant Mexican regulators approved modifications to the environmental permit that facilitate the development of the proposed natural gas liquefaction facility at the ECA LNG terminal in two phases.

Cases involving two parcels of real property have been filed against ECA. In one case, filed in the federal Agrarian Court in 2006, the plaintiffs seek to annul the recorded property title for a parcel on which the ECA LNG terminal is situated and to obtain possession of a different parcel that allegedly sits in the same place. Another civil complaint filed in the state court was served in April 2012 seeking to invalidate the contract by which ECA purchased another of the terminal parcels, on the grounds the purchase price was unfair; the plaintiff filed a second complaint in 2013 in the federal Agrarian Court seeking an order that SEDATU issue title to her. In January 2016, the federal Agrarian Court ruled against the plaintiff, and the plaintiff appealed the ruling. In May 2018, the state court dismissed the civil complaint, and the plaintiff has appealed. IEnova expects further proceedings on these two matters.

An unfavorable final decision on these property disputes or permit challenges could materially and adversely affect our planned natural gas liquefaction projects currently in development at ECA.

Guaymas-El Oro Segment of the Sonora Pipeline. 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, an appellate court ruled that the scope of the 2016 suspension order encompassed the wider Yaqui territory. The legal challenge remains pending. IEnova has subsequently reported damage to the Guaymas-El Oro segment of the Sonora pipeline in the Yaqui territory that has made that section inoperable since August 23, 2017 and, as a result, declared a force majeure event. IEnova will continue to exercise its rights under the contract, which includes seeking continued force majeure payments for the two-year period such force majeure payments are required to be made, which ends on August 22, 2019, and just consideration following the expiration of the two-year period in which force majeure payments are made. The Sasabe-Puerto Libertad-Guaymas segment of the Sonora pipeline remains in full operation.

Other Litigation

Sempra Energy holds an NCI in RBS Sempra Commodities, a limited liability partnership in the process of being liquidated. NatWest Markets plc, formerly RBS, 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 has since been sold to JP Morgan 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. After paying the assessment, RBS filed a Notice of Appeal of the assessment with the First-Tier Tribunal. Trial on the matter has not been scheduled.

During 2015, liquidators filed a claim in the High Court of Justice against RBS and Mercuria Energy Europe Trading Limited (the Defendants) on behalf of ten 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, at the close of which

the Liquidating Companies asserted that the Defendants were liable to the Liquidating Companies in the amount of £71.5 million (approximately $93 million in U.S. dollars at March 31, 2019) for dishonest assistance and, to the extent that claim is unsuccessful, to the liquidators in the same amount under the U.K. Insolvency Act of 1986. If the High Court of Justice finds the Defendants liable, it will determine the amount. JP Morgan has notified us that Mercuria Energy Group, Ltd. has sought indemnity for the claim, and JP Morgan has in turn sought indemnity from Sempra Energy and RBS.

While the ultimate outcome remains uncertain, we continue to evaluate the likelihood of recovery of our investment. Accordingly, in the third quarter of 2018, we fully impaired our remaining $65 million equity method investment in RBS Sempra Commodities.

Certain EFH subsidiaries that we acquired as part of the Merger are defendants in personal injury lawsuits brought in state courts throughout the U.S. As of May 2, 2019, 114 such lawsuits are pending and 1,685 such lawsuits have been filed but not 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. We anticipate additional lawsuits will be filed. None of these claims or lawsuits were discharged in the EFH bankruptcy proceeding.

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

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 combine lease components and nonlease components for all existing classes of underlying assets as a single lease component, 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, if the timing and pattern of transfer of the lease components and nonlease components are the same, and the lease component would be classified as an operating lease if accounted for separately, we combine the lease components and nonlease components.

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.

Some of our leases include options to extend the lease terms for up to 25 years, while others include options to terminate the leases within one year. Our lease liabilities and ROU assets are based on lease terms that may include such options to extend or terminate the lease when it is reasonably certain that we will exercise that option.

Certain of our contracts are short-term leases, which have a lease term of 12 months or less at lease commencement. We do not recognize a lease liability or ROU asset arising from short-term leases for all existing classes of underlying assets. In such cases, we recognize short-term lease costs on a straight-line basis over the lease term. Our short-term lease costs for the period reasonably reflect our short-term lease commitments.

Certain of our leases contain escalation clauses requiring annual increases in rent ranging from 1 percent to 5 percent or based on the Consumer Price Index. The rentals payable under these leases may increase by a fixed amount each year or by a percentage of a base year. Variable lease payments that are based on an index or rate are included in the initial measurement of our lease liability and ROU asset based on the index or rate at lease commencement and are not remeasured because of changes to the index or rate. Rather, changes to the index or rate are treated as variable lease payments and recognized in the period in which the obligation for those payments is incurred.

Similarly, PPAs for the purchase of renewable energy at SDG&E require lease payments based on a stated rate per MWh produced by the facilities, and we are required to purchase substantially all the output from the facilities. SDG&E is required to pay additional amounts for capacity charges and actual purchases of energy that exceed the minimum energy commitments. Under these contracts, we do not recognize a lease liability or ROU asset for leases for which there are no fixed lease payments. Rather, these variable lease payments are recognized separately as variable lease costs.

As of the lease commencement date, we recognize a lease liability for our obligation to make future lease payments, which we initially measure at present value using our incremental borrowing rate at the date of lease commencement, unless the rate implicit in the lease is readily determinable. We determine our incremental borrowing rate based on the rate of interest that we would have to pay to borrow, on a collateralized basis over a similar term, an amount equal to the lease payments in a similar economic environment. We also record an ROU asset for our right to use the underlying asset, which is initially equal to the lease liability and adjusted for lease payments made at or before lease commencement, lease incentives, and any initial direct costs. Like other long-lived assets, we test ROU assets for recoverability whenever events or changes in circumstances have occurred that may affect the recoverability or the estimated useful lives of the ROU assets.

For our operating leases, our non-regulated entities recognize a single lease cost on a straight-line basis over the lease term in operating expenses. The California Utilities recognize this single lease cost on a basis that is consistent with the recovery of such costs in accordance with U.S. GAAP governing rate-regulated operations.

For our finance leases, the interest expense on the lease liability and amortization of the ROU asset are accounted for separately. Our non-regulated entities use the effective interest rate method to account for the imputed interest on the lease liability and amortize the ROU asset on a straight-line basis over the lease term. The California Utilities recognize amortization of the ROU asset on a basis that is consistent with the recovery of such costs in accordance with U.S. GAAP governing rate-regulated operations.

Our leases do not contain any material residual value guarantees, restrictions or covenants.

Classification of ROU assets and lease liabilities and the weighted-average remaining lease term and discount rate associated with operating and finance leases are summarized in the table below.

LESSEE INFORMATION ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	March 31, 2019
	Sempra Energy Consolidated			SDG&E			SoCalGas
Right-of-use assets:
Operating leases:
Right-of-use assets	$	612		$	135		$	110
Finance leases:
Property, plant and equipment	1,322			1,315			7
Accumulated depreciation	(45		)	(43		)	(2		)
Property, plant and equipment, net	1,277			1,272			5
Total right-of-use assets	$	1,889		$	1,407		$	115
Lease liabilities:
Operating leases:
Other current liabilities	$	52		$	24		$	22
Deferred credits and other	455			110			88
	507			134			110
Finance leases:
Current portion of long-term debt and finance leases	21			18			3
Long-term debt and finance leases	1,256			1,254			2
	1,277			1,272			5
Total lease liabilities	$	1,784		$	1,406		$	115
Weighted-average remaining lease term (in years):
Operating leases	14			7			6
Finance leases	20			20			3
Weighted-average discount rate:
Operating leases	5.87		%	3.69		%	3.76		%
Finance leases	14.91		%	14.92		%	3.94		%

The components of lease costs were as follows:

LESSEE INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS(1)
(Dollars in millions)
	Three months ended March 31, 2019
	Sempra Energy Consolidated		SDG&E		SoCalGas
Operating lease costs	$	24	$	8	$	7
Finance lease costs:
Amortization of ROU assets	5		4		1
Interest on lease liabilities	47		47		—
Total finance lease costs	52		51		1
Short-term lease costs(2)	1		—		—
Variable lease costs(2)	92		90		2
Total lease costs	$	169	$	149	$	10

⁽¹⁾  Includes costs capitalized in PP&E.

⁽²⁾  Short-term leases with variable lease costs are recorded and presented as variable lease costs.

Cash paid for amounts included in the measurement of lease liabilities was as follows:

LESSEE INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in millions)
	Three months ended March 31, 2019
	Sempra Energy Consolidated		SDG&E		SoCalGas
Operating activities:
Cash paid for operating leases	$	39	$	8	$	7
Cash paid for finance leases	43		43		—
Financing activities:
Cash paid for finance leases	5		4		1
Increase in operating lease obligations for right-of-use assets	552		142		117
Increase in finance lease obligations for investment in PP&E	7		4		3

The table below presents the maturity analysis of our lease liabilities and reconciliation to the present value of lease liabilities:

LESSEE MATURITY ANALYSIS OF LIABILITIES
(Dollars in millions)
	March 31, 2019
	Sempra Energy Consolidated						SDG&E						SoCalGas
	Operating leases			Finance leases			Operating leases			Finance leases			Operating leases			Finance leases
2019 (excluding first three months of 2019)	$	60		$	146		$	24		$	143		$	20		$	3
2020	69			190			25			189			22			1
2021	65			188			24			188			20			—
2022	59			188			21			188			17			—
2023	50			188			17			188			13			—
Thereafter	479			2,806			42			2,805			31			1
Total undiscounted lease payments	782			3,706			153			3,701			123			5
Less: imputed interest	(275		)	(2,429		)	(19		)	(2,429		)	(13		)	—
Total lease liabilities	507			1,277			134			1,272			110			5
Less: current lease liabilities	(52		)	(21		)	(24		)	(18		)	(22		)	(3		)
Long-term lease liabilities	$	455		$	1,256		$	110		$	1,254		$	88		$	2

Leases that Have Not Yet Commenced

SDG&E has PPAs for three battery storage facilities that are currently under construction. When construction is complete and delivery of contracted power commences, which is scheduled to occur in 2019 through 2022, we will account for the PPAs as finance leases. The future minimum lease payments are expected to be $1 million per year in 2020 through 2023 and $18 million thereafter. These PPA’s expire at various dates from 2031 through 2039.

SDG&E and SoCalGas have lease agreements for future acquisitions of fleet vehicles with an aggregate maximum lease limit of $194 million. SDG&E and SoCalGas have utilized $52 million and $75 million, respectively, as of March 31, 2019.

Lease Disclosures Under Previous U.S. GAAP

The table below presents the future minimum lease payments under previous U.S. GAAP:

FUTURE MINIMUM LEASE PAYMENTS
(Dollars in millions)
	December 31, 2018
	Sempra Energy Consolidated							SDG&E					SoCalGas
	Build-to-suit lease		Operating leases		Capital leases			Operating leases		Capital leases			Operating leases		Capital leases
2019	$	10	$	77	$	215		$	23	$	212		$	26	$	3
2020	11		55		210			22		210			22		—
2021	11		53		211			22		211			21		—
2022	11		50		211			21		211			20		—
2023	11		42		211			17		211			16		—
Thereafter	217		253		3,196			48		3,196			28		—
Total undiscounted lease payments	$	271	$	530	4,254			$	153	4,251			$	133	3
Less: estimated executory costs					(480		)			(480		)			—
Less: imputed interest					(2,483		)			(2,483		)			—
Total future minimum lease payments					$	1,291				$	1,288				$	3

Lessor Accounting

Sempra Mexico is a lessor for certain of its natural gas and ethane pipelines, compressor stations and LPG storage facilities, and land and office space. These operating leases expire at various dates from 2026 through 2039.

Sempra Mexico expects to continue to derive value from the underlying assets associated with its pipelines following the end of their respective lease terms based on the expected remaining useful life, expected market conditions and our plans to re-market and re-contract the underlying assets.

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 from one period to the next.

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

LESSOR INFORMATION – SEMPRA ENERGY
(Dollars in millions)
	March 31, 2019
Assets subject to operating leases:
Assets held for sale	$	148
Property, plant and equipment(1)	$	1,026
Accumulated depreciation	(151		)
Property, plant and equipment, net	$	875
Maturity analysis of operating lease payments:
2019 (excluding first three months of 2019)	$	151
2020	200
2021	200
2022	200
2023	200
Thereafter	2,619
Total undiscounted cash flows	$	3,570

⁽¹⁾   Included in Machinery and Equipment — Pipelines and Storage within the major functional categories of PP&E.

LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA ENERGY
(Dollars in millions)
	Three months ended March 31,
	2019		2018
Minimum lease payments	$	50	$	49
Variable lease payments	4		13
Total revenues from operating leases	$	54	$	62
Depreciation expense	$	9	$	17

CONTRACTUAL COMMITMENTS

We discuss below significant changes in the first three months of 2019 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 terminal. The commitment amount is calculated using a predetermined formula based on estimated forward prices of the index applicable from 2019 to 2029. At March 31, 2019, we expect the commitment amount to decrease by $96 million in 2019 and increase by $19 million in 2020, $8 million in 2021, $3 million in 2022, $2 million in 2023 and $52 million thereafter (through contract termination in 2029) compared to December 31, 2018, reflecting changes in estimated forward prices since December 31, 2018 and actual transactions for the first three months of 2019. 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. 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. 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.CONCENTRATION OF CREDIT RISK

We maintain credit policies and systems designed to manage our overall credit risk. These policies include an evaluation of potential counterparties’ financial condition and an assignment of credit limits. These credit limits are established based on risk and return considerations under terms customarily available in the industry. We grant credit to utility customers and counterparties, substantially all of whom are located in our service territory, which covers most of Southern California and a portion of central California for SoCalGas, and all of San Diego County and an adjacent portion of Orange County for SDG&E. Sempra Mexico’s Ecogas also grants credit to its utility customers and counterparties in Mexico.

Projects and businesses owned or partially owned by Sempra Energy place significant reliance on the ability of their suppliers, customers and partners to perform on long-term agreements and on our ability to enforce contract terms in the event of nonperformance. We consider many factors, including the negotiation of supplier and customer agreements, when we evaluate and approve development projects and investment opportunities.

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SEGMENT INFORMATION

3 Months Ended

Mar. 31, 2019

Segment Reporting [Abstract]

Segment Information

SEGMENT INFORMATION

At March 31, 2019, we had six 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 Utility holds our investment in Oncor Holdings, which owns an 80.25-percent interest in Oncor, a regulated electric transmission and distribution utility serving customers in the north-central, eastern and western parts of Texas.

▪ 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 Renewables develops, owns and operates, or holds interests in, wind power generation facilities serving wholesale electricity markets in the U.S. In December 2018, Sempra Renewables completed the sale of all its operating solar assets, solar and battery storage development projects and one wind generation facility. In April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments. Upon completion of this sale, remaining nominal business activities at Sempra Renewables were subsumed into Parent and other and the Sempra Renewables segment ceased to exist.

▪ Sempra LNG (previously known as Sempra LNG & Midstream) develops, owns and operates, or holds interests in, terminals for the import and export of LNG and sale of natural gas, natural gas pipelines and marketing operations, all within the U.S. and Mexico. In February 2019, we completed the sale of our natural gas storage assets at Mississippi Hub and Bay Gas.

As we discuss in Note 5, the financial information related to our businesses that constituted the Sempra South American Utilities segment has been reclassified to discontinued operations for all periods presented. The information in the tables below excludes amounts from discontinued operations unless otherwise noted.

We evaluate each segment’s performance based on its contribution to Sempra Energy’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. The California Utilities’ operations are based on rates set by the CPUC and 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 March 31,
	2019			2018
REVENUES
SDG&E	$	1,145		$	1,055
SoCalGas	1,361			1,126
Sempra Mexico	383			308
Sempra Renewables	7			25
Sempra LNG	141			104
Adjustments and eliminations	—			(1		)
Intersegment revenues(1)	(139		)	(81		)
Total	$	2,898		$	2,536
INTEREST EXPENSE
SDG&E	$	103		$	52
SoCalGas	34			27
Sempra Mexico	30			30
Sempra Renewables	3			5
Sempra LNG	4			8
All other	109			112
Intercompany eliminations	(23		)	(28		)
Total	$	260		$	206
INTEREST INCOME
SDG&E	$	1		$	1
Sempra Mexico	19			15
Sempra Renewables	10			2
Sempra LNG	14			13
All other	1			16
Intercompany eliminations	(24		)	(18		)
Total	$	21		$	29
DEPRECIATION AND AMORTIZATION
SDG&E	$	186		$	166
SoCalGas	147			135
Sempra Mexico	44			43
Sempra Renewables	—			13
Sempra LNG	2			11
All other	4			4
Total	$	383		$	372
INCOME TAX EXPENSE (BENEFIT)
SDG&E	$	5		$	56
SoCalGas	19			59
Sempra Mexico	72			155
Sempra Renewables	(10		)	(7		)
Sempra LNG	4			12
All other	(48		)	(33		)
Total	$	42		$	242
EQUITY EARNINGS (LOSSES)
Equity earnings before income tax:
Sempra Renewables	$	3		$	5
Sempra LNG	2			—
	5			5
Equity earnings (losses) net of income tax:
Sempra Texas Utility	94			15
Sempra Mexico	2			(41		)
	96			(26		)
Total	$	101		$	(21	)

SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended March 31,
	2019			2018
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E	$	176		$	170
SoCalGas	264			225
Sempra Texas Utility	94			15
Sempra Mexico	57			20
Sempra Renewables	13			21
Sempra LNG	5			(16		)
Discontinued operations	(51		)	21
All other	(117		)	(109		)
Total	$	441		$	347
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E	$	356		$	475
SoCalGas	324			403
Sempra Mexico	85			59
Sempra Renewables	—			31
Sempra LNG	18			6
All other	—			5
Total	$	783		$	979
	March 31, 2019			December 31, 2018
ASSETS
SDG&E	$	19,558		$	19,225
SoCalGas	15,904			15,389
Sempra Texas Utility	9,748			9,652
Sempra Mexico	9,382			9,165
Sempra Renewables	1,310			2,549
Sempra LNG	3,731			4,060
Discontinued operations	3,845			3,718
All other	1,135			1,070
Intersegment receivables	(2,995		)	(4,190		)
Total	$	61,618		$	60,638
EQUITY METHOD AND OTHER INVESTMENTS
Sempra Texas Utility	$	9,748		$	9,652
Sempra Mexico	737			747
Sempra Renewables	290			291
Sempra LNG	1,255			1,271
All other	8			11
Total	$	12,038		$	11,972

⁽¹⁾ 

Revenues for reportable segments include intersegment revenues of $1 million, $17 million, $28 million and $93 million for the three months ended March 31, 2019 and $1 million, $17 million, $29 million and $34 million for the three months ended March 31, 2018, for SDG&E, SoCalGas, Sempra Mexico and Sempra LNG, respectively.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA (Policies)

3 Months Ended

Mar. 31, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Principles of Consolidation

PRINCIPLES OF CONSOLIDATION

Sempra Energy

Sempra Energy’s Condensed Consolidated Financial Statements include the accounts of Sempra Energy, a California-based Fortune 500 energy-services holding company, and its consolidated subsidiaries and VIEs. Sempra Global is the holding company for most of our subsidiaries that are not subject to California or Texas utility regulation. Sempra Energy’s businesses are managed within six separate reportable segments, which we discuss in Note 12. In the first quarter of 2019, our Sempra LNG & Midstream segment was renamed “Sempra LNG.” This segment name change had no impact on our historical position, results of operations, cash flow or segment level results previously reported. 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 Condensed Consolidated Financial Statements include its accounts and the accounts of a VIE of which SDG&E is the primary beneficiary, as we discuss below in “Variable Interest Entities.” SDG&E’s common stock is wholly owned by Enova Corporation, which is a wholly owned subsidiary of Sempra Energy.

SoCalGas

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

In this report, we refer to SDG&E and SoCalGas collectively as the California Utilities.

Basis of Presentation

BASIS OF PRESENTATION

This is a combined report of Sempra Energy, SDG&E and SoCalGas. We provide separate information for SDG&E and SoCalGas as required. References in this report to “we,” “our” and “Sempra Energy Consolidated” are to Sempra Energy and its consolidated entities, unless otherwise indicated by the context. We have eliminated intercompany accounts and transactions within the consolidated financial statements of each reporting entity.

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 Energy and its subsidiaries and VIEs;

▪ the Condensed Consolidated Financial Statements and related Notes of SDG&E and its VIE; and

▪ the Condensed Financial Statements and related Notes of SoCalGas.

We have prepared the Condensed Consolidated Financial Statements in conformity with U.S. GAAP and in accordance with the interim-period-reporting requirements of Form 10-Q. Results of operations for interim periods are not necessarily indicative of results for the entire year. We evaluated events and transactions that occurred after March 31, 2019 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. These adjustments are only of a normal, recurring nature.

All December 31, 2018 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2018 Consolidated Financial Statements in the Annual Report, which for Sempra Energy has been retrospectively adjusted for discontinued operations, as we discuss below. 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 reporting purposes.

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

Discontinued Operations

Discontinued OperationsOn January 25, 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, as the planned sale represents a strategic shift that will have a major effect on our operations and financial results. Throughout this report, the financial information for all periods presented has been adjusted to reflect the presentation of these businesses as discontinued operations, which we discuss further in Note 5. Our discussions in the Notes below relate only to our continuing operations unless otherwise noted.

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 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 the forward sale of our common stock pursuant to the forward sale agreements that we entered into in 2018 is reflected in our diluted EPS calculation using the treasury stock method. We anticipate there will be a dilutive effect on our EPS when the average market price of shares of our common stock is above the applicable adjusted forward sale price, subject to increase or decrease based on the overnight bank funding rate, less a spread, and subject to decrease by

amounts related to expected dividends on shares of our common stock during the term of the forward sale agreements. Additionally, if we decide to physically settle or net share settle the forward sale agreements, delivery of our shares to the forward purchasers on any such physical settlement or net share settlement of the forward sale agreements would result in dilution to our EPS.

The potentially dilutive impact from mandatory convertible preferred stock that we issued in 2018 is calculated under the if-converted method.We discuss share-based compensation plans and related awards further in Note 10 of the Notes to Consolidated Financial Statements in the Annual Report.The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect.

Interim period effective tax rate policy

Sempra Energy, 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; and

▪ state income taxes.

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 2016-02, “Leases,” ASU 2018-01, “Land Easement Practical Expedient for Transition to Topic 842,” ASU 2018-10, “Codification Improvements to Topic 842, Leases,” ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” ASU 2018-20, “Narrow-Scope Improvements for Lessors” and ASU 2019-01, “Leases (Topic 842): Codification Improvements” (collectively referred to as the “lease standard”): In 2016, the FASB began issuing the first in a series of ASUs intended to increase transparency and comparability among organizations with leasing activities. The most significant provision of the lease standard is the requirement that lessees recognize operating lease ROU assets and lease liabilities on the balance sheet.

We adopted the lease standard on January 1, 2019, using the optional transition method to apply the new guidance prospectively as of January 1, 2019, rather than as of the earliest period presented. We elected the package of practical expedients that permits us to not reassess (a) whether a contract is or contains a lease, (b) lease classification or (c) determination of initial direct costs, which allows us to carry forward accounting conclusions under previous U.S. GAAP on contracts that commenced prior to adoption of the lease standard. We also elected the land easement practical expedient, which allows us to continue to account for pre-existing land easements under our accounting policy that existed before adoption of the lease standard. We did not elect the practical expedient to use hindsight in making judgments when determining the lease term.

The adoption of the lease standard did not change our previously reported financial statements. However, in accordance with the lease standard, on a prospective basis, a significant portion of finance lease costs for PPAs that have historically been presented in Cost of Electric Fuel and Purchased Power are now presented in Depreciation and Amortization Expense and Interest Expense on Sempra Energy’s and SDG&E’s statements of operations. Additionally, the adoption of the lease standard had a material impact on our balance sheets at January 1, 2019 due to the initial recognition of ROU assets and lease liabilities for operating leases. Our finance leases were already included on our balance sheets prior to adoption of the lease standard, consistent with previous U.S. GAAP for capital leases.

The following table shows the initial (decreases) increases on our balance sheets at January 1, 2019 from adoption of the lease standard.

IMPACT FROM ADOPTION OF THE LEASE STANDARD
(Dollars in millions)
	Sempra Energy Consolidated			SDG&E		SoCalGas
Assets held for sale	$	13		$	—	$	—
Sundry	(71		)	—		—
Property, plant and equipment, net	(147		)	—		—
Right-of-use assets – operating leases	603			130		116
Deferred income tax assets	(3		)	—		—
Other current liabilities	80			20		23
Long-term debt	(138		)	—		—
Deferred credits and other	436			110		93
Retained earnings	17			—		—

As a result of the adoption of the lease standard, we derecognized our corporate headquarters building lease in accordance with the transition provisions for build-to-suit arrangements. On a prospective basis, we will account for the corporate headquarters building lease as an operating lease. The initial impact is included in the above table.

We include additional disclosures about our leases in Note 11.

ASU 2016-13, “Measurement of Credit Losses on Financial Instruments”: ASU 2016-13 changes how entities will measure credit losses for most financial assets and certain other instruments. The standard introduces an “expected credit loss” impairment model that requires immediate recognition of estimated credit losses expected to occur over the remaining life of most financial assets measured at amortized cost, including trade and other receivables, loan commitments and financial guarantees. ASU 2016-13 also requires use of an allowance to record estimated credit losses on available-for-sale debt securities and expands disclosure requirements regarding an entity’s assumptions, models and methods for estimating the credit losses.

For public entities, ASU 2016-13 is effective for fiscal years beginning after December 15, 2019, including interim periods therein, with early adoption permitted for fiscal years beginning after December 15, 2018. The amendments are to be applied using a modified retrospective approach through a cumulative-effect adjustment to retained earnings at the beginning of the first reporting period in the year of adoption. We are currently evaluating the impact of the standard on our ongoing financial reporting and plan to adopt the standard on January 1, 2020.

ASU 2017-04, “Simplifying the Test for Goodwill Impairment”: ASU 2017-04 removes the second step of the goodwill impairment test, which requires a hypothetical purchase price allocation. An entity will be required to apply a one-step quantitative test and record the amount of goodwill impairment as the excess of a reporting unit’s carrying amount over its fair value, not to exceed the carrying amount of goodwill. For public entities, ASU 2017-04 is effective for annual or interim goodwill impairment tests in fiscal years beginning after December 15, 2019, with early adoption permitted. The amendments are to be applied on a prospective basis. We plan to adopt the standard on January 1, 2020.

ASU 2018-02, “Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income”: ASU 2018-02 contains amendments that allow a reclassification from AOCI to retained earnings for stranded tax effects resulting from the TCJA. Under ASU 2018-02, an entity is required to provide certain disclosures regarding stranded tax effects, including its accounting policy related to releasing the income tax effects from AOCI. The amendments in this update can be applied either as of the beginning of the period of adoption or retrospectively as of the date of enactment of the TCJA and to each period in which the effect of the TCJA is recognized. We adopted ASU 2018-02 on January 1, 2019 and reclassified the income tax effects of the TCJA from AOCI to retained earnings.

The impact from adoption of ASU 2018-02 on January 1, 2019 was as follows:

▪ Sempra Energy: increase of $40 million to beginning Retained Earnings, $2 million to noncurrent Regulatory Liabilities and $42 million to Accumulated Other Comprehensive Loss;

▪ SDG&E: increase of $2 million to beginning Retained Earnings and Accumulated Other Comprehensive Loss; and

▪

SoCalGas: increase of $2 million to beginning Retained Earnings, $2 million to noncurrent Regulatory Liabilities and $4 million to Accumulated Other Comprehensive Loss.

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 our asset values may fall or our liabilities 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 designate each derivative as (1) a cash flow hedge, (2) a fair value hedge, 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 hedge), on the balance sheet (fair value hedges and regulatory offsets), or recognized in earnings. 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, Sempra LNG and Sempra Renewables may use natural gas and electricity derivatives, as appropriate, 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 or in Cost of Sales on the Condensed Consolidated Statements of Operations. Certain of these derivatives may also be designated as cash flow hedges. Sempra Mexico may also use natural gas energy derivatives with the objective of managing price risk and lowering natural gas prices at its distribution operations. These derivatives, which are recorded as commodity costs that are offset by regulatory account balances and recovered in rates, are recognized in Cost of Natural Gas on the Condensed Consolidated Statements of Operations.

▪ 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 GHG 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 Energy 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. Separately, Otay Mesa VIE has entered into interest rate swap agreements, designated as cash flow hedges, to moderate its exposure to interest rate changes.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 utilize foreign currency derivatives as a means to manage the risk of exposure to significant fluctuations in our income tax expense and equity earnings from these impacts; however, we generally do not hedge our deferred income tax assets and liabilities or for inflation.

Fair Value Measurement Policy

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 or decrease in market electricity forward prices would result in a significantly higher or lower fair value, respectively. We summarize long-term, fixed-price electricity position volumes in Note 8.

Realized gains and losses associated with CRRs and long-term 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 Instruments

The fair values of certain of our financial instruments (cash, accounts and notes 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.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 value 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, 2018.

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 (other than a $7 million investment at March 31, 2019 measured at net asset value):

▪ Nuclear decommissioning trusts reflect the assets of SDG&E’s NDT, excluding cash balances. 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.”

▪

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 March 31, 2019 and December 31, 2018.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.

Legal Costs Policy

LEGAL PROCEEDINGSWe 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 applicable insurance coverage and could materially adversely affect our business, cash flows, results of operations, financial condition and prospects. Unless otherwise indicated, we are unable to estimate reasonably possible 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 Energy’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

Certain of our contracts are short-term leases, which have a lease term of 12 months or less at lease commencement. We do not recognize a lease liability or ROU asset arising from short-term leases for all existing classes of underlying assets. In such cases, we recognize short-term lease costs on a straight-line basis over the lease term. Our short-term lease costs for the period reasonably reflect our short-term lease commitments. As of the lease commencement date, we recognize a lease liability for our obligation to make future lease payments, which we initially measure at present value using our incremental borrowing rate at the date of lease commencement, unless the rate implicit in the lease is readily determinable. We determine our incremental borrowing rate based on the rate of interest that we would have to pay to borrow, on a collateralized basis over a similar term, an amount equal to the lease payments in a similar economic environment. We also record an ROU asset for our right to use the underlying asset, which is initially equal to the lease liability and adjusted for lease payments made at or before lease commencement, lease incentives, and any initial direct costs. Like other long-lived assets, we test ROU assets for recoverability whenever events or changes in circumstances have occurred that may affect the recoverability or the estimated useful lives of the ROU assets.

For our operating leases, our non-regulated entities recognize a single lease cost on a straight-line basis over the lease term in operating expenses. The California Utilities recognize this single lease cost on a basis that is consistent with the recovery of such costs in accordance with U.S. GAAP governing rate-regulated operations.

For our finance leases, the interest expense on the lease liability and amortization of the ROU asset are accounted for separately. Our non-regulated entities use the effective interest rate method to account for the imputed interest on the lease liability and amortize the ROU asset on a straight-line basis over the lease term. The California Utilities recognize amortization of the ROU asset on a basis that is consistent with the recovery of such costs in accordance with U.S. GAAP governing rate-regulated operations.

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 from one period to the next.

Segment Information

At March 31, 2019, we had six 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 Utility holds our investment in Oncor Holdings, which owns an 80.25-percent interest in Oncor, a regulated electric transmission and distribution utility serving customers in the north-central, eastern and western parts of Texas.

▪ 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 Renewables develops, owns and operates, or holds interests in, wind power generation facilities serving wholesale electricity markets in the U.S. In December 2018, Sempra Renewables completed the sale of all its operating solar assets, solar and battery storage development projects and one wind generation facility. In April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments. Upon completion of this sale, remaining nominal business activities at Sempra Renewables were subsumed into Parent and other and the Sempra Renewables segment ceased to exist.

▪ Sempra LNG (previously known as Sempra LNG & Midstream) develops, owns and operates, or holds interests in, terminals for the import and export of LNG and sale of natural gas, natural gas pipelines and marketing operations, all within the U.S. and Mexico. In February 2019, we completed the sale of our natural gas storage assets at Mississippi Hub and Bay Gas.

As we discuss in Note 5, the financial information related to our businesses that constituted the Sempra South American Utilities segment has been reclassified to discontinued operations for all periods presented. The information in the tables below excludes amounts from discontinued operations unless otherwise noted.

We evaluate each segment’s performance based on its contribution to Sempra Energy’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. The California Utilities’ operations are based on rates set by the CPUC and 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)

3 Months Ended

Mar. 31, 2019

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 the Condensed Consolidated Balance Sheets to the sum of such amounts reported on the 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)
	March 31,		December 31,
	2019		2018
Sempra Energy Consolidated:
Cash and cash equivalents	$	78	$	102
Restricted cash, current	41		35
Restricted cash, noncurrent	21		21
Cash, cash equivalents and restricted cash in discontinued operations	67		88
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	207	$	246
SDG&E:
Cash and cash equivalents	$	10	$	8
Restricted cash, current	21		11
Restricted cash, noncurrent	18		18
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	49	$	37

Inventory Table

The following table presents the components of inventories by segment.

INVENTORY BALANCES
(Dollars in millions)
	Natural gas				LNG				Materials and supplies				Total
	March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018
SDG&E	$	—	$	—	$	—	$	—	$	99	$	102	$	99	$	102
SoCalGas	12		92		—		—		46		42		58		134
Sempra Mexico	—		—		7		4		16		15		23		19
Sempra LNG	9		3		—		—		—		—		9		3
Sempra Energy Consolidated	$	21	$	95	$	7	$	4	$	161	$	159	$	189	$	258

Capitalized Financing Costs Table

The table below summarizes capitalized interest and AFUDC.

CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Three months ended March 31,
	2019		2018
Sempra Energy Consolidated	$	47	$	49
SDG&E	17		24
SoCalGas	11		13

Variable Interest Entity Table

Sempra Energy’s Condensed Consolidated Statements of Operations include the following amounts associated with the tax equity limited liability companies, net of eliminations of transactions between Sempra Energy and these entities.

AMOUNTS ASSOCIATED WITH TAX EQUITY ARRANGEMENTS
(Dollars in millions)
	Three months ended March 31,
	2019			2018
REVENUES
Energy-related businesses	$	6		$	17
EXPENSES
Operation and maintenance	(2		)	(4		)
Depreciation and amortization	(3		)	(11		)
Income before income taxes	1			2
Income tax benefit (expense)	1			(5		)
Net income (loss)	2			(3		)
(Earnings) losses attributable to noncontrolling interests(1)	(3		)	21
(Losses) earnings attributable to common shares	$	(1	)	$	18

⁽¹⁾

Net income or loss attributable to NCI is computed using the HLBV method and is not based on ownership percentages.The Condensed Consolidated Statements of Operations of Sempra Energy and SDG&E include the following amounts associated with Otay Mesa VIE. The amounts are net of eliminations of transactions between SDG&E and Otay Mesa VIE. The captions in the table below correspond to SDG&E’s Condensed Consolidated Statements of Operations.

AMOUNTS ASSOCIATED WITH OTAY MESA VIE
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Operating expenses
Cost of electric fuel and purchased power	$	(16	)	$	(16	)
Operation and maintenance	4			4
Depreciation and amortization	7			8
Total operating expenses	(5		)	(4		)
Operating income	5			4
Interest expense	(4		)	(5		)
Income (losses) before income taxes/Net income (loss)	1			(1		)
(Earnings) losses attributable to noncontrolling interest	(1		)	1
Earnings attributable to common shares	$	—		$	—

Net Periodic Benefit Cost Table

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

NET PERIODIC BENEFIT COST – SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	Three months ended March 31,
	2019			2018			2019			2018
Service cost	$	27		$	33		$	4		$	6
Interest cost	35			35			9			9
Expected return on assets	(36		)	(42		)	(18		)	(18		)
Amortization of:
Prior service cost	3			3			—			—
Actuarial loss (gain)	14			9			(2		)	(1		)
Settlement charges	—			14			—			—
Net periodic benefit cost (credit)	43			52			(7		)	(4		)
Regulatory adjustment	(36		)	(45		)	7			4
Total expense recognized	$	7		$	7		$	—		$	—

NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	Three months ended March 31,
	2019			2018			2019			2018
Service cost	$	8		$	8		$	1		$	1
Interest cost	9			9			2			2
Expected return on assets	(11		)	(13		)	(3		)	(3		)
Amortization of:
Prior service cost	1			—			1			1
Actuarial loss (gain)	4			1			(1		)	(1		)
Settlement charges	—			14			—			—
Net periodic benefit cost	11			19			—			—
Regulatory adjustment	(11		)	(19		)	—			—
Total expense recognized	$	—		$	—		$	—		$	—

NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	Three months ended March 31,
	2019			2018			2019			2018
Service cost	$	16		$	22		$	3		$	4
Interest cost	23			23			7			7
Expected return on assets	(24		)	(26		)	(14		)	(14		)
Amortization of:
Prior service cost (credit)	2			2			(1		)	(1		)
Actuarial loss (gain)	9			6			(2		)	—
Net periodic benefit cost (credit)	26			27			(7		)	(4		)
Regulatory adjustment	(25		)	(26		)	7			4
Total expense recognized	$	1		$	1		$	—		$	—

Contributions to Benefit Plans Table

The following table shows our year-to-date contributions to pension and other postretirement benefit plans and the amounts we expect to contribute in 2019.

BENEFIT PLAN CONTRIBUTIONS
(Dollars in millions)
	Sempra Energy Consolidated		SDG&E		SoCalGas
Contributions through March 31, 2019:
Pension plans	$	9	$	—	$	1
Other postretirement benefit plans	2		—		—
Total expected contributions in 2019:
Pension plans	$	234	$	40	$	118
Other postretirement benefit plans	9		—		1

Earnings Per Share Computations Table

The following table provides EPS computations for the three months ended March 31, 2019 and 2018. 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 March 31,
	2019			2018
Numerator for continuing operations:
Income from continuing operations, net of income tax	$	560		$	330
(Earnings) losses attributable to noncontrolling interests	(32		)	24
Mandatory convertible preferred stock dividends	(36		)	(28		)
Earnings from continuing operations attributable to common shares	$	492		$	326
Numerator for discontinued operations:
(Loss) income from discontinued operations, net of income tax	$	(42	)	$	28
Earnings attributable to noncontrolling interests	(9		)	(7		)
(Losses) earnings from discontinued operations attributable to common shares	$	(51	)	$	21
Numerator for earnings:
Earnings attributable to common shares	$	441		$	347
Denominator:
Weighted-average common shares outstanding for basic EPS(1)	274,674			257,932
Dilutive effect of stock options and RSUs(2)	969			933
Dilutive effect of common shares sold forward	1,585			625
Weighted-average common shares outstanding for diluted EPS	277,228			259,490
Basic EPS:
Earnings from continuing operations attributable to common shares	$	1.79		$	1.26
(Losses) earnings from discontinued operations attributable to common shares	$	(0.19	)	$	0.08
Earnings attributable to common shares	$	1.60		$	1.34
Diluted EPS:
Earnings from continuing operations attributable to common shares	$	1.78		$	1.25
(Losses) earnings from discontinued operations attributable to common shares	$	(0.19	)	$	0.08
Earnings attributable to common shares	$	1.59		$	1.33

⁽¹⁾ Includes 613 and 628 average fully vested RSUs held in our Deferred Compensation Plan for the three months ended March 31, 2019 and 2018, respectively. These fully vested RSUs are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

⁽²⁾ 

Due to market fluctuations of both Sempra Energy 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 March 31, 2019 and 2018
Sempra Energy Consolidated(2):
Balance as of December 31, 2018	$	(564	)	$	(82	)	$	(118	)	$	(764	)
Cumulative-effect adjustment from change in accounting principle	—			(25		)	(17		)	(42		)
OCI before reclassifications	32			(45		)	1			(12		)
Amounts reclassified from AOCI	—			(1		)	2			1
Net OCI	32			(46		)	3			(11		)
Balance as of March 31, 2019	$	(532	)	$	(153	)	$	(132	)	$	(817	)
Balance as of December 31, 2017	$	(420	)	$	(122	)	$	(84	)	$	(626	)
Cumulative-effect adjustment from change in accounting principle	—			(3		)	—			(3		)
OCI before reclassifications	24			66			—			90
Amounts reclassified from AOCI	—			(8		)	2			(6		)
Net OCI	24			58			2			84
Balance as of March 31, 2018	$	(396	)	$	(67	)	$	(82	)	$	(545	)
SDG&E:
Balance as of December 31, 2018							$	(10	)	$	(10	)
Cumulative-effect adjustment from change in accounting principle							(2		)	(2		)
Balance as of March 31, 2019							$	(12	)	$	(12	)
Balance as of December 31, 2017 and March 31, 2018							$	(8	)	$	(8	)
SoCalGas:
Balance as of December 31, 2018				$	(12	)	$	(8	)	$	(20	)
Cumulative-effect adjustment from change in accounting principle				(2		)	(2		)	(4		)
Balance as of March 31, 2019				$	(14	)	$	(10	)	$	(24	)
Balance as of December 31, 2017 and March 31, 2018				$	(13	)	$	(8	)	$	(21	)

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

⁽²⁾  Includes discontinued operations.

Reclassifications out of AOCI Table

RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
Details about accumulated other comprehensive income (loss) components	Amounts reclassified from accumulated other comprehensive income (loss)						Affected line item on Condensed Consolidated Statements of Operations
	Three months ended March 31,
	2019			2018
Sempra Energy Consolidated:
Financial instruments:
Interest rate and foreign exchange instruments(1)	$	1		$	(2	)	Interest Expense
	(3		)	(18		)	Other Income, Net
Interest rate and foreign exchange instruments	1			4			Equity Earnings (Losses)
Foreign exchange instruments	1			—			Revenues: Energy-Related Businesses
Total before income tax	—			(16		)
	—			3			Income Tax Expense
Net of income tax	—			(13		)
	(1		)	5			(Earnings) Losses Attributable to Noncontrolling Interests
	$	(1	)	$	(8	)
Pension and other postretirement benefits:
Amortization of actuarial loss(2)	$	2		$	3		Other Income, Net
Amortization of prior service cost(2)	1			—			Other Income, Net
Total before income tax	3			3
	(1		)	(1		)	Income Tax Expense
Net of income tax	$	2		$	2
Total reclassifications for the period, net of tax	$	1		$	(6	)
SDG&E:
Financial instruments:
Interest rate instruments(1)	$	1		$	3		Interest Expense
	(1		)	(3		)	(Earnings) Losses Attributable to Noncontrolling Interest
Total reclassifications for the period, net of tax	$	—		$	—

⁽¹⁾  Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.

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

For the three months ended March 31, 2019 and 2018, reclassifications out of AOCI to net income were negligible for SoCalGas.

Ownership Interests Held By Others Table

The following table provides information on noncontrolling ownership interests held by others (not including preferred shareholders) in Other Noncontrolling Interests in Total Equity on Sempra Energy’s Condensed Consolidated Balance Sheets.

OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
	Percent ownership held by noncontrolling interests				Equity (deficit) held by noncontrolling interests
	March 31, 2019		December 31, 2018		March 31, 2019			December 31, 2018
SDG&E:
Otay Mesa VIE	100	%	100	%	$	102		$	100
Sempra Mexico:
IEnova	33.4		33.5		1,611			1,592
IEnova subsidiaries(1)	10.0 – 47.6		10.0 – 49.0		13			13
Sempra Renewables:
Tax equity arrangements – wind(2)	NA		NA		161			158
PXiSE Energy Solutions, LLC	11.1		11.1		—			1
Sempra LNG:
Bay Gas	—		9.1		—			18
Liberty Gas Storage, LLC	24.6		24.6		(12		)	(12		)
Discontinued Operations:
Chilquinta Energía subsidiaries(1)	19.7 – 43.4		19.7 – 43.4		24			23
Luz del Sur	16.4		16.4		201			193
Tecsur	9.8		9.8		4			4
Total Sempra Energy					$	2,104		$	2,090

⁽¹⁾  IEnova and Chilquinta Energía have subsidiaries with NCI held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.

⁽²⁾  Net income or loss attributable to NCI is computed using the HLBV method and is not based on ownership percentages.

Transactions with Affiliates Table

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

AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	March 31, 2019			December 31, 2018
Sempra Energy Consolidated:
Total due from various unconsolidated affiliates – current	$	50		$	37
Sempra Mexico(1):
IMG – Note due March 15, 2022(2)	$	668		$	641
Energía Sierra Juárez – Note(3)	—			3
Total due from unconsolidated affiliates – noncurrent	$	668		$	644
Total due to various unconsolidated affiliates – current	$	(10	)	$	(10	)
Sempra Mexico(1):
Total due to unconsolidated affiliates – noncurrent – TAG – Note due December 20, 2021(4)	$	(38	)	$	(37	)
SDG&E:
Sempra Energy	$	(37	)	$	(43	)
SoCalGas	(14		)	(6		)
Various affiliates	(12		)	(12		)
Total due to unconsolidated affiliates – current	$	(63	)	$	(61	)
Income taxes due (to) from Sempra Energy(5)	$	(29	)	$	5
SoCalGas:
SDG&E	$	14		$	6
Various affiliates	1			1
Total due from unconsolidated affiliates – current	$	15		$	7
Sempra Energy	$	(39	)	$	(34	)
Various affiliates	(3		)	—
Total due to unconsolidated affiliates – current	$	(42	)	$	(34	)
Income taxes due to Sempra Energy(5)	$	(88	)	$	(4	)

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

⁽²⁾  Mexican peso-denominated revolving line of credit for up to 14.2 billion Mexican pesos or approximately $729 million U.S. dollar-equivalent, at a variable interest rate based on the 91-day Interbank Equilibrium Interest Rate plus 220 bps (10.69 percent at March 31, 2019), to finance construction of the natural gas marine pipeline.

⁽³⁾  U.S. dollar-denominated loan, at a variable interest rate based on the 30-day LIBOR plus 637.5 bps (8.89 percent at December 31, 2018).

⁽⁴⁾  U.S. dollar-denominated loan, at a variable interest rate based on the 6-month LIBOR plus 290 bps (5.54 percent at March 31, 2019).

⁽⁵⁾  SDG&E and SoCalGas are included in the consolidated income tax return of Sempra Energy and are allocated income tax expense from Sempra Energy in an amount equal to that which would result from each company having always filed a separate return.

The following table summarizes revenues and cost of sales from unconsolidated affiliates.

REVENUES AND COST OF SALES FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended March 31,
	2019		2018
Revenues:
Sempra Energy Consolidated	$	14	$	16
SDG&E	1		2
SoCalGas	17		17
Cost of Sales:
Sempra Energy Consolidated	$	14	$	12
SDG&E	20		19
SoCalGas	4		—

Other Income and Expense Table

Other Income, Net on the Condensed Consolidated Statements of Operations consisted of the following:

OTHER INCOME, NET
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Sempra Energy Consolidated:
Allowance for equity funds used during construction	$	21		$	27
Investment gains (losses)(1)	26			(1		)
Gains on interest rate and foreign exchange instruments, net	13			62
Foreign currency transaction gains, net(2)	7			30
Non-service component of net periodic benefit credit	24			32
Penalties related to billing practices OII	(8		)	—
Interest on regulatory balancing accounts, net	(1		)	—
Sundry, net	—			2
Total	$	82		$	152
SDG&E:
Allowance for equity funds used during construction	$	12		$	18
Non-service component of net periodic benefit credit	9			9
Sundry, net	1			1
Total	$	22		$	28
SoCalGas:
Allowance for equity funds used during construction	$	8		$	9
Non-service component of net periodic benefit credit	18			25
Penalties related to billing practices OII	(8		)	—
Interest on regulatory balancing accounts, net	(1		)	—
Sundry, net	(1		)	(1		)
Total	$	16		$	33

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

⁽²⁾ 

Includes gains of $10 million and $39 million in the three months ended March 31, 2019 and 2018, respectively, from translation to U.S. dollars of a Mexican peso-denominated loan to the IMG JV, which are offset by corresponding amounts included in Equity Earnings (Losses) on the Condensed Consolidated Statements of Operations.

Income Tax Expense and Effective Income Tax Rates Table

We provide our calculations of ETRs in the following table.

INCOME TAX EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Sempra Energy Consolidated:
Income tax expense from continuing operations	$	42		$	242
Income from continuing operations before income taxes
and equity earnings (losses) of unconsolidated entities	$	501		$	593
Equity earnings, before income tax(1)	5			5
Pretax income	$	506		$	598
Effective income tax rate	8		%	40		%
SDG&E:
Income tax expense	$	5		$	56
Income before income taxes	$	182		$	225
Effective income tax rate	3		%	25		%
SoCalGas:
Income tax expense	$	19		$	59
Income before income taxes	$	283		$	284
Effective income tax rate	7		%	21		%

⁽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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NEW ACCOUNTING STANDARDS (Tables)

3 Months Ended

Mar. 31, 2019

Accounting Changes and Error Corrections [Abstract]

Schedule of New Accounting Pronouncements and Changes in Accounting Principles

The following table shows the initial (decreases) increases on our balance sheets at January 1, 2019 from adoption of the lease standard.

IMPACT FROM ADOPTION OF THE LEASE STANDARD
(Dollars in millions)
	Sempra Energy Consolidated			SDG&E		SoCalGas
Assets held for sale	$	13		$	—	$	—
Sundry	(71		)	—		—
Property, plant and equipment, net	(147		)	—		—
Right-of-use assets – operating leases	603			130		116
Deferred income tax assets	(3		)	—		—
Other current liabilities	80			20		23
Long-term debt	(138		)	—		—
Deferred credits and other	436			110		93
Retained earnings	17			—		—

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REVENUES (Tables)

3 Months Ended

Mar. 31, 2019

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)
	Three months ended March 31, 2019
	SDG&E			SoCalGas			Sempra Mexico		Sempra Renewables		Sempra LNG		Consolidating adjustments			Sempra Energy Consolidated
By major service line:
Utilities	$	1,236		$	1,528		$	27	$	—	$	—	$	(18	)	$	2,773
Midstream	—			—			171		—		67		(59		)	179
Renewables	—			—			20		4		—		—			24
Other	—			—			66		—		1		—			67
Revenues from contracts with customers	$	1,236		$	1,528		$	284	$	4	$	68	$	(77	)	$	3,043
By market:
Electric	$	997		$	—		$	86	$	4	$	1	$	(1	)	$	1,087
Gas	239			1,528			198		—		67		(76		)	1,956
Revenues from contracts with customers	$	1,236		$	1,528		$	284	$	4	$	68	$	(77	)	$	3,043
Revenues from contracts with customers	$	1,236		$	1,528		$	284	$	4	$	68	$	(77	)	$	3,043
Utilities regulatory revenues	(91		)	(167		)	—		—		—		—			(258		)
Other revenues	—			—			99		3		73		(62		)	113
Total revenues	$	1,145		$	1,361		$	383	$	7	$	141	$	(139	)	$	2,898
	Three months ended March 31, 2018
By major service line:
Utilities	$	1,131		$	1,081		$	28	$	—	$	—	$	(19	)	$	2,221
Midstream	—			—			143		—		54		(21		)	176
Renewables	—			—			22		11		1		(1		)	33
Other	—			—			41		—		2		(2		)	41
Revenues from contracts with customers	$	1,131		$	1,081		$	234	$	11	$	57	$	(43	)	$	2,471
By market:
Electric	$	963		$	—		$	62	$	11	$	2	$	(4	)	$	1,034
Gas	168			1,081			172		—		55		(39		)	1,437
Revenues from contracts with customers	$	1,131		$	1,081		$	234	$	11	$	57	$	(43	)	$	2,471
Revenues from contracts with customers	$	1,131		$	1,081		$	234	$	11	$	57	$	(43	)	$	2,471
Utilities regulatory revenues	(76		)	45			—		—		—		—			(31		)
Other revenues	—			—			74		14		47		(39		)	96
Total revenues	$	1,055		$	1,126		$	308	$	25	$	104	$	(82	)	$	2,536

Schedule of Timing of Remaining Performance Obligations

For contracts greater than one year, at March 31, 2019, we expect to recognize revenue related to the fixed fee component of the consideration as shown below. SoCalGas did not have any such remaining performance obligations at March 31, 2019.

REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra Energy Consolidated		SDG&E
2019 (excluding first three months of 2019)	$	384	$	2
2020	512		3
2021	513		3
2022	515		3
2023	509		3
Thereafter	2,784		52
Total revenues to be recognized	$	5,217	$	66

⁽¹⁾

Excludes intercompany transactions.

Schedule of Contract Liabilities

Activities within Sempra Energy’s contract liabilities are presented below. There were no contract liabilities at SDG&E or SoCalGas for the three months ended March 31, 2019 and 2018.

CONTRACT LIABILITIES
(Dollars in millions)
Balance at January 1, 2019	$	(70	)
Revenue from performance obligations satisfied during reporting period	1
Payments received in advance	(2		)
Balance at March 31, 2019(1)	$	(71	)
Balance at January 1, 2018	$	—
Adoption of ASC 606 adjustment	(61		)
Revenue from performance obligations satisfied during reporting period	5
Payments received in advance	(7		)
Balance at March 31, 2018	$	(63	)

⁽¹⁾ Includes a negligible amount in Other Current Liabilities and $71 million in Deferred Credits and Other on the Sempra Energy Condensed Consolidated Balance Sheet.

Schedule of Contract Accounts Receivable

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

RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS
(Dollars in millions)
	March 31, 2019		December 31, 2018
Sempra Energy Consolidated:
Accounts receivable – trade, net	$	1,145	$	1,106
Accounts receivable – other, net	14		11
Due from unconsolidated affiliates – current(1)	6		4
Assets held for sale	1		6
Total	$	1,166	$	1,127
SDG&E:
Accounts receivable – trade, net	$	390	$	368
Accounts receivable – other, net	12		6
Due from unconsolidated affiliates – current(1)	3		3
Total	$	405	$	377
SoCalGas:
Accounts receivable – trade, net	$	674	$	634
Accounts receivable – other, net	2		5
Total	$	676	$	639

⁽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)

3 Months Ended

Mar. 31, 2019

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)
	March 31, 2019			December 31, 2018
SDG&E:
Fixed-price contracts and other derivatives	$	(144	)	$	(150	)
Deferred income taxes refundable in rates	(171		)	(236		)
Pension and other postretirement benefit plan obligations	190			186
Removal obligations	(1,946		)	(1,848		)
Unamortized loss on reacquired debt	6			7
Environmental costs	27			28
Sunrise Powerlink fire mitigation	121			120
Regulatory balancing accounts(1)
Commodity – electric	60			(8		)
Gas transportation	13			45
Safety and reliability	77			70
Public purpose programs	(80		)	(62		)
Other balancing accounts	67			145
Other regulatory liabilities, net(2)	(199		)	(177		)
Total SDG&E	(1,979		)	(1,880		)
SoCalGas:
Pension and other postretirement benefit plan obligations	479			470
Employee benefit costs	49			49
Removal obligations	(804		)	(833		)
Deferred income taxes refundable in rates	(248		)	(336		)
Unamortized loss on reacquired debt	6			7
Environmental costs	32			28
Workers’ compensation	9			9
Regulatory balancing accounts(1)
Commodity – gas, including transportation	16			196
Safety and reliability	348			332
Public purpose programs	(289		)	(325		)
Other balancing accounts	(143		)	(68		)
Other regulatory liabilities, net(2)	(160		)	(130		)
Total SoCalGas	(705		)	(601		)
Sempra Mexico:
Deferred income taxes recoverable in rates	81			81
Other regulatory assets	9			6
Total Sempra Energy Consolidated	$	(2,594	)	$	(2,394	)

⁽¹⁾  At March 31, 2019 and December 31, 2018, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $84 million and $78 million, respectively, and for SoCalGas was $405 million and $185 million, respectively. 

⁽²⁾  

Includes regulatory assets earning a rate of return.

Schedule of Regulatory Liabilities

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

REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	March 31, 2019			December 31, 2018
SDG&E:
Fixed-price contracts and other derivatives	$	(144	)	$	(150	)
Deferred income taxes refundable in rates	(171		)	(236		)
Pension and other postretirement benefit plan obligations	190			186
Removal obligations	(1,946		)	(1,848		)
Unamortized loss on reacquired debt	6			7
Environmental costs	27			28
Sunrise Powerlink fire mitigation	121			120
Regulatory balancing accounts(1)
Commodity – electric	60			(8		)
Gas transportation	13			45
Safety and reliability	77			70
Public purpose programs	(80		)	(62		)
Other balancing accounts	67			145
Other regulatory liabilities, net(2)	(199		)	(177		)
Total SDG&E	(1,979		)	(1,880		)
SoCalGas:
Pension and other postretirement benefit plan obligations	479			470
Employee benefit costs	49			49
Removal obligations	(804		)	(833		)
Deferred income taxes refundable in rates	(248		)	(336		)
Unamortized loss on reacquired debt	6			7
Environmental costs	32			28
Workers’ compensation	9			9
Regulatory balancing accounts(1)
Commodity – gas, including transportation	16			196
Safety and reliability	348			332
Public purpose programs	(289		)	(325		)
Other balancing accounts	(143		)	(68		)
Other regulatory liabilities, net(2)	(160		)	(130		)
Total SoCalGas	(705		)	(601		)
Sempra Mexico:
Deferred income taxes recoverable in rates	81			81
Other regulatory assets	9			6
Total Sempra Energy Consolidated	$	(2,594	)	$	(2,394	)

⁽¹⁾  At March 31, 2019 and December 31, 2018, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $84 million and $78 million, respectively, and for SoCalGas was $405 million and $185 million, respectively. 

⁽²⁾  

Includes regulatory assets earning a rate of return.

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ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS (Tables)

3 Months Ended

Mar. 31, 2019

Business Combinations [Abstract]

Schedule Of Assets Held for Sale and Deconsolidation of Subsidiaries Table

The following table summarizes the carrying amounts of the major classes of assets and related liabilities classified as held for sale.

ASSETS HELD FOR SALE
(Dollars in millions)
	Sempra Renewables’ wind assets
	At March 31, 2019
Cash and cash equivalents	$	4
Accounts receivable – trade, net	2
Other current assets	2
Property, plant and equipment, net	366
Total assets held for sale	$	374
Accounts payable – trade	$	1
Asset retirement obligations	6
Total liabilities held for sale(1)	$	7

⁽¹⁾ 

Included in Other Current Liabilities on Sempra Energy’s Condensed Consolidated Balance Sheet.Summarized results from discontinued operations were as follows:

DISCONTINUED OPERATIONS
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Revenues	$	421		$	426
Cost of sales	(265		)	(293		)
Operating expenses	(45		)	(54		)
Interest and other	(3		)	(5		)
Income before income taxes and equity earnings of unconsolidated entities	108			74
Income tax expense	(151		)	(47		)
Equity earnings	1			1
(Loss) income from discontinued operations, net of income tax	(42		)	28
Earnings attributable to noncontrolling interests	(9		)	(7		)
(Losses) earnings from discontinued operations attributable to common shares	$	(51	)	$	21

The following table summarizes the carrying amounts of the major classes of assets and related liabilities classified as held for sale in discontinued operations.

ASSETS HELD FOR SALE IN DISCONTINUED OPERATIONS
(Dollars in millions)
	March 31, 2019		December 31, 2018
Cash and cash equivalents	$	67	$	88
Accounts receivable, net	331		315
Due from unconsolidated affiliates	3		2
Inventories	41		38
Other current assets	15		16
Current assets	$	457	$	459
Due from unconsolidated affiliates	$	46	$	44
Goodwill and other intangible assets	834		819
Property, plant and equipment, net	2,459		2,357
Other noncurrent assets	49		39
Noncurrent assets	$	3,388	$	3,259
Short-term debt	$	46	$	55
Accounts payable	188		176
Current portion of long-term debt and finance leases	22		29
Other current liabilities	119		108
Current liabilities	$	375	$	368
Long-term debt and finance leases	$	721	$	708
Deferred income taxes	263		250
Other noncurrent liabilities	62		55
Noncurrent liabilities	$	1,046	$	1,013

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INVESTMENT IN UNCONSOLIDATED ENTITIES (Tables)

3 Months Ended

Mar. 31, 2019

Investments [Abstract]

Business Acquisition, Results of Operations

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

SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS
(Dollars in millions)
	Three months ended March 31, 2019			March 9 - March 31, 2018
Operating revenues	$	1,016		$	236
Operating expense	(775		)	(185		)
Income from operations	241			51
Interest expense	(86		)	(22		)
Income tax expense	(23		)	(7		)
Net income	114			19
Noncontrolling interest held by TTI	(23		)	(4		)
Earnings attributable to Sempra Energy(1)	91			15

⁽¹⁾ 

Earnings at Oncor Holdings differ from earnings at the Sempra Texas Utility segment due to amortization of a tax sharing liability associated with a tax sharing arrangement and basis differences in AOCI.

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DEBT AND CREDIT FACILITIES (Tables)

3 Months Ended

Mar. 31, 2019

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities

PRIMARY U.S. COMMITTED LINES OF CREDIT
(Dollars in millions)
	March 31, 2019
	Total facility			Commercial paper outstanding(1)			Available unused credit
Sempra Energy(2)	$	1,250		$	—		$	1,250
Sempra Global(3)	3,185			(1,289		)	1,896
California Utilities(4):
SDG&E	750			(238		)	512
SoCalGas	750			(190		)	560
Less: subject to a combined limit of $1 billion for both utilities	(500		)	—			(500		)
	1,000			(428		)	572
Total	$	5,435		$	(1,717	)	$	3,718

⁽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⁾  The facility also provides for issuance of up to $400 million of letters of credit on behalf of Sempra Energy with the amount of borrowings otherwise available under the facility reduced by the amount of outstanding letters of credit. No letters of credit were outstanding at March 31, 2019.

⁽³⁾  Commercial paper outstanding is before reductions of unamortized discount of $2 million. Sempra Energy guarantees Sempra Global’s obligations under the credit facility.

⁽⁴⁾  The facility also provides for the issuance of letters of credit on behalf of each utility, subject to a combined letter of credit commitment of $250 million for both utilities. The amount of borrowings otherwise available under the facility is reduced by the amount of outstanding letters of credit. No letters of credit were outstanding at March 31, 2019.

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DERIVATIVE FINANCIAL INSTRUMENTS (Tables)

3 Months Ended

Mar. 31, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Commodity Derivative Volumes Table

The following table summarizes net energy derivative volumes.

NET ENERGY DERIVATIVE VOLUMES
(Quantities in millions)
Commodity	Unit of measure	March 31, 2019	December 31, 2018
Sempra Energy Consolidated:
Natural gas	MMBtu	33	35
Electricity	MWh	2	2
Congestion revenue rights	MWh	50	52
SDG&E:
Natural gas	MMBtu	32	33
Electricity	MWh	2	2
Congestion revenue rights	MWh	50	52

Notional Amounts of Derivatives Table

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

FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	March 31, 2019			December 31, 2018
	Notional amount		Maturities	Notional amount		Maturities
Sempra Energy Consolidated:
Cross-currency swaps	$	306	2019-2023	$	306	2019-2023
Other foreign currency derivatives	1,084		2019-2020	1,158		2019-2020

The following table presents the net notional amounts of our interest rate derivatives, excluding JVs.

INTEREST RATE DERIVATIVES
(Dollars in millions)
	March 31, 2019			December 31, 2018
	Notional debt		Maturities	Notional debt		Maturities
Sempra Energy Consolidated:
Cash flow hedges(1)	$	1,430	2019-2032	$	594	2019-2032
SDG&E:
Cash flow hedge(1)	142		2019	142		2019

⁽¹⁾  Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE. In December 2018, OMEC LLC entered into new floating-to-fixed interest rate swaps with notional amounts of $159 million effective April 30, 2019 through October 31, 2019, and a swaption with a notional amount of $142 million effective October 31, 2019 through October 31, 2023.

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, as the cash collateral was in excess of liability positions.

DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	March 31, 2019
	Current assets: Other(1)			Other assets: Sundry			Current liabilities: Other			Deferred credits and other liabilities: Deferred credits and other
Sempra Energy Consolidated:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments(2)	$	—		$	—		$	(5	)	$	(146	)
Derivatives not designated as hedging instruments:
Foreign exchange instruments	12			—			—			—
Commodity contracts not subject to rate recovery	58			6			(65		)	(5		)
Associated offsetting commodity contracts	(47		)	(2		)	47			2
Commodity contracts subject to rate recovery	50			236			(41		)	(65		)
Associated offsetting commodity contracts	(5		)	(2		)	5			2
Associated offsetting cash collateral	—			—			3			3
Net amounts presented on the balance sheet	68			238			(56		)	(209		)
Additional cash collateral for commodity contracts not subject to rate recovery	25			—			—			—
Additional cash collateral for commodity contracts subject to rate recovery	26			—			—			—
Total(3)	$	119		$	238		$	(56	)	$	(209	)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	45		$	234		$	(37	)	$	(65	)
Associated offsetting commodity contracts	(5		)	(2		)	5			2
Associated offsetting cash collateral	—			—			3			3
Net amounts presented on the balance sheet	40			232			(29		)	(60		)
Additional cash collateral for commodity contracts subject to rate recovery	25			—			—			—
Total(3)	$	65		$	232		$	(29	)	$	(60	)
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	5		$	2		$	(4	)	$	—
Net amounts presented on the balance sheet	5			2			(4		)	—
Additional cash collateral for commodity contracts subject to rate recovery	1			—			—			—
Total	$	6		$	2		$	(4	)	$	—

 

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

⁽²⁾ Includes a negligible amount for Otay Mesa VIE.

⁽³⁾ Normal purchase contracts previously measured at fair value are excluded.

DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	December 31, 2018
	Current assets: Other(1)			Other assets: Sundry			Current liabilities: Other			Deferred credits and other liabilities: Deferred credits and other
Sempra Energy Consolidated:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments(2)	$	2		$	—		$	(3	)	$	(147	)
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	153			7			(164		)	(6		)
Associated offsetting commodity contracts	(133		)	(3		)	133			3
Commodity contracts subject to rate recovery	64			233			(42		)	(72		)
Associated offsetting commodity contracts	(6		)	(2		)	6			2
Associated offsetting cash collateral	—			—			—			2
Net amounts presented on the balance sheet	80			235			(70		)	(218		)
Additional cash collateral for commodity contracts not subject to rate recovery	19			—			—			—
Additional cash collateral for commodity contracts subject to rate recovery	33			—			—			—
Total(3)	$	132		$	235		$	(70	)	$	(218	)
SDG&E:
Derivatives designated as hedging instruments:
Interest rate instruments(2)	$	—		$	—		$	(1	)	$	—
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	60			233			(37		)	(72		)
Associated offsetting commodity contracts	(6		)	(2		)	6			2
Associated offsetting cash collateral	—			—			—			2
Net amounts presented on the balance sheet	54			231			(32		)	(68		)
Additional cash collateral for commodity contracts subject to rate recovery	28			—			—			—
Total(3)	$	82		$	231		$	(32	)	$	(68	)
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	4		$	—		$	(5	)	$	—
Net amounts presented on the balance sheet	4			—			(5		)	—
Additional cash collateral for commodity contracts subject to rate recovery	5			—			—			—
Total	$	9		$	—		$	(5	)	$	—

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

⁽²⁾ Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE.

⁽³⁾ Normal purchase contracts previously measured at fair value are excluded.

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

The table below 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 March 31,							Three months ended March 31,
	2019			2018			Location	2019			2018
Sempra Energy Consolidated:
Interest rate and foreign exchange instruments(1)	$	(3	)	$	54		Interest Expense	$	(1	)	$	2
							Other Income, Net	3			18
Interest rate and foreign exchange instruments	(68		)	70			Equity Earnings (Losses)	(1		)	(4		)
Foreign exchange instruments	(3		)	(7		)	Revenues: Energy- Related Businesses	(1		)	—
Total	$	(74	)	$	117			$	—		$	16
SDG&E:
Interest rate instruments(1)	$	—		$	1		Interest Expense	$	(1	)	$	(3	)

⁽¹⁾  Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.

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

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

UNDESIGNATED DERIVATIVE IMPACTS
(Dollars in millions)
		Pretax gain (loss) on derivatives recognized in earnings
		Three months ended March 31,
	Location	2019		2018
Sempra Energy Consolidated:
Foreign exchange instruments	Other Income, Net	$	10	$	44
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	—		(9		)
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	2		2
Commodity contracts subject to rate recovery	Cost of Natural Gas	2		1
Total		$	14	$	38
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	2	$	2
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas	$	2	$	1

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FAIR VALUE MEASUREMENTS (Tables)

3 Months Ended

Mar. 31, 2019

Fair Value Disclosures [Abstract]

Recurring Fair Value Measures Table

RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
	Fair value at March 31, 2019
	Level 1			Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	454		$	5	$	—	$	459
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies	39			9		—		48
Municipal bonds	—			279		—		279
Other securities	—			238		—		238
Total debt securities	39			526		—		565
Total nuclear decommissioning trusts(1)	493			531		—		1,024
Interest rate and foreign exchange instruments	—			12		—		12
Commodity contracts not subject to rate recovery	—			15		—		15
Effect of netting and allocation of collateral(2)	25			—		—		25
Commodity contracts subject to rate recovery	—			8		271		279
Effect of netting and allocation of collateral(2)	21			—		5		26
Total	$	539		$	566	$	276	$	1,381
Liabilities:
Interest rate and foreign exchange instruments	$	—		$	151	$	—	$	151
Commodity contracts not subject to rate recovery	—			21		—		21
Commodity contracts subject to rate recovery	6			4		89		99
Effect of netting and allocation of collateral(2)	(6		)	—		—		(6		)
Total	$	—		$	176	$	89	$	265
	Fair value at December 31, 2018
	Level 1			Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	407		$	4	$	—	$	411
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies	43			10		—		53
Municipal bonds	—			269		—		269
Other securities	—			234		—		234
Total debt securities	43			513		—		556
Total nuclear decommissioning trusts(1)	450			517		—		967
Interest rate and foreign exchange instruments	—			2		—		2
Commodity contracts not subject to rate recovery	—			24		—		24
Effect of netting and allocation of collateral(2)	19			—		—		19
Commodity contracts subject to rate recovery	2			9		278		289
Effect of netting and allocation of collateral(2)	28			—		5		33
Total	$	499		$	552	$	283	$	1,334
Liabilities:
Interest rate and foreign exchange instruments	$	—		$	150	$	—	$	150
Commodity contracts not subject to rate recovery	—			34		—		34
Commodity contracts subject to rate recovery	2			5		99		106
Effect of netting and allocation of collateral(2)	(2		)	—		—		(2		)
Total	$	—		$	189	$	99	$	288

⁽¹⁾  Excludes cash balances and cash equivalents.

⁽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 March 31, 2019
	Level 1			Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	454		$	5	$	—	$	459
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies	39			9		—		48
Municipal bonds	—			279		—		279
Other securities	—			238		—		238
Total debt securities	39			526		—		565
Total nuclear decommissioning trusts(1)	493			531		—		1,024
Commodity contracts subject to rate recovery	—			1		271		272
Effect of netting and allocation of collateral(2)	20			—		5		25
Total	$	513		$	532	$	276	$	1,321
Liabilities:
Commodity contracts subject to rate recovery	$	6		$	—	$	89	$	95
Effect of netting and allocation of collateral(2)	(6		)	—		—		(6		)
Total	$	—		$	—	$	89	$	89
	Fair value at December 31, 2018
	Level 1			Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Equity securities	$	407		$	4	$	—	$	411
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies	43			10		—		53
Municipal bonds	—			269		—		269
Other securities	—			234		—		234
Total debt securities	43			513		—		556
Total nuclear decommissioning trusts(1)	450			517		—		967
Commodity contracts subject to rate recovery	1			6		278		285
Effect of netting and allocation of collateral(2)	23			—		5		28
Total	$	474		$	523	$	283	$	1,280
Liabilities:
Interest rate instruments	$	—		$	1	$	—	$	1
Commodity contracts subject to rate recovery	2			—		99		101
Effect of netting and allocation of collateral(2)	(2		)	—		—		(2		)
Total	$	—		$	1	$	99	$	100

⁽¹⁾  Excludes cash balances and cash equivalents.

⁽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 March 31, 2019
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	—	$	7	$	—	$	7
Effect of netting and allocation of collateral(1)	1		—		—		1
Total	$	1	$	7	$	—	$	8
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	4	$	—	$	4
Total	$	—	$	4	$	—	$	4
	Fair value at December 31, 2018
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	1	$	3	$	—	$	4
Effect of netting and allocation of collateral(1)	5		—		—		5
Total	$	6	$	3	$	—	$	9
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	5	$	—	$	5
Total	$	—	$	5	$	—	$	5

⁽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 Energy Consolidated and SDG&E.

LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)
	Three months ended March 31,
	2019			2018
Balance at January 1	$	179		$	(28	)
Realized and unrealized gains	5			4
Allocated transmission instruments	—			3
Settlements	(2		)	(19		)
Balance at March 31	$	182		$	(40	)
Change in unrealized gains (losses) relating to instruments still held at March 31	$	13		$	(8	)

⁽¹⁾ 

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

Schedule of Fair Value Inputs

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 were as follows:

LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS
Settlement year		Price per MWh					Weighted-average price per MWh
2019	$	23.25	to	$	81.75	$	42.49
2018		20.00	to		47.65		35.42

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
2019	$	(8.57	)	to	$	35.21	$	(2.94	)
2018	(7.25		)	to	11.99		0.09

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)
	March 31, 2019
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
Sempra Energy Consolidated:
Long-term amounts due from unconsolidated affiliates	$	668	$	—	$	689	$	—	$	689
Long-term amounts due to unconsolidated affiliates	38		—		37		—		37
Total long-term debt(1)(2)	20,814		—		20,598		248		20,846
SDG&E:
Total long-term debt(2)(3)	$	4,978	$	—	$	4,918	$	220	$	5,138
SoCalGas:
Total long-term debt(4)	$	3,459	$	—	$	3,595	$	—	$	3,595
	December 31, 2018
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
Sempra Energy Consolidated:
Long-term amounts due from unconsolidated affiliates	$	644	$	—	$	648	$	4	$	652
Long-term amounts due to unconsolidated affiliates	37		—		35		—		35
Total long-term debt(2)(5)	21,340		—		20,616		247		20,863
SDG&E:
Total long-term debt(6)	$	4,996	$	—	$	4,897	$	220	$	5,117
SoCalGas:
Total long-term debt(7)	$	3,459	$	—	$	3,505	$	—	$	3,505

⁽¹⁾  Before reductions of unamortized discount and debt issuance costs of $201 million and excluding finance lease obligations of $1,277 million.

⁽²⁾  Level 3 instruments includes $220 million at both March 31, 2019 and December 31, 2018 related to Otay Mesa VIE.

⁽³⁾  Before reductions of unamortized discount and debt issuance costs of $48 million and excluding finance lease obligations of $1,272 million.

⁽⁴⁾  Before reductions of unamortized discount and debt issuance costs of $32 million and excluding finance lease obligations of $5 million.

⁽⁵⁾  Before reductions of unamortized discount and debt issuance costs of $206 million and excluding build-to-suit and capital lease obligations of $1,413 million.

⁽⁶⁾  Before reductions of unamortized discount and debt issuance costs of $49 million and excluding capital lease obligations of $1,272 million.

⁽⁷⁾  Before reductions of unamortized discount and debt issuance costs of $32 million and excluding capital lease obligations of $3 million.

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SAN ONOFRE NUCLEAR GENERATING STATION (Tables)

3 Months Ended

Mar. 31, 2019

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 March 31, 2019:
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies(1)	$	48	$	—	$	—		$	48
Municipal bonds(2)	271		8		—			279
Other securities(3)	236		3		(1		)	238
Total debt securities	555		11		(1		)	565
Equity securities	166		299		(6		)	459
Cash and cash equivalents	13		—		—			13
Total	$	734	$	310	$	(7	)	$	1,037
At December 31, 2018:
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies	$	52	$	1	$	—		$	53
Municipal bonds	266		4		(1		)	269
Other securities	238		1		(5		)	234
Total debt securities	556		6		(6		)	556
Equity securities	168		253		(10		)	411
Cash and cash equivalents	7		—		—			7
Total	$	731	$	259	$	(16	)	$	974

⁽¹⁾  Maturity dates are 2019-2049.

⁽²⁾  Maturity dates are 2019-2056.

⁽³⁾  Maturity dates are 2019-2064.

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 March 31,
	2019			2018
Proceeds from sales	$	225		$	210
Gross realized gains	5			4
Gross realized losses	(2		)	(3		)

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COMMITMENTS AND CONTINGENCIES (Tables)

3 Months Ended

Mar. 31, 2019

Commitments and Contingencies Disclosure [Abstract]

Schedule of Leases Statement of Financial Position

Classification of ROU assets and lease liabilities and the weighted-average remaining lease term and discount rate associated with operating and finance leases are summarized in the table below.

LESSEE INFORMATION ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	March 31, 2019
	Sempra Energy Consolidated			SDG&E			SoCalGas
Right-of-use assets:
Operating leases:
Right-of-use assets	$	612		$	135		$	110
Finance leases:
Property, plant and equipment	1,322			1,315			7
Accumulated depreciation	(45		)	(43		)	(2		)
Property, plant and equipment, net	1,277			1,272			5
Total right-of-use assets	$	1,889		$	1,407		$	115
Lease liabilities:
Operating leases:
Other current liabilities	$	52		$	24		$	22
Deferred credits and other	455			110			88
	507			134			110
Finance leases:
Current portion of long-term debt and finance leases	21			18			3
Long-term debt and finance leases	1,256			1,254			2
	1,277			1,272			5
Total lease liabilities	$	1,784		$	1,406		$	115
Weighted-average remaining lease term (in years):
Operating leases	14			7			6
Finance leases	20			20			3
Weighted-average discount rate:
Operating leases	5.87		%	3.69		%	3.76		%
Finance leases	14.91		%	14.92		%	3.94		%

Schedule of Lease Cost

The components of lease costs were as follows:

LESSEE INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS(1)
(Dollars in millions)
	Three months ended March 31, 2019
	Sempra Energy Consolidated		SDG&E		SoCalGas
Operating lease costs	$	24	$	8	$	7
Finance lease costs:
Amortization of ROU assets	5		4		1
Interest on lease liabilities	47		47		—
Total finance lease costs	52		51		1
Short-term lease costs(2)	1		—		—
Variable lease costs(2)	92		90		2
Total lease costs	$	169	$	149	$	10

⁽¹⁾  Includes costs capitalized in PP&E.

⁽²⁾ 

Short-term leases with variable lease costs are recorded and presented as variable lease costs.

Schedule of Lease Cash Flow Activity [Table Text Block]

Cash paid for amounts included in the measurement of lease liabilities was as follows:

LESSEE INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in millions)
	Three months ended March 31, 2019
	Sempra Energy Consolidated		SDG&E		SoCalGas
Operating activities:
Cash paid for operating leases	$	39	$	8	$	7
Cash paid for finance leases	43		43		—
Financing activities:
Cash paid for finance leases	5		4		1
Increase in operating lease obligations for right-of-use assets	552		142		117
Increase in finance lease obligations for investment in PP&E	7		4		3

Schedule of Operating Lease Maturity Payments

The table below presents the future minimum lease payments under previous U.S. GAAP:

FUTURE MINIMUM LEASE PAYMENTS
(Dollars in millions)
	December 31, 2018
	Sempra Energy Consolidated							SDG&E					SoCalGas
	Build-to-suit lease		Operating leases		Capital leases			Operating leases		Capital leases			Operating leases		Capital leases
2019	$	10	$	77	$	215		$	23	$	212		$	26	$	3
2020	11		55		210			22		210			22		—
2021	11		53		211			22		211			21		—
2022	11		50		211			21		211			20		—
2023	11		42		211			17		211			16		—
Thereafter	217		253		3,196			48		3,196			28		—
Total undiscounted lease payments	$	271	$	530	4,254			$	153	4,251			$	133	3
Less: estimated executory costs					(480		)			(480		)			—
Less: imputed interest					(2,483		)			(2,483		)			—
Total future minimum lease payments					$	1,291				$	1,288				$	3

The table below presents the maturity analysis of our lease liabilities and reconciliation to the present value of lease liabilities:

LESSEE MATURITY ANALYSIS OF LIABILITIES
(Dollars in millions)
	March 31, 2019
	Sempra Energy Consolidated						SDG&E						SoCalGas
	Operating leases			Finance leases			Operating leases			Finance leases			Operating leases			Finance leases
2019 (excluding first three months of 2019)	$	60		$	146		$	24		$	143		$	20		$	3
2020	69			190			25			189			22			1
2021	65			188			24			188			20			—
2022	59			188			21			188			17			—
2023	50			188			17			188			13			—
Thereafter	479			2,806			42			2,805			31			1
Total undiscounted lease payments	782			3,706			153			3,701			123			5
Less: imputed interest	(275		)	(2,429		)	(19		)	(2,429		)	(13		)	—
Total lease liabilities	507			1,277			134			1,272			110			5
Less: current lease liabilities	(52		)	(21		)	(24		)	(18		)	(22		)	(3		)
Long-term lease liabilities	$	455		$	1,256		$	110		$	1,254		$	88		$	2

Schedule of Finance Lease Maturity Payments

The table below presents the future minimum lease payments under previous U.S. GAAP:

FUTURE MINIMUM LEASE PAYMENTS
(Dollars in millions)
	December 31, 2018
	Sempra Energy Consolidated							SDG&E					SoCalGas
	Build-to-suit lease		Operating leases		Capital leases			Operating leases		Capital leases			Operating leases		Capital leases
2019	$	10	$	77	$	215		$	23	$	212		$	26	$	3
2020	11		55		210			22		210			22		—
2021	11		53		211			22		211			21		—
2022	11		50		211			21		211			20		—
2023	11		42		211			17		211			16		—
Thereafter	217		253		3,196			48		3,196			28		—
Total undiscounted lease payments	$	271	$	530	4,254			$	153	4,251			$	133	3
Less: estimated executory costs					(480		)			(480		)			—
Less: imputed interest					(2,483		)			(2,483		)			—
Total future minimum lease payments					$	1,291				$	1,288				$	3

The table below presents the maturity analysis of our lease liabilities and reconciliation to the present value of lease liabilities:

LESSEE MATURITY ANALYSIS OF LIABILITIES
(Dollars in millions)
	March 31, 2019
	Sempra Energy Consolidated						SDG&E						SoCalGas
	Operating leases			Finance leases			Operating leases			Finance leases			Operating leases			Finance leases
2019 (excluding first three months of 2019)	$	60		$	146		$	24		$	143		$	20		$	3
2020	69			190			25			189			22			1
2021	65			188			24			188			20			—
2022	59			188			21			188			17			—
2023	50			188			17			188			13			—
Thereafter	479			2,806			42			2,805			31			1
Total undiscounted lease payments	782			3,706			153			3,701			123			5
Less: imputed interest	(275		)	(2,429		)	(19		)	(2,429		)	(13		)	—
Total lease liabilities	507			1,277			134			1,272			110			5
Less: current lease liabilities	(52		)	(21		)	(24		)	(18		)	(22		)	(3		)
Long-term lease liabilities	$	455		$	1,256		$	110		$	1,254		$	88		$	2

Schedule of Operating Lease Payments to Be Received

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

LESSOR INFORMATION – SEMPRA ENERGY
(Dollars in millions)
	March 31, 2019
Assets subject to operating leases:
Assets held for sale	$	148
Property, plant and equipment(1)	$	1,026
Accumulated depreciation	(151		)
Property, plant and equipment, net	$	875
Maturity analysis of operating lease payments:
2019 (excluding first three months of 2019)	$	151
2020	200
2021	200
2022	200
2023	200
Thereafter	2,619
Total undiscounted cash flows	$	3,570

⁽¹⁾   Included in Machinery and Equipment — Pipelines and Storage within the major functional categories of PP&E.

LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA ENERGY
(Dollars in millions)
	Three months ended March 31,
	2019		2018
Minimum lease payments	$	50	$	49
Variable lease payments	4		13
Total revenues from operating leases	$	54	$	62
Depreciation expense	$	9	$	17

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SEGMENT INFORMATION (Tables)

3 Months Ended

Mar. 31, 2019

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 March 31,
	2019			2018
REVENUES
SDG&E	$	1,145		$	1,055
SoCalGas	1,361			1,126
Sempra Mexico	383			308
Sempra Renewables	7			25
Sempra LNG	141			104
Adjustments and eliminations	—			(1		)
Intersegment revenues(1)	(139		)	(81		)
Total	$	2,898		$	2,536
INTEREST EXPENSE
SDG&E	$	103		$	52
SoCalGas	34			27
Sempra Mexico	30			30
Sempra Renewables	3			5
Sempra LNG	4			8
All other	109			112
Intercompany eliminations	(23		)	(28		)
Total	$	260		$	206
INTEREST INCOME
SDG&E	$	1		$	1
Sempra Mexico	19			15
Sempra Renewables	10			2
Sempra LNG	14			13
All other	1			16
Intercompany eliminations	(24		)	(18		)
Total	$	21		$	29
DEPRECIATION AND AMORTIZATION
SDG&E	$	186		$	166
SoCalGas	147			135
Sempra Mexico	44			43
Sempra Renewables	—			13
Sempra LNG	2			11
All other	4			4
Total	$	383		$	372
INCOME TAX EXPENSE (BENEFIT)
SDG&E	$	5		$	56
SoCalGas	19			59
Sempra Mexico	72			155
Sempra Renewables	(10		)	(7		)
Sempra LNG	4			12
All other	(48		)	(33		)
Total	$	42		$	242
EQUITY EARNINGS (LOSSES)
Equity earnings before income tax:
Sempra Renewables	$	3		$	5
Sempra LNG	2			—
	5			5
Equity earnings (losses) net of income tax:
Sempra Texas Utility	94			15
Sempra Mexico	2			(41		)
	96			(26		)
Total	$	101		$	(21	)

SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended March 31,
	2019			2018
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E	$	176		$	170
SoCalGas	264			225
Sempra Texas Utility	94			15
Sempra Mexico	57			20
Sempra Renewables	13			21
Sempra LNG	5			(16		)
Discontinued operations	(51		)	21
All other	(117		)	(109		)
Total	$	441		$	347
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E	$	356		$	475
SoCalGas	324			403
Sempra Mexico	85			59
Sempra Renewables	—			31
Sempra LNG	18			6
All other	—			5
Total	$	783		$	979
	March 31, 2019			December 31, 2018
ASSETS
SDG&E	$	19,558		$	19,225
SoCalGas	15,904			15,389
Sempra Texas Utility	9,748			9,652
Sempra Mexico	9,382			9,165
Sempra Renewables	1,310			2,549
Sempra LNG	3,731			4,060
Discontinued operations	3,845			3,718
All other	1,135			1,070
Intersegment receivables	(2,995		)	(4,190		)
Total	$	61,618		$	60,638
EQUITY METHOD AND OTHER INVESTMENTS
Sempra Texas Utility	$	9,748		$	9,652
Sempra Mexico	737			747
Sempra Renewables	290			291
Sempra LNG	1,255			1,271
All other	8			11
Total	$	12,038		$	11,972

⁽¹⁾ 

Revenues for reportable segments include intersegment revenues of $1 million, $17 million, $28 million and $93 million for the three months ended March 31, 2019 and $1 million, $17 million, $29 million and $34 million for the three months ended March 31, 2018, for SDG&E, SoCalGas, Sempra Mexico and Sempra LNG, respectively.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA PRINCIPLES OF CONSOLIDATION (Details)	3 Months Ended
	Mar. 31, 2019 segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of Reportable Segments	6

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - REGULATED OPERATIONS (Details)	Mar. 31, 2019
Oncor Electric Delivery Company LLC. [Member] | Sempra Texas Utility [Member]
Regulatory Assets [Line Items]
Ownership Percentage	80.25%

XML

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Cash and Cash Equivalents [Line Items]
Cash and cash equivalents	$ 78	$ 102	[1]
Restricted cash, current	41	35	[1]
Restricted cash, noncurrent	21	21	[1]
Cash and cash equivalents	67	88
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	207	246
San Diego Gas and Electric Company [Member]
Cash and Cash Equivalents [Line Items]
Cash and cash equivalents	10	8	[1]
Restricted cash, current	21	11	[1]
Restricted cash, noncurrent	18	18	[1]
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$ 49	$ 37

[1] Derived from audited financial statements.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - INVENTORIES (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Inventory [Line Items]
Natural gas	$ 21	$ 95
LNG	7	4
Materials and supplies	161	159
Inventory	189	258	[1]
SDG&E [Member]
Inventory [Line Items]
Natural gas	0	0
LNG	0	0
Materials and supplies	99	102
Inventory	99	102
SoCalGas [Member]
Inventory [Line Items]
Natural gas	12	92
LNG	0	0
Materials and supplies	46	42
Inventory	58	134
Sempra Mexico [Member]
Inventory [Line Items]
Natural gas	0	0
LNG	7	4
Materials and supplies	16	15
Inventory	23	19
Sempra LNG [Member]
Inventory [Line Items]
Natural gas	9	3
LNG	0	0
Materials and supplies	0	0
Inventory	$ 9	$ 3

[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
	Mar. 31, 2019	Mar. 31, 2018
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	$ 47	$ 49
San Diego Gas and Electric Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	17	24
Southern California Gas Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	$ 11	$ 13

XML

GENERAL INFORMATION AND OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITIES (Details) $ in Millions		3 Months Ended
	Mar. 09, 2018	Mar. 31, 2019 USD ($) MW	Mar. 31, 2018 USD ($)	Dec. 31, 2018 USD ($)
Variable Interest Entities [Line Items]
Equity method investment		$ 9,748		$ 9,652	[1]
Energy-related businesses		383	$ 346
Operation and maintenance		(832)	(741)
Depreciation and amortization		(383)	(372)
Interest expense		(260)	(206)
Income from continuing operations before income taxes and equity earnings (losses) of unconsolidated entities		501	593
Income tax expense		(42)	(242)
Net income		518	358
(Earnings) losses attributable to noncontrolling interest		(41)	17
Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Assets of VIEs		502		286
Sempra Texas Utility [Member] | Oncor Holdings [Member]
Variable Interest Entities [Line Items]
Equity method investment		9,748		9,652
Commitment to invest		1,025
Management Agreement Termination Fee		40
Sempra Renewables [Member] | Tax Equity Investors [Member]
Variable Interest Entities [Line Items]
Equity		161		158
Energy-related businesses		6	17
Operation and maintenance		(2)	(4)
Depreciation and amortization		(3)	(11)
Income from continuing operations before income taxes and equity earnings (losses) of unconsolidated entities		1	2
Income tax expense		1	(5)
Net income		2	(3)
(Earnings) losses attributable to noncontrolling interest		(3)	21
Earnings attributable to common shares		(1)	18
Sempra Natural Gas [Member] | Cameron LNG Holdings [Member]
Variable Interest Entities [Line Items]
Equity method investment		1,255		1,271
San Diego Gas and Electric Company [Member]
Variable Interest Entities [Line Items]
Operation and maintenance		286	248
Depreciation and amortization		186	166
Operating income		262	248
Interest expense		(103)	(52)
Income from continuing operations before income taxes and equity earnings (losses) of unconsolidated entities		182	225
Income tax expense		(5)	(56)
Net income		177	169
(Earnings) losses attributable to noncontrolling interest		$ (1)	1
San Diego Gas and Electric Company [Member] | Otay Mesa VIE [Member]
Variable Interest Entities [Line Items]
Generating capacity | MW		605
Conditional purchase obligation		$ 280
Equity of variable interest entity		102		$ 100
Secured debt of variable interest entity		220
Cost of electric fuel and purchased power		(16)	(16)
Operation and maintenance		4	4
Depreciation and amortization		7	8
Total operating expenses		(5)	(4)
Operating income		5	4
Interest expense		(4)	(5)
Net income		1	(1)
(Earnings) losses attributable to noncontrolling interest		(1)	1
Earnings attributable to common shares		$ 0	$ 0
Oncor Holdings [Member] | Sempra Texas Holdings Corp [Member] | Sempra Texas Intermediate Holding Company LLC [Member]
Variable Interest Entities [Line Items]
Ownership percentage in consolidated entity	100.00%
Oncor Electric Delivery Company LLC. [Member]
Variable Interest Entities [Line Items]
Acquired percentage interest	80.25%
Oncor Electric Delivery Company LLC. [Member] | Sempra Texas Holdings Corp [Member]
Variable Interest Entities [Line Items]
Acquired percentage interest	80.03%

[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
	Mar. 31, 2019	Mar. 31, 2018
Pension benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 27	$ 33
Interest cost	35	35
Expected return on assets	(36)	(42)
Prior service cost (credit)	3	3
Actuarial loss (gain)	14	9
Settlement charges	0	14
Net periodic benefit cost (credit)	43	52
Regulatory adjustment	(36)	(45)
Total expense recognized	7	7
Contributions by employer	9
Expected contributions in current fiscal year	234
Pension benefits [Member] | San Diego Gas and Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	8	8
Interest cost	9	9
Expected return on assets	(11)	(13)
Prior service cost (credit)	1	0
Actuarial loss (gain)	4	1
Settlement charges	0	14
Net periodic benefit cost (credit)	11	19
Regulatory adjustment	(11)	(19)
Total expense recognized	0	0
Contributions by employer	0
Expected contributions in current fiscal year	40
Pension benefits [Member] | Southern California Gas Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	16	22
Interest cost	23	23
Expected return on assets	(24)	(26)
Prior service cost (credit)	2	2
Actuarial loss (gain)	9	6
Net periodic benefit cost (credit)	26	27
Regulatory adjustment	(25)	(26)
Total expense recognized	1	1
Contributions by employer	1
Expected contributions in current fiscal year	118
Other postretirement benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	4	6
Interest cost	9	9
Expected return on assets	(18)	(18)
Prior service cost (credit)	0	0
Actuarial loss (gain)	(2)	(1)
Settlement charges	0	0
Net periodic benefit cost (credit)	(7)	(4)
Regulatory adjustment	7	4
Total expense recognized	0	0
Contributions by employer	2
Expected contributions in current fiscal year	9
Other postretirement benefits [Member] | San Diego Gas and Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	1	1
Interest cost	2	2
Expected return on assets	(3)	(3)
Prior service cost (credit)	1	1
Actuarial loss (gain)	(1)	(1)
Settlement charges	0	0
Net periodic benefit cost (credit)	0	0
Regulatory adjustment	0	0
Total expense recognized	0	0
Contributions by employer	0
Expected contributions in current fiscal year	0
Other postretirement benefits [Member] | Southern California Gas Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	3	4
Interest cost	7	7
Expected return on assets	(14)	(14)
Prior service cost (credit)	(1)	(1)
Actuarial loss (gain)	(2)	0
Net periodic benefit cost (credit)	(7)	(4)
Regulatory adjustment	7	4
Total expense recognized	0	$ 0
Contributions by employer	0
Expected contributions in current fiscal year	$ 1

XML

GENERAL INFORMATION AND OTHER FINANCIAL DATA - RABBI TRUST (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Rabbi trust	$ 413	$ 416	[1]

[1] Derived from audited financial statements.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Income from continuing operations, net of income tax	$ 560	$ 330
(Earnings) losses attributable to noncontrolling interests	(32)	24
Mandatory convertible preferred stock dividends	(36)	(28)
Earnings from continuing operations attributable to common shares	492	326
(Loss) income from discontinued operations, net of income tax	(42)	28
(Losses) earnings from discontinued operations attributable to common shares	(51)	21
Earnings attributable to common shares	$ 441	$ 347
Weighted-average common shares outstanding for basic EPS	274,674,000	257,932,000
Dilutive effect of stock options, RSAs and RSUs (in shares)	969,000	933,000
Dilutive effect of common stock forward shares (in shares)	1,585,000	625,000
Weighted-average common shares outstanding for diluted EPS (in shares)	277,228,000	259,490,000
Earnings from continuing operations attributable to common shares (in usd per share)	$ 1.79	$ 1.26
(Losses) earnings from discontinued operations attributable to common shares (in usd per share)	(0.19)	0.08
Earnings attributable to common shares (in usd per share)	1.60	1.34
Earnings from continuing operations attributable to common shares (in usd per share)	1.78	1.25
(Losses) earnings from discontinued operations attributable to common shares (in usd per share)	(0.19)	0.08
Earnings from continuing operations attributable to common shares (n usd per share)	$ 1.59	$ 1.33
Vested RSUs included in basic WASO (in shares)	613,000	628,000
Non-qualified stock options granted (in shares)	261,075
Convertible Preferred Stock [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)	18,601,085	15,592,572
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)	316,385	80,449
Employee Stock Option [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Exercisable period	3 years
Performance-based RSUs [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)	384,373
Service-based RSUs [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)	214,502

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018	Dec. 31, 2017
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
AOCI, beginning balance	[1]	$ 17,138
Cumulative-effect adjustment from change in accounting principle				$ 15	$ (1)
AOCI, ending balance		17,346
Foreign currency translation adjustments [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
AOCI, beginning balance		(564)	$ (420)
Cumulative-effect adjustment from change in accounting principle				0	0
OCI before reclassifications		32	24
Amounts reclassified from AOCI		0	0
Net OCI		32	24
AOCI, ending balance		(532)	(396)
Financial instruments [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
AOCI, beginning balance		(82)	(122)
Cumulative-effect adjustment from change in accounting principle				(25)	(3)
OCI before reclassifications		(45)	66
Amounts reclassified from AOCI		(1)	(8)
Net OCI		(46)	58
AOCI, ending balance		(153)	(67)
Pension and other postretirement benefits [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
AOCI, beginning balance		(118)	(84)
Cumulative-effect adjustment from change in accounting principle				(17)	0
OCI before reclassifications		1	0
Amounts reclassified from AOCI		2	2
Net OCI		3	2
AOCI, ending balance		(132)	(82)
Total accumulated other comprehensive income (loss) [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
AOCI, beginning balance		(764)	(626)
Cumulative-effect adjustment from change in accounting principle				(42)	$ (3)
OCI before reclassifications		(12)	90
Amounts reclassified from AOCI		1	(6)
Net OCI		(11)	84
AOCI, ending balance		(817)	(545)
San Diego Gas and Electric Company [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
AOCI, beginning balance	[1]	6,015
Cumulative-effect adjustment from change in accounting principle				0
AOCI, ending balance		6,191
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]
AOCI, beginning balance		(10)	(8)
Cumulative-effect adjustment from change in accounting principle				(2)
AOCI, ending balance		(12)	(8)
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]
AOCI, beginning balance		(10)	(8)
Cumulative-effect adjustment from change in accounting principle				(2)
AOCI, ending balance		(12)	(8)
Southern California Gas Company [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
AOCI, beginning balance	[1]	4,258
Cumulative-effect adjustment from change in accounting principle				(2)
AOCI, ending balance		4,520
Southern California Gas Company [Member] | Financial instruments [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
AOCI, beginning balance		(12)	(13)
Cumulative-effect adjustment from change in accounting principle				(2)
AOCI, ending balance		(14)	(13)
Southern California Gas Company [Member] | Pension and other postretirement benefits [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
AOCI, beginning balance		(8)	(8)
Cumulative-effect adjustment from change in accounting principle				(2)
AOCI, ending balance		(10)	(8)
Southern California Gas Company [Member] | Total accumulated other comprehensive income (loss) [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
AOCI, beginning balance		(20)	(21)
Cumulative-effect adjustment from change in accounting principle				$ (4)
AOCI, ending balance		$ (24)	$ (21)

[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
	Mar. 31, 2019	Mar. 31, 2018
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	$ (260)	$ (206)
Other income, net	(82)	(152)
Equity earnings (losses)	101	(21)
Energy-related businesses	383	346
Income from continuing operations before income taxes and equity earnings (losses) of unconsolidated entities	501	593
Income tax benefit (expense)	42	242
Net income	(518)	(358)
Earnings attributable to noncontrolling interest	(41)	17
Earnings attributable to common shares	441	347
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	1	(6)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Gains (Losses) on Cash Flow hedges [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income from continuing operations before income taxes and equity earnings (losses) of unconsolidated entities	0	(16)
Income tax benefit (expense)	0	(3)
Net income	0	13
Reclassification out of Accumulated Other Comprehensive Income [Member] | Gains (Losses) on Cash Flow hedges [Member] | Interest rate and foreign exchange instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	1	(2)
Other income, net	(3)	(18)
Equity earnings (losses)	1	4
Reclassification out of Accumulated Other Comprehensive Income [Member] | Gains (Losses) on Cash Flow hedges [Member] | Foreign exchange instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Energy-related businesses	1	0
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	(1)	5
Reclassification out of Accumulated Other Comprehensive Income [Member] | Gains (Losses) on Cash Flow hedges Attributable to Parent [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	(1)	(8)
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, net	2	3
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, net	1	0
Reclassification out of Accumulated Other Comprehensive Income [Member] | Pension and Other Postretirement Benefits [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income from continuing operations before income taxes and equity earnings (losses) of unconsolidated entities	3	3
Income tax benefit (expense)	(1)	(1)
Net income	2	2
San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(103)	(52)
Other income, net	(22)	(28)
Income from continuing operations before income taxes and equity earnings (losses) of unconsolidated entities	182	225
Income tax benefit (expense)	5	56
Net income	(177)	(169)
Earnings attributable to noncontrolling interest	(1)	1
Earnings attributable to common shares	176	170
San Diego Gas and Electric Company [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	0	0
San Diego Gas and Electric Company [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Gains (Losses) on Cash Flow hedges [Member] | Interest rate instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	1	3
San Diego Gas and Electric Company [Member] | 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	$ (1)	$ (3)

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - SHAREHOLDER'S EQUITY AND NONCONTROLLING INTEREST (Details) - USD ($) $ / shares in Units, $ in Millions		1 Months Ended		3 Months Ended
	May 07, 2019	Jul. 31, 2018	Jan. 31, 2018	Mar. 31, 2019	Jun. 30, 2018	Mar. 31, 2018	Jul. 13, 2018	Jan. 09, 2018
Subsidiary, Sale of Stock [Line Items]
Proceeds from issuance				$ 0		$ 1,693
Proceeds from issuance				$ 11		$ 1,278
Public Offering [Member] | Common Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Shares issued		11,212,500	26,869,158
Shares issued (in usd per share)		$ 113.75	$ 107.00
Shares issued net of underwriting discount (in usd per share)		$ 111.87	$ 105.07
Proceeds from issuance			$ 1,270
Over-Allotment Option [Member] | Common Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Proceeds from issuance		$ 164	$ 367
Settlement of Forward Sale Contracts [Member] | Common Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Proceeds from issuance					$ 800
Sempra Energy [Member] | Series A Preferred Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Shares issued			17,250,000
Proceeds from issuance			$ 1,690
Liquidation price (in usd per share)								$ 100.00
Sempra Energy [Member] | Series B Preferred Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Shares issued		5,750,000
Proceeds from issuance		$ 565
Liquidation price (in usd per share)							$ 100.00
Subsequent Event [Member] | Settlement of Forward Sale Contracts [Member] | Common Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Shares issuable under forward contracts	16,906,185

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - OTHER NONCONTROLLING INTERESTS (Details) - USD ($) $ in Millions		3 Months Ended
	Feb. 07, 2019	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Noncontrolling Interest [Line Items]
Repurchases of common stock		$ 14	$ 19
Other noncontrolling interests		$ 2,104		$ 2,090	[1]
Infraestructura Energética Nova [Member]
Noncontrolling Interest [Line Items]
Common stock repurchased (in shares)		1,600,000
Repurchases of common stock		$ 6
San Diego Gas and Electric Company [Member] | Otay Mesa VIE [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests		100.00%		100.00%
Other noncontrolling interests		$ 102		$ 100
Sempra Mexico [Member] | IEnova [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests		33.40%		33.50%
Other noncontrolling interests		$ 1,611		$ 1,592
Sempra Mexico [Member] | Ownership Interests Held By Others, IEnova, Subsidiary One [Member]
Noncontrolling Interest [Line Items]
Other noncontrolling interests		$ 13		$ 13
Sempra Mexico [Member] | Ownership Interests Held By Others, IEnova, Subsidiary One [Member] | Minimum [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests		10.00%		10.00%
Sempra Mexico [Member] | Ownership Interests Held By Others, IEnova, Subsidiary One [Member] | Maximum [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests		47.60%		49.00%
Sempra Renewables [Member] | Tax equity arrangement – wind [Member]
Noncontrolling Interest [Line Items]
Other noncontrolling interests		$ 161		$ 158
Sempra Renewables [Member] | PXISE Energy Solutions LLC [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests		11.10%		11.10%
Other noncontrolling interests		$ 0		$ 1
Sempra LNG [Member] | Bay Gas Storage Company, Ltd. [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests		0.00%		9.10%
Other noncontrolling interests		$ 0		$ 18
Sempra LNG [Member] | Liberty Gas Storage, LLC [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests		24.60%		24.60%
Other noncontrolling interests		$ (12)		$ (12)
Sempra South American Utilities [Member] | Chilquinta Energía subsidiaries [Member]
Noncontrolling Interest [Line Items]
Other noncontrolling interests		$ 24		$ 23
Sempra South American Utilities [Member] | Chilquinta Energía subsidiaries [Member] | Minimum [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests		19.70%		19.70%
Sempra South American Utilities [Member] | Chilquinta Energía subsidiaries [Member] | Maximum [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests		43.40%		43.40%
Sempra South American Utilities [Member] | Luz del Sur [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests		16.40%		16.40%
Other noncontrolling interests		$ 201		$ 193
Sempra South American Utilities [Member] | Tecsur [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests		9.80%		9.80%
Other noncontrolling interests		$ 4		$ 4
Infraestructura Energética Nova [Member]
Noncontrolling Interest [Line Items]
Ownership interest		66.60%		66.50%
Bay Gas [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Payment to acquire remaining interest in Bay Gas	$ 20
Sale of interest	100.00%

[1] Derived from audited financial statements.

XML

GENERAL INFORMATION AND OTHER FINANCIAL DATA - DUE TO DUE FROM AFFILIATES (Details) $ in Billions	3 Months Ended	12 Months Ended
	Mar. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)		Mar. 31, 2019 MXN ($)
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	$ 50,000,000	$ 37,000,000	[1]
Due from unconsolidated affiliates - noncurrent	668,000,000	644,000,000	[1]
Due to unconsolidated affiliates, current	(10,000,000)	(10,000,000)	[1]
Due to unconsolidated affiliates - noncurrent	$ (38,000,000)	$ (37,000,000)	[1]
ESJ joint venture [Member] | LIBOR [Member]
Related Party Transaction [Line Items]
Spread on variable rate	6.375%	6.375%
Interest rate on due from affiliate, noncurrent		8.89%
TAG Pipeline Norte [Member]
Related Party Transaction [Line Items]
Interest rate on due from affiliate, noncurrent	5.54%
TAG Pipeline Norte [Member] | LIBOR [Member]
Related Party Transaction [Line Items]
Spread on variable rate	2.90%	2.90%
California Utilities Combined [Member]
Related Party Transaction [Line Items]
Maximum borrowing capacity	$ 1,000,000,000
San Diego Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current	(63,000,000)	$ (61,000,000)	[1]
Maximum borrowing capacity	750,000,000
San Diego Gas and Electric Company [Member] | Due to/from Sempra Energy [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current	(37,000,000)	(43,000,000)
Income taxes due (to) from Sempra Energy	(29,000,000)	5,000,000
San Diego Gas and Electric Company [Member] | Due to/from SoCalGas [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current	(14,000,000)	(6,000,000)
San Diego Gas and Electric Company [Member] | Due to/from Other affiliates [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current	(12,000,000)	(12,000,000)
Southern California Gas Company [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	15,000,000	7,000,000	[1]
Due to unconsolidated affiliates, current	(42,000,000)	(34,000,000)	[1]
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	(39,000,000)	(34,000,000)
Income taxes due (to) from Sempra Energy	(88,000,000)	(4,000,000)
Southern California Gas Company [Member] | Due to/from Other affiliates [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	1,000,000	1,000,000
Due to unconsolidated affiliates, current	(3,000,000)	0
Southern California Gas Company [Member] | Due to/from SDG&E
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	14,000,000	6,000,000
Sempra Mexico [Member] | IMG [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	668,000,000	$ 641,000,000
Maximum borrowing capacity	$ 729,000,000			$ 14.2
Sempra Mexico [Member] | IMG [Member] | Interbank Equilibrium Rate [Member]
Related Party Transaction [Line Items]
Spread on variable rate	2.20%	2.20%
Interest rate on due from affiliate, noncurrent	10.69%
Sempra Mexico [Member] | ESJ joint venture [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	$ 0	$ 3,000,000
Sempra Mexico [Member] | TAG Pipeline Norte [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - noncurrent	$ 38,000,000	$ 37,000,000

[1] Derived from audited financial statements.

XML

GENERAL INFORMATION AND OTHER FINANCIAL DATA - AFFILIATES REVENUE AND COST OF SALES (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Related Party Transaction [Line Items]
Revenue from related parties	$ 14	$ 16
Costs of sales to related parties	14	12
San Diego Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Revenue from related parties	1	2
Costs of sales to related parties	20	19
Southern California Gas Company [Member]
Related Party Transaction [Line Items]
Revenue from related parties	17	17
Costs of sales to related parties	$ 4	$ 0

XML

GENERAL INFORMATION AND OTHER FINANCIAL DATA - OTHER INCOME (EXPENSE), NET (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended
	Jan. 31, 2019	Mar. 31, 2019	Mar. 31, 2018
Other Income [Line Items]
Allowance for equity funds used during construction		$ 21	$ 27
Investment gains (losses)		26	(1)
Gains on interest rate and foreign exchange instruments, net		13	62
Foreign currency transaction gains, net		7	30
Non-service component of net periodic benefit credit		24	32
Penalties related to billing practices OII		(8)	0
Interest on regulatory balancing accounts, net		(1)	0
Sundry, net		0	2
Total		82	152
San Diego Gas and Electric Company [Member]
Other Income [Line Items]
Allowance for equity funds used during construction		12	18
Non-service component of net periodic benefit credit		9	9
Sundry, net		1	1
Total		22	28
Southern California Gas Company [Member]
Other Income [Line Items]
Allowance for equity funds used during construction		8	9
Non-service component of net periodic benefit credit		18	25
Penalties related to billing practices OII	$ (8)	(8)	0
Interest on regulatory balancing accounts, net		(1)	0
Sundry, net		(1)	(1)
Total		16	33
Sempra Mexico [Member] | IMG [Member]
Other Income [Line Items]
Foreign currency gain		$ 10	$ 39

XML

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INCOME TAXES (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income Tax Expense (Benefit)	$ 42	$ 242
Income from continuing operations before income taxes and equity earnings (losses) of unconsolidated entities	501	593
Equity (losses) earnings, before income tax	5	5
Pretax income	$ 506	$ 598
Effective income tax rate	8.00%	40.00%
Income tax expense related to outside basis differences existing prior to the January 25, 2019 approval of our plan to sell our South American businesses	$ 103
Income tax expense related to the increase in outside basis differences from 2019 earnings since January 25, 2019	13
San Diego Gas and Electric Company [Member]
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Tax Cuts and Jobs Act of 2017, Change in Tax Rate, Deferred Tax Assets and Liabilities, Income Tax (Expense) Benefit, Recognized in Period	31
Income Tax Expense (Benefit)	5	$ 56
Income from continuing operations before income taxes and equity earnings (losses) of unconsolidated entities	182	225
Pretax income	$ 182	$ 225
Effective income tax rate	3.00%	25.00%
Southern California Gas Company [Member]
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Tax Cuts and Jobs Act of 2017, Change in Tax Rate, Deferred Tax Assets and Liabilities, Income Tax (Expense) Benefit, Recognized in Period	$ 35
Income Tax Expense (Benefit)	19	$ 59
Income from continuing operations before income taxes and equity earnings (losses) of unconsolidated entities	283	284
Pretax income	$ 283	$ 284
Effective income tax rate	7.00%	21.00%

XML

NEW ACCOUNTING STANDARDS (Details) - USD ($) $ in Millions	Mar. 31, 2019	Jan. 01, 2019	Dec. 31, 2018	[1]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Sundry	$ 262		$ 249
Property, plant and equipment, net	34,698		34,439
Right-of-use assets – operating leases	612
Deferred Income Tax Assets, Net	139		141
Deferred income tax assets	2,622		2,321
Other current liabilities	993		935
Deferred credits and other	1,949		1,493
Retained earnings	10,337		10,104
Regulatory liabilities	3,996		4,016
Accumulated other comprehensive income (loss)	(817)		(764)
Accounting Standards Update 2016-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Sundry		$ (71)
Property, plant and equipment, net		(147)
Right-of-use assets – operating leases		603
Deferred Income Tax Assets, Net		(3)
Other current liabilities		80
Long-term debt		(138)
Deferred credits and other		436
Retained earnings		17
Accounting Standards Update 2018-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Retained earnings		40
Regulatory liabilities		2
Accumulated other comprehensive income (loss)		42
San Diego Gas and Electric Company [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Sundry	26		5
Property, plant and equipment, net	16,464		16,310
Right-of-use assets – operating leases	135
Deferred income tax assets	1,653		1,616
Other current liabilities	280		141
Deferred credits and other	610		488
Retained earnings	4,865		4,687
Regulatory liabilities	2,470		2,404
Accumulated other comprehensive income (loss)	(12)		(10)
San Diego Gas and Electric Company [Member] | Accounting Standards Update 2016-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Sundry		0
Property, plant and equipment, net		0
Right-of-use assets – operating leases		130
Deferred Tax Assets, Net		0
Other current liabilities		20
Long-term debt		0
Deferred credits and other		110
Retained earnings		0
San Diego Gas and Electric Company [Member] | Accounting Standards Update 2018-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Retained earnings		2
Accumulated other comprehensive income (loss)		2
Southern California Gas Company [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Sundry	39		31
Property, plant and equipment, net	12,581		12,439
Right-of-use assets – operating leases	110
Deferred income tax assets	1,204		1,177
Other current liabilities	333		217
Deferred credits and other	422		330
Retained earnings	3,656		3,390
Regulatory liabilities	1,526		1,612
Accumulated other comprehensive income (loss)	$ (24)		$ (20)
Southern California Gas Company [Member] | Accounting Standards Update 2016-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Sundry		0
Property, plant and equipment, net		0
Right-of-use assets – operating leases		116
Deferred Tax Assets, Net		0
Other current liabilities		23
Long-term debt		0
Deferred credits and other		93
Retained earnings		0
Southern California Gas Company [Member] | Accounting Standards Update 2018-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Retained earnings		2
Regulatory liabilities		2
Accumulated other comprehensive income (loss)		4
Disposal Group Held-for-sale [Member] | Accounting Standards Update 2016-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Assets Held-for-sale, Not Part of Disposal Group, Current		13
Disposal Group Held-for-sale [Member] | San Diego Gas and Electric Company [Member] | Accounting Standards Update 2016-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Assets Held-for-sale, Not Part of Disposal Group, Current		0
Disposal Group Held-for-sale [Member] | Southern California Gas Company [Member] | Accounting Standards Update 2016-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Assets Held-for-sale, Not Part of Disposal Group, Current		$ 0

[1] Derived from audited financial statements.

XML

REVENUES - DISAGGREGATION OF REVENUE (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 3,043	$ 2,471
Utilities regulatory revenues	(258)	(31)
Other revenues	113	96
Total revenues	2,898	2,536
Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,773	2,221
Midstream service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	179	176
Renewables service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	24	33
Other service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	67	41
Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,087	1,034
Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,956	1,437
Operating Segments [Member] | San Diego Gas and Electric Company [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,236	1,131
Utilities regulatory revenues	(91)	(76)
Other revenues	0	0
Total revenues	1,145	1,055
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,236	1,131
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Midstream service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Renewables service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Other service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	997	963
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	239	168
Operating Segments [Member] | Southern California Gas Company [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,528	1,081
Utilities regulatory revenues	(167)	45
Other revenues	0	0
Total revenues	1,361	1,126
Operating Segments [Member] | Southern California Gas Company [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,528	1,081
Operating Segments [Member] | Southern California Gas Company [Member] | Midstream service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments [Member] | Southern California Gas Company [Member] | Renewables service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments [Member] | Southern California Gas Company [Member] | Other service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments [Member] | Southern California Gas Company [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments [Member] | Southern California Gas Company [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,528	1,081
Operating Segments [Member] | Sempra Mexico [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	284	234
Utilities regulatory revenues	0	0
Other revenues	99	74
Total revenues	383	308
Operating Segments [Member] | Sempra Mexico [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	27	28
Operating Segments [Member] | Sempra Mexico [Member] | Midstream service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	171	143
Operating Segments [Member] | Sempra Mexico [Member] | Renewables service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	20	22
Operating Segments [Member] | Sempra Mexico [Member] | Other service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	66	41
Operating Segments [Member] | Sempra Mexico [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	86	62
Operating Segments [Member] | Sempra Mexico [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	198	172
Operating Segments [Member] | Sempra Renewables [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4	11
Utilities regulatory revenues	0	0
Other revenues	3	14
Total revenues	7	25
Operating Segments [Member] | Sempra Renewables [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments [Member] | Sempra Renewables [Member] | Midstream service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments [Member] | Sempra Renewables [Member] | Renewables service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4	11
Operating Segments [Member] | Sempra Renewables [Member] | Other service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments [Member] | Sempra Renewables [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4	11
Operating Segments [Member] | Sempra Renewables [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments [Member] | Sempra LNG [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	68	57
Utilities regulatory revenues	0	0
Other revenues	73	47
Total revenues	141	104
Operating Segments [Member] | Sempra LNG [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments [Member] | Sempra LNG [Member] | Midstream service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	67	54
Operating Segments [Member] | Sempra LNG [Member] | Renewables service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	1
Operating Segments [Member] | Sempra LNG [Member] | Other service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1	2
Operating Segments [Member] | Sempra LNG [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1	2
Operating Segments [Member] | Sempra LNG [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	67	55
Consolidating Adjustments [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(77)	(43)
Utilities regulatory revenues	0	0
Other revenues	(62)	(39)
Total revenues	(139)	(82)
Consolidating Adjustments [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(18)	(19)
Consolidating Adjustments [Member] | Midstream service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(59)	(21)
Consolidating Adjustments [Member] | Renewables service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	(1)
Consolidating Adjustments [Member] | Other service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	(2)
Consolidating Adjustments [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(1)	(4)
Consolidating Adjustments [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ (76)	$ (39)

XML

REVENUES - PERFORMANCE OBLIGATIONS (Details) $ in Millions	Mar. 31, 2019 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 384
Revenues to be recognized, period of recognition	9 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 512
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 513
Revenues to be recognized, period of recognition	1 year
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	$ 515
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	$ 509
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	$ 2,784
Revenues to be recognized, period of recognition
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 5,217
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 2
Revenues to be recognized, period of recognition	9 months
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 3
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]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 3
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]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 3
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	$ 3
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	$ 52
Revenues to be recognized, period of recognition
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 66

XML

REVENUES - CONTRACT LIABILITIES (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Contract with Customer, Liability [Roll Forward]
Contract liabilities, opening balance	$ (70)	$ 0
Adoption of ASC 606 adjustment		(61)
Revenue from performance obligations satisfied during reporting period	1	5
Payments received in advance	(2)	(7)
Contract liabilities, closing balance	(71)	(63)
Other Current Liabilities [Member]
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	0
Deferred Credits and Other [Member]
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(71)
San Diego Gas and Electric Company [Member]
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	0	0
Southern California Gas Company [Member]
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	$ 0	$ 0

XML

REVENUES - RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 1,166	$ 1,127
Accounts receivable – trade, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1,145	1,106
Accounts receivable – other, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	14	11
Due from unconsolidated affiliates – current [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	6	4
Assets held-for-sale [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1	6
San Diego Gas and Electric Company [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	405	377
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	390	368
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	12	6
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	3
Southern California Gas Company [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	676	639
Southern California Gas Company [Member] | Accounts receivable – trade, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	674	634
Southern California Gas Company [Member] | Accounts receivable – other, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 2	$ 5

XML

REGULATORY MATTERS - REGULATORY ACCOUNTS (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Net Regulatory Assets (Liabilities) Sempra Energy Consolidated [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ (2,594)	$ (2,394)
San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	84	78
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)	(144)	(150)
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)	(171)	(236)
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)	190	186
San Diego Gas and Electric Company [Member] | Removal obligations [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(1,946)	(1,848)
San Diego Gas and Electric Company [Member] | Unamortized loss on reacquired debt [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	6	7
San Diego Gas and Electric Company [Member] | Environmental costs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	27	28
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	120
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)	60	(8)
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)	13	45
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)	77	70
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)	(80)	(62)
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)	67	145
San Diego Gas and Electric Company [Member] | Other regulatory (liabilities) assets [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(199)	(177)
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)	(1,979)	(1,880)
Southern California Gas Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	405	185
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)	(248)	(336)
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)	479	470
Southern California Gas Company [Member] | Employee benefit costs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	49	49
Southern California Gas Company [Member] | Removal obligations [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(804)	(833)
Southern California Gas Company [Member] | Unamortized loss on reacquired debt [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	6	7
Southern California Gas Company [Member] | Environmental costs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	32	28
Southern California Gas Company [Member] | Workers’ compensation [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	9	9
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Commodity - gas including transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	16	196
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Safety and reliability [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	348	332
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Public purpose programs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(289)	(325)
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Other balancing accounts [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(143)	(68)
Southern California Gas Company [Member] | Other regulatory (liabilities) assets [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(160)	(130)
Southern California Gas Company [Member] | Net Regulatory Assets (Liabilities) SoCalGas [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(705)	(601)
Sempra Mexico [Member] | Deferred income taxes (refundable) recoverable in rates [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	81	81
Sempra Mexico [Member] | Other regulatory (liabilities) assets [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ 9	$ 6

XML

REGULATORY MATTERS - GENERAL RATE CASE (Details) - USD ($) $ in Millions		1 Months Ended	3 Months Ended
	Oct. 06, 2017	Apr. 30, 2018	Mar. 31, 2019
San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
GRC requested revenue requirement	$ 2,203	$ 1,918
GRC requested revenue requirement adjustment	221	$ 64
Tax Cuts and Jobs Act, change in tax rate, change in revenue requirement			$ 58
Proposed annual attrition percentage		4.00%
San Diego Gas and Electric Company [Member] | General Rate Case [Member]
General Rate Case [Line Items]
Tracked income tax expense liability			90
San Diego Gas and Electric Company [Member] | Future Refund of Rates to Customers [Member]
General Rate Case [Line Items]
Regulatory liability			95
San Diego Gas and Electric Company [Member] | Future Refund of Rates to Customers - FERC [Member]
General Rate Case [Line Items]
Regulatory liability			85
Southern California Gas Company [Member]
General Rate Case [Line Items]
GRC requested revenue requirement	2,937	$ 2,695
GRC requested revenue requirement adjustment	$ 481	$ 239
Tax Cuts and Jobs Act, change in tax rate, change in revenue requirement			58
Southern California Gas Company [Member] | General Rate Case [Member]
General Rate Case [Line Items]
Tracked income tax expense liability			95
Southern California Gas Company [Member] | Future Refund of Rates to Customers [Member]
General Rate Case [Line Items]
Regulatory liability			$ 91
Minimum [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
GRC requested revenue requirement adjustment percentage	5.00%
Minimum [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
GRC requested revenue requirement adjustment percentage	6.00%
Proposed annual attrition percentage		4.00%
Maximum [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
GRC requested revenue requirement adjustment percentage	7.00%
Maximum [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
GRC requested revenue requirement adjustment percentage	8.00%
Proposed annual attrition percentage		5.00%
Otay Mesa Energy Center [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
Owning and operating costs		$ 68

XML

REGULATORY MATTERS - COST OF CAPITAL (Details) - Forecast [Member] - California Public Utilities Commission [Member]		24 Months Ended
	Jan. 01, 2020	Dec. 31, 2019
San Diego Gas and Electric Company [Member]
Public Utilities, General Disclosures [Line Items]
Return On Rate Base	10.03%	7.55%
San Diego Gas and Electric Company [Member] | Common Equity [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting	56.00%	52.00%
Return on rate base	14.30%	10.20%
Premium for wildfire risk	3.40%
Southern California Gas Company [Member]
Public Utilities, General Disclosures [Line Items]
Return On Rate Base	7.85%	7.34%
Southern California Gas Company [Member] | Common Equity [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting	56.00%	52.00%
Return on rate base	10.70%	10.05%

XML

REGULATORY MATTERS - BILLING PRACTICES (Details) - USD ($)	1 Months Ended	3 Months Ended
	Jan. 31, 2019	Mar. 31, 2019	Mar. 31, 2018
Public Utilities, General Disclosures [Line Items]
Penalties related to billing practices OII		$ (8,000,000)	$ 0
Southern California Gas Company [Member]
Public Utilities, General Disclosures [Line Items]
Penalties related to billing practices OII	$ (8,000,000)	$ (8,000,000)	$ 0
Penalties related to billing practives, payable to general fund	3,000,000
Total amount penalties credited to customers	$ 5,000,000
Number of days that customers bills were delayed	45 days
Penalty credit per customer	$ 100

XML

ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - ACQUISITION ACTIVITY (Details) - USD ($) $ / shares in Units, $ in Millions				3 Months Ended
	Dec. 18, 2018	Oct. 18, 2018	Mar. 09, 2018	Mar. 31, 2019
Oncor Electric Delivery Company LLC. [Member]
Business Acquisition [Line Items]
Acquired percentage interest			80.25%
Compania Transmisora del Norte Grande S.A. [Member]
Business Acquisition [Line Items]
Cash consideration	$ 208
Consideration	226
Cash acquired	$ 18
Sempra Texas Holdings Corp [Member] | Oncor Electric Delivery Company LLC. [Member]
Business Acquisition [Line Items]
Acquired percentage interest			80.03%
Sempra Texas Holdings Corp [Member] | Sempra Texas Intermediate Holding Company LLC [Member] | Oncor Holdings [Member]
Business Acquisition [Line Items]
Ownership percentage in consolidated entity			100.00%
Sempra Texas Holdings Corp [Member] | Texas Transmission Investment LLC [Member] | Oncor Electric Delivery Company LLC. [Member]
Business Acquisition [Line Items]
Ownership percentage held by noncontrolling owners			19.75%
Sempra Texas Holdings Corp [Member] | Oncor Holdings [Member]
Business Acquisition [Line Items]
Cash consideration			$ 9,450
Adjustment for dividends			$ 31
Sempra Texas Holdings Corp [Member] | Oncor Holdings [Member] | Oncor Electric Delivery Company LLC. [Member]
Business Acquisition [Line Items]
Ownership percentage in consolidated entity			80.25%
Oncor Electric Delivery Company LLC Additional Acquisition [Member] | Sempra Texas Intermediate Holding Company LLC [Member] | Oncor Holdings [Member]
Business Acquisition [Line Items]
Cash consideration			$ 26
Oncor Electric Delivery Company LLC Additional Acquisition [Member] | Oncor Electric Delivery Company LLC. [Member] | Oncor Holdings [Member]
Business Acquisition [Line Items]
Acquired percentage interest			0.22%
Compania Transmisora del Norte Grande S.A. [Member] | Sempra South American Utilities [Member] | Compania Transmisora del Norte Grande S.A. [Member]
Business Acquisition [Line Items]
Acquired percentage interest	100.00%
InfraREIT Acquisition [Member] | Sempra Texas Utility [Member]
Business Acquisition [Line Items]
Consideration		$ 1,275
Acquisition price per share acquired		$ 21
Management agreement termination fee paid		$ 40
Debt assumed				$ 946
InfraREIT Acquisition [Member] | Sempra Texas Utility [Member] | InfraREIT [Member]
Business Acquisition [Line Items]
Acquired percentage interest		100.00%
InfraREIT Acquisition [Member] | Sempra Texas Utility [Member] | InfraREIT Partners [Member]
Business Acquisition [Line Items]
Acquired percentage interest		100.00%
Sharyland Holdings, LP [Member]
Business Acquisition [Line Items]
Commitment to invest		$ 1,025
Sharyland Holdings, LP [Member] | Sempra Texas Utility [Member]
Business Acquisition [Line Items]
Acquired percentage interest		50.00%
Consideration		$ 98
Sharyland Holdings, LP [Member] | Sempra Texas Utility [Member] | Sharyland Utilities [Member]
Business Acquisition [Line Items]
Ownership percentage in consolidated entity		50.00%
Acquired percentage interest		100.00%

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ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - DIVESTITURES (Details) - Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] - Sempra LNG [Member] - USD ($) $ in Millions	Feb. 07, 2019	Jan. 31, 2019
Mississippi Hub And Bay Gas [Member]
Business Acquisition [Line Items]
Consideration to be received	$ 322
Other Non-Utility assets [Member]
Business Acquisition [Line Items]
Consideration to be received		$ 5

XML

ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - ASSETS HELD FOR SALE (Details) - USD ($) $ in Millions	Apr. 22, 2019	Mar. 31, 2019	Dec. 31, 2018
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures		$ 12,038	$ 11,972
Assets Held for Sale, Assets [Abstract]
Cash and cash equivalents		67	88
Sempra Renewables [Member] | Disposal Group Held-for-sale [Member] | Wind Facilities [Member]
Assets Held for Sale, Assets [Abstract]
Cash and cash equivalents		4
Accounts receivable – trade, net		2
Other current assets		2
Property, plant and equipment, net		366
Total assets held for sale		374
Assets Held for Sale, Liabilities [Abstract]
Accounts payable – trade		1
Asset retirement obligations		6
Total liabilities held for sale		7
Operating Segments [Member] | Sempra LNG [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures		1,255	$ 1,271
Operating Segments [Member] | Sempra Renewables [Member] | Wind and Solar Investments [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures		$ 290
Subsequent Event [Member] | Sempra Renewables [Member] | Disposal Group Held-for-sale [Member] | Wind Facilities [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Consideration to be received	$ 584

XML

ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - DISCONTINUED OPERATIONS (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
(Loss) income from discontinued operations, net of income tax	$ (42)	$ 28
(Losses) earnings from discontinued operations attributable to common shares	(51)	21
Cash and cash equivalents	67		$ 88
Noncurrent assets	3,388		3,259	[1]
Current liabilities	375		368	[1]
Noncurrent liabilities	1,046		1,013	[1]
Disposal Group Held-for-sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Current assets	457		459	[1]
Disposal Group Held-for-sale [Member] | Sempra South American Utilities [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues	421	426
Cost of sales	(265)	(293)
Operating expenses	(45)	(54)
Interest and other	(3)	(5)
Income before income taxes and equity earnings of unconsolidated entities	108	74
Income tax expense	(151)	(47)
Equity earnings	1	1
(Loss) income from discontinued operations, net of income tax	(42)	28
Earnings attributable to noncontrolling interests	(9)	(7)
(Losses) earnings from discontinued operations attributable to common shares	(51)	$ 21
Cash and cash equivalents	67		88
Accounts receivable, net	331		315
Due from unconsolidated affiliates	3		2
Inventories	41		38
Other current assets	15		16
Current assets	457		459
Due from unconsolidated affiliates	46		44
Goodwill and other intangible assets	834		819
Property, plant and equipment, net	2,459		2,357
Other noncurrent assets	49		39
Noncurrent assets	3,388		3,259
Short-term debt	46		55
Accounts payable	188		176
Current portion of long-term debt and finance leases	22		29
Other current liabilities	119		108
Current liabilities	375		368
Long-term debt and finance leases	721		708
Deferred income taxes	263		250
Other noncurrent liabilities	62		55
Noncurrent liabilities	$ 1,046		$ 1,013
Disposal Group Held-for-sale [Member] | Luz Del Sur [Member] | Sempra South American Utilities [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest	83.60%
Disposal Group Held-for-sale [Member] | Chilquinta Energia [Member] | Sempra South American Utilities [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest	100.00%

[1] Derived from audited financial statements.

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INVESTMENTS IN UNCONSOLIDATED ENTITIES - NARRATIVE (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended
	May 07, 2019	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Schedule of Equity Method Investments [Line Items]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures		$ 12,038		$ 11,972
Maximum exposure under guarantor obligations		4,200
Aggregate carrying value of guarantor obligations		10
Joint Venture [Member] | Sempra Mexico [Member] | IMG [Member]
Schedule of Equity Method Investments [Line Items]
Investments made during period			$ 25
Joint Venture [Member] | Sempra LNG [Member] | Cameron LNG [Member]
Schedule of Equity Method Investments [Line Items]
Investments made during period		25	29
Capitalized interest		13	$ 11
Oncor Holdings [Member] | Sempra Energy [Member]
Schedule of Equity Method Investments [Line Items]
Contribution		56
Operating Segments [Member] | Sempra LNG [Member]
Schedule of Equity Method Investments [Line Items]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures		1,255		$ 1,271
Operating Segments [Member] | Wind Investments [Member] | Sempra Renewables [Member]
Schedule of Equity Method Investments [Line Items]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures		290
Sempra Energy [Member] | Oncor Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Dividends		54
Tax sharing payments		$ 3
Subsequent Event [Member] | Sempra Energy [Member] | Oncor Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Contribution	$ 56
Dividends	54
Tax sharing payments	$ 3

XML

INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARIZED FINANCIAL INFORMATION (Details) - Oncor Holdings [Member] - USD ($) $ in Millions	1 Months Ended	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2019
Schedule of Equity Method Investments [Line Items]
Operating revenues	$ 236	$ 1,016
Operating expense	(185)	(775)
Income from operations	51	241
Interest expense	(22)	(86)
Income tax expense	(7)	(23)
Net income / Earnings	19	114
Noncontrolling interest held by TTI	(4)	(23)
Earnings attributable to Sempra Energy	$ 15	$ 91

XML

DEBT AND CREDIT FACILITIES - LINES OF CREDIT (Details)		1 Months Ended	12 Months Ended
	Apr. 11, 2019 USD ($)	Feb. 28, 2019 USD ($) lender	Dec. 31, 2018 USD ($) lender	Mar. 31, 2019 USD ($)
Line of Credit Facility [Line Items]
Standby letters of credit outstanding				$ 611,000,000
Sempra U.S. Businesses [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity				5,435,000,000
Available unused credit				$ 3,718,000,000
Maximum ratio of indebtedness to total capitalization				65.00%
Sempra Energy [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity				$ 1,250,000,000
Available unused credit				1,250,000,000
Capacity for issuance of letters of credit				400,000,000
Sempra Global [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity				3,185,000,000
Available unused credit				1,896,000,000
California Utilities Combined [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity				1,000,000,000
Limit on facility borrowings				(500,000,000)
Available unused credit				572,000,000
Limit on borrowings available				(500,000,000)
Capacity for issuance of letters of credit				250,000,000
San Diego Gas and Electric Company [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity				750,000,000
Available unused credit				$ 512,000,000
Maximum ratio of indebtedness to total capitalization				65.00%
Southern California Gas Company [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity				$ 750,000,000
Available unused credit				$ 560,000,000
Maximum ratio of indebtedness to total capitalization				65.00%
Sempra Mexico [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 1,500,000,000	$ 1,170,000,000
Available unused credit				$ 692,000,000
Term of debt instrument		5 years
Number of lenders | lender		10	8
Commercial Paper [Member] | Sempra U.S. Businesses [Member]
Line of Credit Facility [Line Items]
Amount outstanding				(1,717,000,000)
Commercial Paper [Member] | Sempra Energy [Member]
Line of Credit Facility [Line Items]
Amount outstanding				0
Commercial Paper [Member] | Sempra Global [Member]
Line of Credit Facility [Line Items]
Amount outstanding				(1,289,000,000)
Unamortized debt discount				2,000,000
Commercial Paper [Member] | California Utilities Combined [Member]
Line of Credit Facility [Line Items]
Amount outstanding				(428,000,000)
Limit on facility borrowings				0
Commercial Paper [Member] | San Diego Gas and Electric Company [Member]
Line of Credit Facility [Line Items]
Amount outstanding				(238,000,000)
Commercial Paper [Member] | Southern California Gas Company [Member]
Line of Credit Facility [Line Items]
Amount outstanding				$ (190,000,000)
Subsequent Event [Member] | Sempra Mexico [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 100,000,000
Term of debt instrument	3 years

XML

DEBT AND CREDIT FACILITIES - WEIGHTED-AVERAGE INTEREST RATES AND INTEREST RATE SWAPS (Details) - USD ($) $ in Millions	Mar. 31, 2019	Feb. 28, 2019	Dec. 31, 2018
Sempra Energy Consolidated [Member]
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	3.07%		2.99%
San Diego Gas and Electric Company [Member]
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	2.80%		2.97%
Southern California Gas Company [Member]
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	2.49%		2.58%
Interest Rate Swap, maturing in March 2021 [Member]
Debt Instrument [Line Items]
Notional amount of derivative		$ 850
Fixed interest rate		3.069%

XML

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE COMMODITY VOLUMES (Details)	3 Months Ended	12 Months Ended
	Mar. 31, 2019 MWh MMBTU	Dec. 31, 2018 MWh MMBTU
Natural Gas Derivative [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | MMBTU	33	35
Electric Energy Derivative [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount	2	2
Congestion Revenue Rights Derivative [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount	50	52
SDG&E [Member] | Natural Gas Derivative [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | MMBTU	32	33
SDG&E [Member] | Electric Energy Derivative [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount	2	2
SDG&E [Member] | Congestion Revenue Rights Derivative [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount	50	52

XML

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE NOTIONALS (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
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	1,084	1,158
Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Notional amount of derivative	1,430	594
San Diego Gas and Electric Company [Member] | Interest Rate Swap maturing on October 31 2019 [Member]
Derivative [Line Items]
Notional amount of derivative	159
San Diego Gas and Electric Company [Member] | Swaption [Member]
Derivative [Line Items]
Notional amount of derivative	142
San Diego Gas and Electric Company [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Notional amount of derivative	$ 142	$ 142
Maximum [Member] | Interest rate and foreign exchange instruments [Member]
Derivative [Line Items]
Derivative, Maturity Date	Dec. 31, 2023	Dec. 31, 2023
Maximum [Member] | Foreign Exchange [Member]
Derivative [Line Items]
Derivative, Maturity Date	Dec. 31, 2020	Dec. 31, 2020
Maximum [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative, Maturity Date	Dec. 31, 2032	Dec. 31, 2032
Maximum [Member] | San Diego Gas and Electric Company [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative, Maturity Date	Dec. 31, 2019	Dec. 31, 2019
Minimum [Member] | Interest rate and foreign exchange instruments [Member]
Derivative [Line Items]
Derivative, Maturity Date	Dec. 31, 2019	Dec. 31, 2019
Minimum [Member] | Foreign Exchange [Member]
Derivative [Line Items]
Derivative, Maturity Date	Dec. 31, 2019	Dec. 31, 2019
Minimum [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative, Maturity Date	Dec. 31, 2019	Dec. 31, 2019
Minimum [Member] | San Diego Gas and Electric Company [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative, Maturity Date	Dec. 31, 2019	Dec. 31, 2019

XML

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS ON THE CONDENSED BALANCE SHEET (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Current assets: Other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	$ 68	$ 80
Additional cash collateral for commodity contracts not subject to rate recovery	25	19
Additional cash collateral for commodity contracts subject to rate recovery	26	33
Total	119	132
Other assets: Sundry [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	238	235
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	238	235
Current liabilities: Other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(56)	(70)
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	(56)	(70)
Deferred credits and other liabilities: Deferred credits and other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(209)	(218)
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	(209)	(218)
Designated as Hedging Instrument [Member] | Current assets: Other [Member]
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	0	2
Designated as Hedging Instrument [Member] | Other assets: Sundry [Member]
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	0	0
Designated as Hedging Instrument [Member] | Current liabilities: Other [Member]
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	(5)	(3)
Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	(146)	(147)
Not Designated as Hedging Instrument [Member] | Current assets: Other [Member]
Derivatives not designated as hedging instruments:
Foreign exchange instruments	12
Commodity contracts not subject to rate recovery	58	153
Associated offsetting commodity contracts	(47)	(133)
Commodity contracts subject to rate recovery	50	64
Associated offsetting commodity contracts	(5)	(6)
Associated offsetting cash collateral	0	0
Not Designated as Hedging Instrument [Member] | Other assets: Sundry [Member]
Derivatives not designated as hedging instruments:
Foreign exchange instruments	0
Commodity contracts not subject to rate recovery	6	7
Associated offsetting commodity contracts	(2)	(3)
Commodity contracts subject to rate recovery	236	233
Associated offsetting commodity contracts	(2)	(2)
Associated offsetting cash collateral	0	0
Not Designated as Hedging Instrument [Member] | Current liabilities: Other [Member]
Derivatives not designated as hedging instruments:
Foreign exchange instruments	0
Commodity contracts not subject to rate recovery	(65)	(164)
Associated offsetting commodity contracts	47	133
Commodity contracts subject to rate recovery	(41)	(42)
Associated offsetting commodity contracts	5	6
Associated offsetting cash collateral	3	0
Not Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Derivatives not designated as hedging instruments:
Foreign exchange instruments	0
Commodity contracts not subject to rate recovery	(5)	(6)
Associated offsetting commodity contracts	2	3
Commodity contracts subject to rate recovery	(65)	(72)
Associated offsetting commodity contracts	2	2
Associated offsetting cash collateral	3	2
San Diego Gas and Electric Company [Member] | Current assets: Other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	40	54
Additional cash collateral for commodity contracts subject to rate recovery	25	28
Total	65	82
San Diego Gas and Electric Company [Member] | Other assets: Sundry [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	232	231
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	232	231
San Diego Gas and Electric Company [Member] | Current liabilities: Other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(29)	(32)
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(29)	(32)
San Diego Gas and Electric Company [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(60)	(68)
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(60)	(68)
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Current assets: Other [Member]
Derivatives designated as hedging instruments:
Interest rate instruments		0
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Other assets: Sundry [Member]
Derivatives designated as hedging instruments:
Interest rate instruments		0
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Current liabilities: Other [Member]
Derivatives designated as hedging instruments:
Interest rate instruments		(1)
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Derivatives designated as hedging instruments:
Interest rate instruments		0
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Current assets: Other [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	45	60
Associated offsetting commodity contracts	(5)	(6)
Associated offsetting cash collateral	0	0
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Other assets: Sundry [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	234	233
Associated offsetting commodity contracts	(2)	(2)
Associated offsetting cash collateral	0	0
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Current liabilities: Other [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(37)	(37)
Associated offsetting commodity contracts	5	6
Associated offsetting cash collateral	3	0
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(65)	(72)
Associated offsetting commodity contracts	2	2
Associated offsetting cash collateral	3	2
Southern California Gas Company [Member] | Current assets: Other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	5	4
Additional cash collateral for commodity contracts subject to rate recovery	1	5
Total	6	9
Southern California Gas Company [Member] | Other assets: Sundry [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	2	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	2	0
Southern California Gas Company [Member] | Current liabilities: Other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(4)	(5)
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(4)	(5)
Southern California Gas Company [Member] | Deferred credits and other liabilities: Deferred credits and other [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] | Not Designated as Hedging Instrument [Member] | Current assets: Other [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	5	4
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Other assets: Sundry [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	2	0
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Current liabilities: Other [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(4)	(5)
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$ 0	$ 0

XML

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE IMPACT ON INCOME (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 27	$ 35
Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net	14	38
Not Designated as Hedging Instrument [Member] | Other Income [Member] | Foreign Exchange [Member]
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net	10	44
Not Designated as Hedging Instrument [Member] | Sales [Member] | Commodity Contracts not subject to rate recovery [Member]
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net	0	(9)
Not Designated as Hedging Instrument [Member] | Cost of Electric Fuel and Purchased Power [Member] | Commodity Contracts Subject To Rate Recovery [Member]
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net	2	2
Not Designated as Hedging Instrument [Member] | Cost of Natural Gas [Member] | Commodity Contracts Subject To Rate Recovery [Member]
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net	2	1
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member]
Derivative [Line Items]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, before Tax	(74)	117
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0	16
Designated as Hedging Instrument [Member] | Interest Expense [Member] | Cash Flow Hedging [Member] | Interest rate and foreign exchange instruments [Member]
Derivative [Line Items]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, before Tax	(3)	54
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	(1)	2
Designated as Hedging Instrument [Member] | Other Income [Member] | Cash Flow Hedging [Member] | Interest rate and foreign exchange instruments [Member]
Derivative [Line Items]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	3	18
Designated as Hedging Instrument [Member] | Equity Earnings (Losses) [Member] | Cash Flow Hedging [Member] | Interest rate and foreign exchange instruments [Member]
Derivative [Line Items]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, before Tax	(68)	70
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	(1)	(4)
Designated as Hedging Instrument [Member] | Sales [Member] | Cash Flow Hedging [Member] | Foreign Exchange [Member]
Derivative [Line Items]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, before Tax	(3)	(7)
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	(1)	0
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]
Derivative, Gain (Loss) on Derivative, Net	2	2
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Interest Expense [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, before Tax	0	1
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	(1)	(3)
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]
Derivative, Gain (Loss) on Derivative, Net	$ 2	$ 1

XML

DERIVATIVE FINANCIAL INSTRUMENTS - CASH FLOW HEDGES (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified	$ 5
Term of interest rate cash flow hedge	13 years
San Diego Gas and Electric Company [Member]
Derivative [Line Items]
Term of interest rate cash flow hedge	1 year
San Diego Gas and Electric Company [Member] | Noncontrolling Interest [Member]
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified	$ (1)
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	15 years

XML

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS WITH CONTINGENT FEATURES (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Derivative [Line Items]
Derivative fair value	$ 14	$ 16
Collateral	15
Southern California Gas Company [Member]
Derivative [Line Items]
Derivative fair value	4	$ 5
Collateral	$ 4

XML

FAIR VALUE MEASUREMENTS - RECURRING FAIR VALUE MEASURES (Details) - USD ($)	Mar. 31, 2019	Dec. 31, 2018
Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments at NAV	$ 7,000,000
Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	459,000,000	$ 411,000,000
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	48,000,000	53,000,000
Nuclear decommissioning trusts - Municipal bonds	279,000,000	269,000,000
Nuclear decommissioning trusts - Other securities	238,000,000	234,000,000
Nuclear decommissioning trusts - Total debt securities	565,000,000	556,000,000
Total nuclear decommissioning trusts	1,024,000,000	967,000,000
Total Assets Measured at Fair Value	1,381,000,000	1,334,000,000
Total LIabilities Measured at Fair Value	265,000,000	288,000,000
Recurring [Member] | Interest rate and foreign exchange instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	12,000,000	2,000,000
Derivative liabilities	151,000,000	150,000,000
Recurring [Member] | Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	15,000,000	24,000,000
Effect of netting and allocation of collateral	25,000,000	19,000,000
Derivative liabilities	21,000,000	34,000,000
Recurring [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	279,000,000	289,000,000
Effect of netting and allocation of collateral	26,000,000	33,000,000
Derivative liabilities	99,000,000	106,000,000
Effect of netting and allocation of collateral	(6,000,000)	(2,000,000)
Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	454,000,000	407,000,000
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	39,000,000	43,000,000
Nuclear decommissioning trusts - Municipal bonds	0	0
Nuclear decommissioning trusts - Other securities	0	0
Nuclear decommissioning trusts - Total debt securities	39,000,000	43,000,000
Total nuclear decommissioning trusts	493,000,000	450,000,000
Total Assets Measured at Fair Value	539,000,000	499,000,000
Total LIabilities Measured at Fair Value	0	0
Recurring [Member] | 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
Recurring [Member] | 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	25,000,000	19,000,000
Derivative liabilities	0	0
Recurring [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	2,000,000
Effect of netting and allocation of collateral	21,000,000	28,000,000
Derivative liabilities	6,000,000	2,000,000
Effect of netting and allocation of collateral	(6,000,000)	(2,000,000)
Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	5,000,000	4,000,000
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	9,000,000	10,000,000
Nuclear decommissioning trusts - Municipal bonds	279,000,000	269,000,000
Nuclear decommissioning trusts - Other securities	238,000,000	234,000,000
Nuclear decommissioning trusts - Total debt securities	526,000,000	513,000,000
Total nuclear decommissioning trusts	531,000,000	517,000,000
Total Assets Measured at Fair Value	566,000,000	552,000,000
Total LIabilities Measured at Fair Value	176,000,000	189,000,000
Recurring [Member] | 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	12,000,000	2,000,000
Derivative liabilities	151,000,000	150,000,000
Recurring [Member] | 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	15,000,000	24,000,000
Effect of netting and allocation of collateral	0	0
Derivative liabilities	21,000,000	34,000,000
Recurring [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	8,000,000	9,000,000
Effect of netting and allocation of collateral	0	0
Derivative liabilities	4,000,000	5,000,000
Effect of netting and allocation of collateral	0	0
Recurring [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	276,000,000	283,000,000
Total LIabilities Measured at Fair Value	89,000,000	99,000,000
Recurring [Member] | 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
Recurring [Member] | 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
Recurring [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	271,000,000	278,000,000
Effect of netting and allocation of collateral	5,000,000	5,000,000
Derivative liabilities	89,000,000	99,000,000
Effect of netting and allocation of collateral	0	0
San Diego Gas and Electric Company [Member] | Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	459,000,000	411,000,000
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	48,000,000	53,000,000
Nuclear decommissioning trusts - Municipal bonds	279,000,000	269,000,000
Nuclear decommissioning trusts - Other securities	238,000,000	234,000,000
Nuclear decommissioning trusts - Total debt securities	565,000,000	556,000,000
Total nuclear decommissioning trusts	1,024,000,000	967,000,000
Total Assets Measured at Fair Value	1,321,000,000	1,280,000,000
Total LIabilities Measured at Fair Value	89,000,000	100,000,000
San Diego Gas and Electric Company [Member] | Recurring [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	272,000,000	285,000,000
Effect of netting and allocation of collateral	25,000,000	28,000,000
Derivative liabilities	95,000,000	101,000,000
Effect of netting and allocation of collateral	(6,000,000)	(2,000,000)
San Diego Gas and Electric Company [Member] | Recurring [Member] | Interest rate instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		1,000,000
San Diego Gas and Electric Company [Member] | Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	454,000,000	407,000,000
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	39,000,000	43,000,000
Nuclear decommissioning trusts - Municipal bonds	0	0
Nuclear decommissioning trusts - Other securities	0	0
Nuclear decommissioning trusts - Total debt securities	39,000,000	43,000,000
Total nuclear decommissioning trusts	493,000,000	450,000,000
Total Assets Measured at Fair Value	513,000,000	474,000,000
Total LIabilities Measured at Fair Value	0	0
San Diego Gas and Electric Company [Member] | Recurring [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	1,000,000
Effect of netting and allocation of collateral	20,000,000	23,000,000
Derivative liabilities	6,000,000	2,000,000
Effect of netting and allocation of collateral	(6,000,000)	(2,000,000)
San Diego Gas and Electric Company [Member] | Recurring [Member] | Level 1 [Member] | Interest rate instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		0
San Diego Gas and Electric Company [Member] | Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	5,000,000	4,000,000
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	9,000,000	10,000,000
Nuclear decommissioning trusts - Municipal bonds	279,000,000	269,000,000
Nuclear decommissioning trusts - Other securities	238,000,000	234,000,000
Nuclear decommissioning trusts - Total debt securities	526,000,000	513,000,000
Total nuclear decommissioning trusts	531,000,000	517,000,000
Total Assets Measured at Fair Value	532,000,000	523,000,000
Total LIabilities Measured at Fair Value	0	1,000,000
San Diego Gas and Electric Company [Member] | Recurring [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	1,000,000	6,000,000
Effect of netting and allocation of collateral	0	0
Derivative liabilities	0	0
Effect of netting and allocation of collateral	0	0
San Diego Gas and Electric Company [Member] | Recurring [Member] | Level 2 [Member] | Interest rate instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		1,000,000
San Diego Gas and Electric Company [Member] | Recurring [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	276,000,000	283,000,000
Total LIabilities Measured at Fair Value	89,000,000	99,000,000
San Diego Gas and Electric Company [Member] | Recurring [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	271,000,000	278,000,000
Effect of netting and allocation of collateral	5,000,000	5,000,000
Derivative liabilities	89,000,000	99,000,000
Effect of netting and allocation of collateral	0	0
San Diego Gas and Electric Company [Member] | Recurring [Member] | Level 3 [Member] | Interest rate instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		0
Southern California Gas Company [Member] | Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total Assets Measured at Fair Value	8,000,000	9,000,000
Total LIabilities Measured at Fair Value	4,000,000	5,000,000
Southern California Gas Company [Member] | Recurring [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	7,000,000	4,000,000
Effect of netting and allocation of collateral	1,000,000	5,000,000
Derivative liabilities	4,000,000	5,000,000
Southern California Gas Company [Member] | Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total Assets Measured at Fair Value	1,000,000	6,000,000
Total LIabilities Measured at Fair Value	0	0
Southern California Gas Company [Member] | Recurring [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	1,000,000
Effect of netting and allocation of collateral	1,000,000	5,000,000
Derivative liabilities	0	0
Southern California Gas Company [Member] | Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total Assets Measured at Fair Value	7,000,000	3,000,000
Total LIabilities Measured at Fair Value	4,000,000	5,000,000
Southern California Gas Company [Member] | Recurring [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	7,000,000	3,000,000
Effect of netting and allocation of collateral	0	0
Derivative liabilities	4,000,000	5,000,000
Southern California Gas Company [Member] | Recurring [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] | Recurring [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

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FAIR VALUE MEASUREMENTS - RECON OF LEVEL 3 ASSETS (Details) - USD ($)	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at January 1	$ 179,000,000	$ (28,000,000)	$ 179,000,000	$ (28,000,000)
Realized and unrealized gains	5,000,000	4,000,000
Allocated transmission instruments	0	3,000,000
Settlements	(2,000,000)	(19,000,000)
Balance at March 31	182,000,000	(40,000,000)		179,000,000
Change in unrealized gains relating to instruments still held at the end of the period	$ 13,000,000	$ (8,000,000)
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)				(7.25)
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)				11.99
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)				0.09
Subsequent Event [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)			(8.57)
Subsequent Event [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)			35.21
Subsequent Event [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)			(2.94)
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]
Market electricity forward price inputs ( in dollars per MWH)				20.00
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]
Market electricity forward price inputs ( in dollars per MWH)				47.65
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]
Market electricity forward price inputs ( in dollars per MWH)				$ 35.42
Level 3 [Member] | Subsequent Event [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]
Market electricity forward price inputs ( in dollars per MWH)			23.25
Level 3 [Member] | Subsequent Event [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]
Market electricity forward price inputs ( in dollars per MWH)			81.75
Level 3 [Member] | Subsequent Event [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]
Market electricity forward price inputs ( in dollars per MWH)			$ 42.49

XML

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($)	Mar. 31, 2019	Dec. 31, 2018
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount (net of premium) and debt issuance costs	$ 201,000,000	$ 206,000,000
Finance Lease, Liability	1,277,000,000
Build-to-suit and capital lease obligations		1,413,000,000
Level 3 [Member] | Otay Mesa VIE [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	220,000,000	220,000,000
Carrying amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates	668,000,000	644,000,000
Long-term amounts due to unconsolidated affiliate	38,000,000	37,000,000
Total long-term debt	20,814,000,000	21,340,000,000
Fair value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates	689,000,000	652,000,000
Long-term amounts due to unconsolidated affiliate	37,000,000	35,000,000
Total long-term debt	20,846,000,000	20,863,000,000
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	689,000,000	648,000,000
Long-term amounts due to unconsolidated affiliate	37,000,000	35,000,000
Total long-term debt	20,598,000,000	20,616,000,000
Fair value [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates	0	4,000,000
Long-term amounts due to unconsolidated affiliate	0	0
Total long-term debt	248,000,000	247,000,000
San Diego Gas and Electric Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount (net of premium) and debt issuance costs	48,000,000	49,000,000
Finance Lease, Liability	1,272,000,000
Capital lease obligations		1,272,000,000
San Diego Gas and Electric Company [Member] | Carrying amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	4,978,000,000	4,996,000,000
San Diego Gas and Electric Company [Member] | Fair value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	5,138,000,000	5,117,000,000
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	4,918,000,000	4,897,000,000
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	220,000,000	220,000,000
Southern California Gas Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount (net of premium) and debt issuance costs	32,000,000	32,000,000
Finance Lease, Liability	5,000,000
Capital lease obligations		3,000,000
Southern California Gas Company [Member] | Carrying amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	3,459,000,000	3,459,000,000
Southern California Gas Company [Member] | Fair value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	3,595,000,000	3,505,000,000
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	3,595,000,000	3,505,000,000
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

XML

SAN ONOFRE NUCLEAR GENERATING STATION (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Jan. 31, 2019
Jointly Owned Utility Plant Interests [Line Items]
Anticipated term of dismantlement work	10 years
San Diego Gas and Electric Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Percent of dismantlement work expense	20.00%
Nuclear decommissioning trust authorized withdrawal amount	$ 455	$ 93
ARO related to decommissioning costs	620
Cost study estimate decommissioning escalated	$ 810
Jointly Owned Nuclear Power Plant [Member] | San Diego Gas and Electric Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, proportionate ownership share	20.00%

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SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR DECOMMISSIONING TRUSTS (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Debt Securities, Available-for-sale [Line Items]
Cost	$ 734		$ 731
Gross unrealized gains	310		259
Gross unrealized losses	(7)		(16)
Estimated fair value	1,037		974
Proceeds from sales	225	$ 210
Gross realized gains	5	4
Gross realized losses	(2)	$ (3)
Total debt securities [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	555		556
Gross unrealized gains	11		6
Gross unrealized losses	(1)		(6)
Estimated fair value	565		556
U.S. government corporations and agencies [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	48		52
Gross unrealized gains	0		1
Gross unrealized losses	0		0
Estimated fair value	48		53
Municipal bonds [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	271		266
Gross unrealized gains	8		4
Gross unrealized losses	0		(1)
Estimated fair value	279		269
Other securities [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	236		238
Gross unrealized gains	3		1
Gross unrealized losses	(1)		(5)
Estimated fair value	238		234
Equity securities [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	166		168
Gross unrealized gains	299		253
Gross unrealized losses	(6)		(10)
Estimated fair value	459		411
Cash and cash equivalents [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	13		7
Gross unrealized gains	0		0
Gross unrealized losses	0		0
Estimated fair value	$ 13		$ 7

XML

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR INSURANCE (Details) - San Diego Gas and Electric Company [Member] $ in Millions	Mar. 31, 2019 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	1,500.0
Spent nuclear fuel storage insurance	500.0
Federal nuclear property damage insurance, minimum required	1,060.0
Maximum premium assessment under nuclear property damage insurance	10.4
Maximum nuclear property insurance terrorism coverage	$ 3,240.0

XML

COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details)			1 Months Ended				3 Months Ended
	May 02, 2019 plaintiff lawsuit	Feb. 18, 2016 Bcf	Oct. 31, 2018 plaintiff	Aug. 31, 2018 USD ($)	Jan. 31, 2017 lawsuit	Feb. 29, 2016 USD ($)	Mar. 31, 2019 USD ($) Bcf lawsuit	Sep. 30, 2018 lawsuit	Sep. 30, 2017 USD ($)	Dec. 31, 2018 USD ($)	[1]	Oct. 21, 2016 t
Loss Contingencies [Line Items]
Liability for legal proceedings							$ 104,000,000
Reserve for Aliso Canyon costs							$ 60,000,000			$ 160,000,000
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
Complaints Filed by Public Entities [Member]
Loss Contingencies [Line Items]
Number of lawsuits filed | lawsuit							3	3
Southern California Gas Company [Member]
Loss Contingencies [Line Items]
Liability for legal proceedings							$ 54,000,000
Insurance Settlements Receivable							1,043,000,000
Reserve for Aliso Canyon costs							60,000,000			$ 160,000,000
Southern California Gas Company [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Liability for legal proceedings							53,000,000
Amount of natural gas released | Bcf		4.62
Mitigation requirements (in metric tons) | t												109,000
Loss contingency accrual							$ 1,071,000,000
Percent of Loss Accrual Allocated to Temporary Relocation Program							53.00%
Reserve for Aliso Canyon costs							$ 60,000,000
Receivable related to natural gas leak							477,000,000
Insurance proceeds							$ 566,000,000
Storage facility capacity | Bcf							86
Proportion of total gas storage capacity (percentage)							63.00%
Storage Facility, Working Gas Target | Bcf							34
Net book value of Aliso Canyon facility							$ 741,000,000
Southern California Gas Company [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Subsequent Event [Member]
Loss Contingencies [Line Items]
Number of lawsuits | lawsuit	394
Number of plaintiffs | plaintiff	48,500
Southern California Gas Company [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Minimum [Member]
Loss Contingencies [Line Items]
Liability insurance coverage							1,200,000,000
Southern California Gas Company [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Maximum [Member]
Loss Contingencies [Line Items]
Liability insurance coverage							$ 1,400,000,000
Southern California Gas Company [Member] | Damages from Product Defects [Member]
Loss Contingencies [Line Items]
Maximum occupational safety and health fines						$ 75,000
Penalty assessments						233,500
Maximum other assessments in settlement of criminal complaint						$ 6,000,000
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] | Complaints Filed by Public Entities [Member] | Funding for Environmental Projects [Member]
Loss Contingencies [Line Items]
Settlement amount payable				$ 120,000,000
Southern California Gas Company [Member] | Complaints Filed by Public Entities [Member] | Civil Penalties [Member]
Loss Contingencies [Line Items]
Settlement amount payable				$ 21,000,000
San Diego Gas and Electric Company [Member] | Wildfire [Member]
Loss Contingencies [Line Items]
Write-off of wildfire regulatory asset									$ 351,000,000
After-tax charge for nonrecovery of CPUC regulatory assets									$ 208,000,000
Energy Future Holdings Corp. [Member] | Subsequent Event [Member]
Loss Contingencies [Line Items]
Number of lawsuits | lawsuit	114
Number of lawsuits filed | lawsuit	1,685

[1] Derived from audited financial statements.

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COMMITMENTS AND CONTINGENCIES - OTHER LITIGATION (Details) £ in Millions, $ in Millions		3 Months Ended
	May 02, 2019 lawsuit	Mar. 31, 2019 USD ($) proof_of_claim	Mar. 31, 2019 GBP (£) proof_of_claim	Sep. 30, 2018 USD ($)	Oct. 01, 2014 USD ($)	Oct. 01, 2014 GBP (£)
Southern California Gas Company [Member] | Subsequent Event [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Number of lawsuits	394
R B S Sempra Commodities [Member]
Loss Contingencies [Line Items]
Investment in RBS Sempra Commodities LLP | $				$ 65.0
R B S Sempra Commodities [Member] | HMRC VAT Claim [Member]
Loss Contingencies [Line Items]
VAT tax claim paid upon appeal					$ 138.0	£ 86.0
Plaintiffs [Member] | HMRC VAT Claim [Member]
Loss Contingencies [Line Items]
Filed claims amount		$ 93.0	£ 71.5
Energy Future Holdings Corp. [Member]
Loss Contingencies [Line Items]
Number of proof of claims | proof_of_claim		28,000	28,000
Energy Future Holdings Corp. [Member] | Subsequent Event [Member]
Loss Contingencies [Line Items]
Number of lawsuits	114
Number of lawsuits filed	1,685

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COMMITMENTS AND CONTINGENCIES - LEASES (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($) facility
Lessee, Lease, Description [Line Items]
Lease term	12 months
Number of battery storage facilities | facility	3
Leases not yet commenced, future minimum lease payments, 2020 - 2024	$ 1
Leases not yet commenced, future minimum lease payments, thereafter	18
Aggregate maximum lease limit	194
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Aggregate maximum lease limit, utilized	52
Southern California Gas Company [Member]
Lessee, Lease, Description [Line Items]
Aggregate maximum lease limit, utilized	$ 75
Minimum [Member]
Lessee, Lease, Description [Line Items]
Termination period	1 year
Annual increase in rent	1.00%
Maximum [Member]
Lessee, Lease, Description [Line Items]
Option to extend terms	25 years
Annual increase in rent	5.00%

XML

COMMITMENTS AND CONTINGENCIES - LESSEE BALANCE SHEET INFORMATION (Details)	Mar. 31, 2019 USD ($)
Lessee, Lease, Description [Line Items]
Right-of-use assets	$ 612,000,000
Property, plant and equipment	1,322,000,000
Accumulated depreciation	(45,000,000)
Property, plant and equipment, net	1,277,000,000
Total right-of-use assets	1,889,000,000
Other current liabilities	52,000,000
Deferred credits and other	455,000,000
Total lease liabilities	507,000,000
Current portion of long-term debt and finance leases	21,000,000
Long-term debt and finance leases	1,256,000,000
Total lease liabilities	1,277,000,000
Total lease liabilities	$ 1,784,000,000
Operating leases, Weighted-average remaining lease term (in years)	14 years
Finance leases, Weighted-average remaining lease term (in years)	20 years
Operating leases, Weighted-average discount rate	5.87%
Finance leases, Weighted-average discount rate	14.91%
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Right-of-use assets	$ 135,000,000
Property, plant and equipment	1,315,000,000
Accumulated depreciation	(43,000,000)
Property, plant and equipment, net	1,272,000,000
Total right-of-use assets	1,407,000,000
Other current liabilities	24,000,000
Deferred credits and other	110,000,000
Total lease liabilities	134,000,000
Current portion of long-term debt and finance leases	18,000,000
Long-term debt and finance leases	1,254,000,000
Total lease liabilities	1,272,000,000
Total lease liabilities	$ 1,406,000,000
Operating leases, Weighted-average remaining lease term (in years)	7 years
Finance leases, Weighted-average remaining lease term (in years)	20 years
Operating leases, Weighted-average discount rate	3.69%
Finance leases, Weighted-average discount rate	14.92%
Southern California Gas Company [Member]
Lessee, Lease, Description [Line Items]
Right-of-use assets	$ 110,000,000
Property, plant and equipment	7,000,000
Accumulated depreciation	(2,000,000)
Property, plant and equipment, net	5,000,000
Total right-of-use assets	115,000,000
Other current liabilities	22,000,000
Deferred credits and other	88,000,000
Total lease liabilities	110,000,000
Current portion of long-term debt and finance leases	3,000,000
Long-term debt and finance leases	2,000,000
Total lease liabilities	5,000,000
Total lease liabilities	$ 115,000,000
Operating leases, Weighted-average remaining lease term (in years)	6 years
Finance leases, Weighted-average remaining lease term (in years)	3 years
Operating leases, Weighted-average discount rate	3.76%
Finance leases, Weighted-average discount rate	3.94%

XML

COMMITMENTS AND CONTINGENCIES - LESSEE STATEMENT OF OPERATIONS INFORMATION (Details)	3 Months Ended
	Mar. 31, 2019 USD ($)
Lessee, Lease, Description [Line Items]
Operating lease costs	$ 24,000,000
Amortization of ROU assets	5,000,000
Interest on lease liabilities	47,000,000
Total finance lease costs	52,000,000
Short-term lease costs	1,000,000
Variable lease costs	92,000,000
Total lease costs	169,000,000
Southern California Gas Company [Member]
Lessee, Lease, Description [Line Items]
Operating lease costs	7,000,000
Amortization of ROU assets	1,000,000
Interest on lease liabilities	0
Total finance lease costs	1,000,000
Short-term lease costs	0
Variable lease costs	2,000,000
Total lease costs	10,000,000
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Operating lease costs	8,000,000
Amortization of ROU assets	4,000,000
Interest on lease liabilities	47,000,000
Total finance lease costs	51,000,000
Short-term lease costs	0
Variable lease costs	90,000,000
Total lease costs	$ 149,000,000

XML

COMMITMENTS AND CONTINGENCIES - LESSEE CASH FLOW INFORMATION (Details) - USD ($)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Lessee, Lease, Description [Line Items]
Cash paid for operating leases	$ 39,000,000
Cash paid for finance leases	43,000,000
Cash paid for finance leases	5,000,000
Increase in operating lease obligations for right-of-use assets	552,000,000
Increase in finance lease obligations for investment in PP&E	7,000,000	$ 5,000,000
Southern California Gas Company [Member]
Lessee, Lease, Description [Line Items]
Cash paid for operating leases	7,000,000
Cash paid for finance leases	0
Cash paid for finance leases	1,000,000	0
Increase in operating lease obligations for right-of-use assets	117,000,000
Increase in finance lease obligations for investment in PP&E	3,000,000	5,000,000
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Cash paid for operating leases	8,000,000
Cash paid for finance leases	43,000,000
Cash paid for finance leases	4,000,000
Increase in operating lease obligations for right-of-use assets	142,000,000
Increase in finance lease obligations for investment in PP&E	$ 4,000,000	$ 0

XML

COMMITMENTS AND CONTINGENCIES - LESSEE MATURITY OF LEASE LIABILITIES (Details)	Mar. 31, 2019 USD ($)
Operating leases
2019 (excluding first three months of 2019)	$ 60,000,000
2020	69,000,000
2021	65,000,000
2022	59,000,000
2023	50,000,000
Thereafter	479,000,000
Total undiscounted lease payments	782,000,000
Less: imputed interest	(275,000,000)
Total lease liabilities	507,000,000
Less: current lease liabilities	(52,000,000)
Long-term lease liabilities	455,000,000
Finance leases
2019 (excluding first three months of 2019)	146,000,000
2020	190,000,000
2021	188,000,000
2022	188,000,000
2023	188,000,000
Thereafter	2,806,000,000
Total undiscounted lease payments	3,706,000,000
Less: imputed interest	(2,429,000,000)
Total lease liabilities	1,277,000,000
Less: current lease liabilities	(21,000,000)
Long-term lease liabilities	1,256,000,000
Southern California Gas Company [Member]
Operating leases
2019 (excluding first three months of 2019)	20,000,000
2020	22,000,000
2021	20,000,000
2022	17,000,000
2023	13,000,000
Thereafter	31,000,000
Total undiscounted lease payments	123,000,000
Less: imputed interest	(13,000,000)
Total lease liabilities	110,000,000
Less: current lease liabilities	(22,000,000)
Long-term lease liabilities	88,000,000
Finance leases
2019 (excluding first three months of 2019)	3,000,000
2020	1,000,000
2021	0
2022	0
2023	0
Thereafter	1,000,000
Total undiscounted lease payments	5,000,000
Less: imputed interest	0
Total lease liabilities	5,000,000
Less: current lease liabilities	(3,000,000)
Long-term lease liabilities	2,000,000
San Diego Gas and Electric Company [Member]
Operating leases
2019 (excluding first three months of 2019)	24,000,000
2020	25,000,000
2021	24,000,000
2022	21,000,000
2023	17,000,000
Thereafter	42,000,000
Total undiscounted lease payments	153,000,000
Less: imputed interest	(19,000,000)
Total lease liabilities	134,000,000
Less: current lease liabilities	(24,000,000)
Long-term lease liabilities	110,000,000
Finance leases
2019 (excluding first three months of 2019)	143,000,000
2020	189,000,000
2021	188,000,000
2022	188,000,000
2023	188,000,000
Thereafter	2,805,000,000
Total undiscounted lease payments	3,701,000,000
Less: imputed interest	(2,429,000,000)
Total lease liabilities	1,272,000,000
Less: current lease liabilities	(18,000,000)
Long-term lease liabilities	$ 1,254,000,000

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COMMITMENTS AND CONTINGENCIES - FUTURE MINIMUM LEASE PAYMENTS UNDER TOPIC 840 (Details) $ in Millions	Dec. 31, 2018 USD ($)
Capital Leases [Abstract]
2019	$ 215
2020	210
2021	211
2022	211
2023	211
Thereafter	3,196
Total undiscounted lease payments	4,254
Less: estimated executory costs	(480)
Less: imputed interest	(2,483)
Total future minimum lease payments	1,291
Leases, Operating [Abstract]
2019	77
2020	55
2021	53
2022	50
2023	42
Thereafter	253
Total undiscounted lease payments	530
HQ Build To Suit Lease [Member]
Capital Leases [Abstract]
2019	10
2020	11
2021	11
2022	11
2023	11
Thereafter	217
Total undiscounted lease payments	271
San Diego Gas and Electric Company [Member]
Capital Leases [Abstract]
2019	212
2020	210
2021	211
2022	211
2023	211
Thereafter	3,196
Total undiscounted lease payments	4,251
Less: estimated executory costs	(480)
Less: imputed interest	(2,483)
Total future minimum lease payments	1,288
Leases, Operating [Abstract]
2019	23
2020	22
2021	22
2022	21
2023	17
Thereafter	48
Total undiscounted lease payments	153
Southern California Gas Company [Member]
Capital Leases [Abstract]
2019	3
2020	0
2021	0
2022	0
2023	0
Thereafter	0
Total undiscounted lease payments	3
Less: estimated executory costs	0
Less: imputed interest	0
Total future minimum lease payments	3
Leases, Operating [Abstract]
2019	26
2020	22
2021	21
2022	20
2023	16
Thereafter	28
Total undiscounted lease payments	$ 133

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COMMITMENTS AND CONTINGENCIES - LESSOR INFORMATION (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018	[1]
Lessee, Lease, Description [Line Items]
Property, plant and equipment	$ 47,105		$ 46,615
Accumulated depreciation	(12,407)		(12,176)
Property, plant and equipment, net	34,698		$ 34,439
Lessor, Operating Lease, Payments, Fiscal Year Maturity [Abstract]
2019 (excluding first three months of 2019)	151
2020	200
2021	200
2022	200
2023	200
Thereafter	2,619
Total undiscounted cash flows	3,570
Minimum lease payments	50	$ 49
Variable lease payments	4	13
Total revenues from operating leases	54	62
Assets Leased to Others [Member]
Lessee, Lease, Description [Line Items]
Assets held for sale	148
Property, plant and equipment	1,026
Accumulated depreciation	(151)
Property, plant and equipment, net	875
Lessor, Operating Lease, Payments, Fiscal Year Maturity [Abstract]
Depreciation	$ 9	$ 17

[1] Derived from audited financial statements.

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COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS (Details) - Sempra LNG [Member] - Liquefied Natural Gas Contracts [Member] $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Unrecorded Unconditional Purchase Obligation [Line Items]
Increase (decrease) in commitment amount, 2019	$ (96)
Increase (decrease) in commitment amount, 2020	19
Increase (decrease) in commitment amount, 2021	8
Increase (decrease) in commitment amount, 2022	3
Increase (decrease) in commitment amount, 2023	2
Increase (decrease) in commitment amount, thereafter	$ 52

XML

SEGMENT INFORMATION (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($) segment facility	Mar. 31, 2018 USD ($)	Dec. 31, 2018 USD ($)
Segment Reporting Information [Line Items]
Number of reportable segments | segment	6
Wind generation facility | facility	1
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 2,898	$ 2,536
INTEREST EXPENSE	260	206
INTEREST INCOME	21	29
DEPRECIATION AND AMORTIZATION	383	372
Income Tax Expense (Benefit)	42	242
Equity earnings before income tax:	5	5
Equity earnings (losses) net of income tax:	96	(26)
Equity earnings (losses)	101	(21)
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	441	347
Discontinued operations	(51)	21
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	783	979
ASSETS	61,618		$ 60,638	[1]
EQUITY METHOD AND OTHER INVESTMENTS	12,038		11,972
Operating Segments [Member] | SDG&E [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	1,145	1,055
INTEREST EXPENSE	103	52
INTEREST INCOME	1	1
DEPRECIATION AND AMORTIZATION	186	166
Income Tax Expense (Benefit)	5	56
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	176	170
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	356	475
ASSETS	19,558		19,225
Operating Segments [Member] | SoCalGas [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	1,361	1,126
INTEREST EXPENSE	34	27
DEPRECIATION AND AMORTIZATION	147	135
Income Tax Expense (Benefit)	19	59
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	264	225
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	324	403
ASSETS	15,904		15,389
Operating Segments [Member] | Sempra Texas Utility [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Equity earnings (losses) net of income tax:	94	15
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	94	15
Segment Reporting Information, Additional Information [Abstract]
ASSETS	9,748		9,652
EQUITY METHOD AND OTHER INVESTMENTS	9,748		9,652
Operating Segments [Member] | Sempra Mexico [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	383	308
INTEREST EXPENSE	30	30
INTEREST INCOME	19	15
DEPRECIATION AND AMORTIZATION	44	43
Income Tax Expense (Benefit)	72	155
Equity earnings (losses) net of income tax:	2	(41)
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	57	20
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	85	59
ASSETS	9,382		9,165
EQUITY METHOD AND OTHER INVESTMENTS	737		747
Operating Segments [Member] | Sempra Renewables [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	7	25
INTEREST EXPENSE	3	5
INTEREST INCOME	10	2
DEPRECIATION AND AMORTIZATION	0	13
Income Tax Expense (Benefit)	(10)	(7)
Equity earnings before income tax:	3	5
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	13	21
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	0	31
ASSETS	1,310		2,549
EQUITY METHOD AND OTHER INVESTMENTS	290		291
Operating Segments [Member] | Sempra LNG [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	141	104
INTEREST EXPENSE	4	8
INTEREST INCOME	14	13
DEPRECIATION AND AMORTIZATION	2	11
Income Tax Expense (Benefit)	4	12
Equity earnings before income tax:	2	0
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	5	(16)
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	18	6
ASSETS	3,731		4,060
EQUITY METHOD AND OTHER INVESTMENTS	1,255		1,271
Segment Reconciling Items [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	0	(1)
INTEREST EXPENSE	109	112
INTEREST INCOME	1	16
DEPRECIATION AND AMORTIZATION	4	4
Income Tax Expense (Benefit)	(48)	(33)
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	(117)	(109)
Discontinued operations	(51)	21
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	0	5
ASSETS	1,135		1,070
Discontinued operations	3,845		3,718
EQUITY METHOD AND OTHER INVESTMENTS	8		11
Intersegment eliminations [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(139)	(81)
INTEREST EXPENSE	(23)	(28)
INTEREST INCOME	(24)	(18)
Segment Reporting Information, Additional Information [Abstract]
ASSETS	(2,995)		$ (4,190)
Intersegment eliminations [Member] | SDG&E [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	1	1
Intersegment eliminations [Member] | SoCalGas [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	17	17
Intersegment eliminations [Member] | Sempra Mexico [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	28	29
Intersegment eliminations [Member] | Sempra LNG [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 93	$ 34
Oncor Electric Delivery Company LLC. [Member] | Oncor Holdings [Member] | Sempra Texas Utility [Member]
Segment Reporting Information [Line Items]
Ownership interest	80.25%

[1] Derived from audited financial statements.