Sempra 8K 2011 Other Events | SRE Filing

Sempra (SRE) 8-K2011 FY Other Events

Exhibit 99.5

The information provided in this Exhibit is presented only in connection with the reporting changes described in the accompanying Form 8-K. This information does not reflect events occurring after February 28, 2012, the date we filed our 2011 Form 10-K, and does not modify or update the disclosures therein in any way, other than as required to reflect the change in segments, the change in accounting principle and the adoption of a new accounting standard, as described in the Form 8-K and set forth in Exhibits 99.1 through 99.6 attached thereto. You should therefore read this information in conjunction with the 2011 Form 10-K and subsequent amendments on Form 10-K/A and with our reports filed with the Securities and Exchange Commission after February 28, 2012.

PART II

ITEM 9A. CONTROLS AND PROCEDURES

EVALUATION OF DISCLOSURE CONTROLS AND PROCEDURES

SEMPRA ENERGY, SDG&E, SOCALGAS

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 Securities and Exchange Commission and is accumulated and communicated to the management of each company, including each respective Chief Executive Officer and Chief 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 Chief Executive Officers and Chief 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 December 31, 2011, the end of the period covered by this report. Based on these evaluations, the Chief Executive Officers and Chief 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.

MANAGEMENT’S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

SEMPRA ENERGY, SDG&E, SOCALGAS

The respective management of each company is responsible for establishing and maintaining adequate internal control over financial reporting, as defined in Exchange Act Rules 13a-15(f). Under the supervision and with the participation of the management of each company, including each company’s principal executive officer and principal financial officer, the effectiveness of each company’s internal control over financial reporting was evaluated based on the framework in Internal Control – Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on the evaluations, each company concluded that its internal control over financial reporting was effective as of December 31, 2011. Deloitte & Touche, LLP audited the effectiveness of each company’s internal control over financial reporting as of December 31, 2011, as stated in their reports, which are included herein.

There have been no changes in the companies’ 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.

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

REPORTS OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

SEMPRA ENERGY

To the Board of Directors and Shareholders of Sempra Energy:

We have audited the accompanying consolidated balance sheets of Sempra Energy and subsidiaries (the “Company”) as of December 31, 2011 and 2010, and the related consolidated statements of operations, comprehensive income, changes in equity, and cash flows for each of the three years in the period ended December 31, 2011. Our audits also included the financial statement schedule listed in Exhibit 99.6. These financial statements and financial statement schedule are the responsibility of the Company’s management. Our responsibility is to express an opinion on the financial statements and financial statement schedule based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of Sempra Energy and subsidiaries as of December 31, 2011 and 2010, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2011, in conformity with accounting principles generally accepted in the United States of America. Also, in our opinion, such financial statement schedule, when considered in relation to the basic consolidated financial statements taken as a whole, presents fairly, in all material respects, the information set forth therein.

The accompanying consolidated financial statements and financial statement schedule have been retrospectively adjusted, as applicable, for the i) change in reportable segments, ii) change in the method of accounting for investment tax credits from the flow-through method to the deferral method, and iii) change in method of presenting comprehensive income due to the adoption of a new accounting standard, as discussed in Note 1 to the consolidated financial statements.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 28, 2012 expressed an unqualified opinion on the Company’s internal control over financial reporting.

/S/ DELOITTE & TOUCHE LLP

San Diego, California

February 28, 2012

(May 11, 2012 as to the effects of the changes in reportable segments, accounting for investment tax credits, and the method of presenting comprehensive income as described in Note 1 to the consolidated financial statements)

To the Board of Directors and Shareholders of Sempra Energy:

We have audited the internal control over financial reporting of Sempra Energy and subsidiaries (the “Company”) as of December 31, 2011, based on criteria established in Internal Control —Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed by, or under the supervision of, the company’s principal executive and principal financial officers, or persons performing similar functions, and effected by the company’s board of directors, management, and other personnel 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. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control —Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements and financial statement schedule as of and for the year ended December 31, 2011 of the Company and our report dated February 28, 2012 (May 11, 2012 as to the effects of the changes in reportable segments, accounting for investment tax credits, and the method of presenting comprehensive income as described in Note 1 to the consolidated financial statements) expressed an unqualified opinion on those financial statements and financial statement schedule, and included an explanatory paragraph concerning the i) retrospective change in reportable segments, ii) retrospective change in method of accounting for investment tax credits from the flow-through method to the deferral method, and iii) retrospective change in method of presenting comprehensive income due to the adoption of a new accounting standard.

/S/ DELOITTE & TOUCHE LLP

San Diego, California

February 28, 2012

SAN DIEGO GAS & ELECTRIC COMPANY

To the Board of Directors and Shareholders of San Diego Gas & Electric Company:

We have audited the internal control over financial reporting of San Diego Gas & Electric Company (the “Company”) as of December 31, 2011, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements as of and for the year ended December 31, 2011 of the Company and our report dated February 28, 2012 expressed an unqualified opinion on those financial statements.

/S/ DELOITTE & TOUCHE LLP

San Diego, California

February 28, 2012

To the Board of Directors and Shareholders of San Diego Gas & Electric Company:

We have audited the accompanying consolidated balance sheets of San Diego Gas & Electric Company (the “Company”) as of December 31, 2011 and 2010, and the related consolidated statements of operations, comprehensive income and changes in equity, and cash flows for each of the three years in the period ended December 31, 2011. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of San Diego Gas & Electric Company as of December 31, 2011 and 2010, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2011, in conformity with accounting principles generally accepted in the United States of America.

/S/ DELOITTE & TOUCHE LLP

San Diego, California

February 28, 2012

SOUTHERN CALIFORNIA GAS COMPANY

To the Board of Directors and Shareholders of Southern California Gas Company:

We have audited the internal control over financial reporting of Southern California Gas Company and subsidiaries (the “Company”) as of December 31, 2011, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.

/S/ DELOITTE & TOUCHE LLP

San Diego, California

February 28, 2012

To the Board of Directors and Shareholders of Southern California Gas Company:

We have audited the accompanying consolidated balance sheets of Southern California Gas Company and subsidiaries (the “Company”) as of December 31, 2011 and 2010, and the related consolidated statements of operations, comprehensive income and changes in shareholders’ equity, and cash flows for each of the three years in the period ended December 31, 2011. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of Southern California Gas Company and subsidiaries as of December 31, 2011 and 2010, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2011, in conformity with accounting principles generally accepted in the United States of America.

/S/ DELOITTE & TOUCHE LLP

San Diego, California

February 28, 2012

SEMPRA ENERGY
CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions, except per share amounts)
		Years ended December 31,
		2011(1)		2010(1)		2009(1)

REVENUES
Utilities		$	8,322	$	7,019	$	6,421
Energy-related businesses			1,714		1,984		1,685
Total revenues			10,036		9,003		8,106
EXPENSES AND OTHER INCOME
Utilities:
Cost of natural gas			(1,866)		(2,012)		(1,645)
Cost of electric fuel and purchased power			(1,397)		(637)		(672)
Energy-related businesses:
Cost of natural gas, electric fuel and purchased power			(746)		(1,046)		(864)
Other cost of sales			(137)		(88)		(77)
Litigation expense			(37)		(169)		(4)
Other operation and maintenance			(2,788)		(2,499)		(2,467)
Depreciation and amortization			(976)		(866)		(775)
Franchise fees and other taxes			(343)		(327)		(296)
Write-off of long-lived assets			―		―		(132)
Equity earnings (losses), before income tax:
RBS Sempra Commodities LLP			(24)		(314)		463
Other			33		22		36
Remeasurement of equity method investments			277		―		―
Other income, net			130		140		149
Interest income			26		16		21
Interest expense			(465)		(436)		(367)
Income before income taxes and equity earnings
of certain unconsolidated subsidiaries			1,723		787		1,476
Income tax expense			(394)		(133)		(422)
Equity earnings, net of income tax			52		49		68
Net income			1,381		703		1,122
(Earnings) losses attributable to noncontrolling interests			(42)		16		7
Preferred dividends of subsidiaries			(8)		(10)		(10)
Earnings		$	1,331	$	709	$	1,119


Basic earnings per common share		$	5.55	$	2.90	$	4.60
Weighted-average number of shares outstanding, basic (thousands)			239,720		244,736		243,339

Diluted earnings per common share		$	5.51	$	2.86	$	4.52
Weighted-average number of shares outstanding, diluted (thousands)			241,523		247,942		247,384

Dividends declared per share of common stock		$	1.92	$	1.56	$	1.56
(1)	As adjusted for the retrospective effect of a change in accounting principle as we discuss in Note 1.
See Notes to Consolidated Financial Statements.

SEMPRA ENERGY
CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME
(Dollars in millions)
		Years ended December 31, 2011, 2010 and 2009
		Sempra Energy Shareholders' Equity
		Pretax		Income Tax		Net-of-tax		Noncontrolling
		Amount(1)		(Expense) Benefit		Amount		Interests (After-tax)		Total
2011:
Net income(2)		$	1,339			$	1,339	$	42	$	1,381
Other comprehensive income (loss):
Foreign currency translation adjustments			(79)	$	3		(76)		6		(70)
Reclassification to net income of foreign
currency translation adjustment related
to remeasurement of equity method
investments			(54)		―		(54)		―		(54)
Available-for-sale securities			(2)		1		(1)		―		(1)
Pension and other postretirement benefits			(20)		8		(12)		―		(12)
Financial instruments			(26)		10		(16)		(36)		(52)
Total other comprehensive income (loss)			(181)		22		(159)		(30)		(189)
Total comprehensive income(2)			1,158		22		1,180		12		1,192
Preferred dividends of subsidiaries			(8)		―		(8)		―		(8)
Total comprehensive income, after preferred
dividends of subsidiaries		$	1,150	$	22	$	1,172	$	12	$	1,184
2010:
Net income (loss)(2)		$	719			$	719	$	(16)	$	703
Other comprehensive income (loss):
Foreign currency translation adjustments			47	$	―		47		―		47
Available-for-sale securities			(10)		2		(8)		―		(8)
Pension and other postretirement benefits			23		(10)		13		―		13
Financial instruments			(22)		9		(13)		7		(6)
Total other comprehensive income			38		1		39		7		46
Total comprehensive income (loss)(2)			757		1		758		(9)		749
Preferred dividends of subsidiaries			(10)		―		(10)		―		(10)
Total comprehensive income (loss), after
Preferred dividends of subsidiaries		$	747	$	1	$	748	$	(9)	$	739
2009:
Net income (loss)(2)		$	1,129			$	1,129	$	(7)	$	1,122
Other comprehensive income (loss):
Foreign currency translation adjustments			102	$	―		102		―		102
Available-for-sale securities			9		(2)		7		―		7
Pension and other postretirement benefits			(6)		3		(3)		―		(3)
Financial instruments			60		(22)		38		(3)		35
Total other comprehensive income (loss)			165		(21)		144		(3)		141
Total comprehensive income (loss)(2)			1,294		(21)		1,273		(10)		1,263
Preferred dividends of subsidiaries			(10)		―		(10)		―		(10)
Total comprehensive income (loss), after
preferred dividends of subsidiaries		$	1,284	$	(21)	$	1,263	$	(10)	$	1,253
(1)	Except for Net Income (Loss) and Total Comprehensive Income (Loss).
(2)	As adjusted for the retrospective effect of a change in accounting principle as we discuss in Note 1.
See Notes to Consolidated Financial Statements.

SEMPRA ENERGY
CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
		December 31,		December 31,
		2011(1)		2010(1)
ASSETS
Current assets:
Cash and cash equivalents		$	252	$	912
Restricted cash			24		131
Trade accounts receivable, net			1,198		891
Other accounts and notes receivable, net			147		141
Due from unconsolidated affiliates			―		34
Income taxes receivable			―		257
Deferred income taxes			―		75
Inventories			346		258
Regulatory balancing accounts – undercollected			38		―
Regulatory assets			89		90
Fixed-price contracts and other derivatives			85		81
Settlements receivable related to wildfire litigation			10		300
Other			143		193
Total current assets			2,332		3,363

Investments and other assets:
Restricted cash			22		27
Regulatory assets arising from pension and other postretirement
benefit obligations			1,126		869
Regulatory assets arising from wildfire litigation costs			594		364
Other regulatory assets			1,060		934
Nuclear decommissioning trusts			804		769
Investment in RBS Sempra Commodities LLP			126		787
Other investments			1,545		2,164
Goodwill			1,036		87
Other intangible assets			448		453
Sundry			691		600
Total investments and other assets			7,452		7,054

Property, plant and equipment:
Property, plant and equipment			31,192		27,023
Less accumulated depreciation and amortization			(7,727)		(7,209)
Property, plant and equipment, net ($494 and $516 at December 31, 2011 and
2010, respectively, related to VIE)			23,465		19,814
Total assets		$	33,249	$	30,231
(1)	As adjusted for the retrospective effect of a change in accounting principle as we discuss in Note 1.
See Notes to Consolidated Financial Statements.

SEMPRA ENERGY
CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
		December 31,		December 31,
		2011(1)		2010(1)
LIABILITIES AND EQUITY
Current liabilities:
Short-term debt		$	449	$	158
Accounts payable – trade			983		755
Accounts payable – other			124		109
Due to unconsolidated affiliates			―		36
Income taxes payable			5		―
Deferred income taxes			173		―
Dividends and interest payable			219		188
Accrued compensation and benefits			323		311
Regulatory balancing accounts – overcollected			105		241
Current portion of long-term debt			336		349
Fixed-price contracts and other derivatives			92		106
Customer deposits			142		129
Reserve for wildfire litigation			586		639
Other			615		765
Total current liabilities			4,152		3,786
Long-term debt ($345 and $355 at December 31, 2011 and 2010, respectively,
related to VIE)			10,078		8,980

Deferred credits and other liabilities:
Customer advances for construction			142		154
Pension and other postretirement benefit obligations, net of plan assets			1,423		1,105
Deferred income taxes			1,520		1,545
Deferred investment tax credits			49		50
Regulatory liabilities arising from removal obligations			2,551		2,630
Asset retirement obligations			1,905		1,449
Other regulatory liabilities			87		138
Fixed-price contracts and other derivatives			301		290
Deferred credits and other			784		824
Total deferred credits and other liabilities			8,762		8,185
Contingently redeemable preferred stock of subsidiary			79		79

Commitments and contingencies (Note 15)

Equity:
Preferred stock (50 million shares authorized; none issued)			―		―
Common stock (750 million shares authorized; 240 million
shares outstanding at December 31, 2011 and 2010; no par value)			2,104		2,036
Retained earnings			8,162		7,292
Deferred compensation			(2)		(8)
Accumulated other comprehensive income (loss)			(489)		(330)
Total Sempra Energy shareholders’ equity			9,775		8,990
Preferred stock of subsidiaries			20		100
Other noncontrolling interests			383		111
Total equity			10,178		9,201
Total liabilities and equity		$	33,249	$	30,231
(1)	As adjusted for the retrospective effect of a change in accounting principle as we discuss in Note 1.
See Notes to Consolidated Financial Statements.

SEMPRA ENERGY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in millions)
		Years ended December 31,
		2011(1)		2010(1)		2009(1)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income		$	1,381	$	703	$	1,122
Adjustments to reconcile net income to net cash provided
by operating activities:
Depreciation and amortization			976		866		775
Deferred income taxes and investment tax credits			3		37		295
Equity (earnings) losses			(61)		243		(567)
Remeasurement of equity method investments			(277)		―		―
Write-off of long-lived assets			―		―		132
Fixed-price contracts and other derivatives			2		13		(30)
Other			(15)		(55)		(48)
Net change in other working capital components			(224)		100		(256)
Distributions from RBS Sempra Commodities LLP			53		198		407
Changes in other assets			34		54		139
Changes in other liabilities			(5)		(5)		(94)
Net cash provided by operating activities			1,867		2,154		1,875

CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment			(2,844)		(2,062)		(1,912)
Proceeds from sale of assets			2		303		179
Expenditures for investments and acquisition of businesses,
net of cash acquired			(941)		(611)		(939)
Distributions from RBS Sempra Commodities LLP			570		849		―
Distributions from other investments			64		371		23
Purchases of nuclear decommissioning and other trust assets			(755)		(371)		(267)
Proceeds from sales by nuclear decommissioning and other trusts			753		372		230
Decrease in restricted cash			653		195		37
Increase in restricted cash			(541)		(318)		(45)
Decrease in notes receivable from unconsolidated affiliate			―		―		100
Purchase of bonds issued by unconsolidated affiliate			―		―		(50)
Other			(31)		(11)		(28)
Net cash used in investing activities			(3,070)		(1,283)		(2,672)

CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid			(440)		(364)		(341)
Redemption of subsidiary preferred stock			(80)		―		―
Preferred dividends paid by subsidiaries			(8)		(10)		(10)
Issuances of common stock			28		40		73
Repurchases of common stock			(18)		(502)		(22)
Issuances of debt (maturities greater than 90 days)			2,098		1,125		2,151
Payments on debt (maturities greater than 90 days)			(482)		(905)		(435)
(Decrease) increase in short-term debt, net			(498)		568		(659)
Payments on notes payable to unconsolidated affiliate			―		―		(100)
Purchase of noncontrolling interests			(43)		―		(94)
Other			(23)		(21)		13
Net cash provided by (used in) financing activities			534		(69)		576

Effect of exchange rate changes on cash and cash equivalents			9		―		―

(Decrease) increase in cash and cash equivalents			(660)		802		(221)
Cash and cash equivalents, January 1			912		110		331
Cash and cash equivalents, December 31		$	252	$	912	$	110
(1)	As adjusted for the retrospective effect of a change in accounting principle as we discuss in Note 1.
See Notes to Consolidated Financial Statements.

SEMPRA ENERGY
CONSOLIDATED STATEMENTS OF CASH FLOWS (CONTINUED)
(Dollars in millions)
		Years ended December 31,
		2011(1)		2010(1)		2009(1)
CHANGES IN OTHER WORKING CAPITAL COMPONENTS
(Excluding cash and cash equivalents, and debt due within one year)
Accounts and notes receivable		$	(32)	$	89	$	(190)
Income taxes, net			269		12		(17)
Inventories			(84)		(62)		124
Regulatory balancing accounts			(150)		(155)		42
Regulatory assets and liabilities			(2)		6		(1)
Other current assets			295		310		685
Accounts and notes payable			60		79		(109)
Other current liabilities			(580)		(179)		(790)
Net change in other working capital components		$	(224)	$	100	$	(256)

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized		$	440	$	415	$	326
Income tax payments, net of refunds			144		68		112

SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING ACTIVITIES
Acquisition of businesses:
Assets acquired		$	2,833	$	303	$	―
Cash paid, net of cash acquired			(611)		(292)		―
Fair value of equity method investments immediately prior to the acquisition			(882)		―		―
Fair value of noncontrolling interests			(279)		―		―
Additional consideration accrued			(32)		―		―
Liabilities assumed		$	1,029	$	11	$	―

Increase in capital lease obligations for investments in property, plant and equipment		$	―	$	192	$	50
Accrued capital expenditures			368		341		247
Return of investment (industrial development bonds)			180		―		―

SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES
Dividends declared but not paid		$	120	$	96	$	99
Cancellation of debt (industrial development bonds)			180		―		―
Conversion of debt into equity			30		―		―
(1)	As adjusted for the retrospective effect of a change in accounting principle as we discuss in Note 1.
See Notes to Consolidated Financial Statements.

SEMPRA ENERGY
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
(Dollars in millions)
		Years ended December 31, 2011(1), 2010(1) and 2009(1)
						Deferred
						Compen-		Accumulated
						sation		Other		Sempra
						Relating		Compre-		Energy		Non-
		Common		Retained		to		hensive		Shareholders’		controlling		Total
		Stock		Earnings		ESOP		Income (Loss)		Equity		Interests		Equity
Balance at December 31, 2008		$	2,265	$	6,235	$	(18)	$	(513)	$	7,969	$	340	$	8,309

Net income (loss)					1,129						1,129		(7)		1,122
Other comprehensive income (loss)									144		144		(3)		141

Cumulative effect of change in accounting
principle					(7)						(7)				(7)
Share-based compensation expense			38								38				38
Common stock dividends declared					(383)						(383)				(383)
Preferred dividends of subsidiaries					(10)						(10)				(10)
Issuance of common stock			114								114				114
Tax benefit related to share-based
compensation			23								23				23
Repurchases of common stock			(22)								(22)				(22)
Common stock released from ESOP			10				5				15				15
Equity contributed by noncontrolling interests													7		7
Distributions to noncontrolling interests													(9)		(9)
Purchase of noncontrolling interest in
subsidiary			(10)								(10)		(84)		(94)
Balance at December 31, 2009			2,418		6,964		(13)		(369)		9,000		244		9,244

Net income (loss)					719						719		(16)		703
Other comprehensive income									39		39		7		46

Share-based compensation expense			38								38				38
Common stock dividends declared					(381)						(381)				(381)
Preferred dividends of subsidiaries					(10)						(10)				(10)
Issuance of common stock			64								64				64
Tax benefit related to share-based
compensation			5								5				5
Repurchases of common stock			(502)								(502)				(502)
Common stock released from ESOP			13				5				18				18
Distributions to noncontrolling interests													(24)		(24)
Balance at December 31, 2010		$	2,036	$	7,292	$	(8)	$	(330)	$	8,990	$	211	$	9,201
(1)	As adjusted for the retrospective effect of a change in accounting principle as we discuss in Note 1.
See Notes to Consolidated Financial Statements.

SEMPRA ENERGY
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY (CONTINUED)
(Dollars in millions)
		Years ended December 31, 2011(1), 2010(1) and 2009(1)
						Deferred
						Compen-		Accumulated
						sation		Other		Sempra
						Relating		Compre-		Energy		Non-
		Common		Retained		to		hensive		Shareholders’		controlling		Total
		Stock		Earnings		ESOP		Income (Loss)		Equity		Interests		Equity
Balance at December 31, 2010		$	2,036	$	7,292	$	(8)	$	(330)	$	8,990	$	211	$	9,201

Net income					1,339						1,339		42		1,381
Other comprehensive loss									(159)		(159)		(30)		(189)

Share-based compensation expense			48								48				48
Common stock dividends declared					(461)						(461)				(461)
Preferred dividends of subsidiaries					(8)						(8)				(8)
Issuance of common stock			28								28				28
Repurchases of common stock			(18)								(18)				(18)
Common stock released from ESOP			14				6				20				20
Distributions to noncontrolling interests													(16)		(16)
Equity contributed by noncontrolling interests													36		36
Acquisition of South American entities													279		279
Purchase of noncontrolling interests in
subsidiary			(4)								(4)		(39)		(43)
Redemption of preferred stock of subsidiary													(80)		(80)
Balance at December 31, 2011		$	2,104	$	8,162	$	(2)	$	(489)	$	9,775	$	403	$	10,178
(1)	As adjusted for the retrospective effect of a change in accounting principle as we discuss in Note 1.
See Notes to Consolidated Financial Statements.

SAN DIEGO GAS & ELECTRIC COMPANY
CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
	Years ended December 31,
	2011		2010		2009
Operating revenues
Electric	$	2,830	$	2,535	$	2,426
Natural gas		543		514		490
Total operating revenues		3,373		3,049		2,916
Operating expenses
Cost of electric fuel and purchased power		715		637		672
Cost of natural gas		226		217		206
Operation and maintenance		1,072		987		960
Depreciation and amortization		422		381		329
Franchise fees and other taxes		183		170		160
Total operating expenses		2,618		2,392		2,327
Operating income		755		657		589
Other income, net		79		10		64
Interest income		―		―		1
Interest expense		(142)		(136)		(104)
Income before income taxes		692		531		550
Income tax expense		(237)		(173)		(177)
Net income		455		358		373
(Earnings) losses attributable to noncontrolling interest		(19)		16		(24)
Earnings		436		374		349
Preferred dividend requirements		(5)		(5)		(5)
Earnings attributable to common shares	$	431	$	369	$	344
See Notes to Consolidated Financial Statements.

SAN DIEGO GAS & ELECTRIC COMPANY
CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	December 31,		December 31,
	2011		2010
ASSETS
Current assets:
Cash and cash equivalents	$	29	$	127
Restricted cash		21		116
Accounts receivable – trade, net		267		248
Accounts receivable – other, net		23		59
Due from unconsolidated affiliates		67		12
Income taxes receivable		102		37
Deferred income taxes		―		129
Inventories		82		71
Regulatory balancing accounts, net		38		―
Regulatory assets arising from fixed-price contracts and other derivatives		67		66
Other regulatory assets		11		5
Fixed-price contracts and other derivatives		27		28
Settlements receivable related to wildfire litigation		10		300
Other		51		50
Total current assets		795		1,248

Other assets:
Restricted cash		22		―
Deferred taxes recoverable in rates		570		502
Regulatory assets arising from fixed-price contracts and other derivatives		191		233
Regulatory assets arising from pension and other postretirement
benefit obligations		309		279
Regulatory assets arising from wildfire litigation costs		594		364
Other regulatory assets		160		73
Nuclear decommissioning trusts		804		769
Sundry		70		56
Total other assets		2,720		2,276

Property, plant and equipment:
Property, plant and equipment		13,003		11,247
Less accumulated depreciation and amortization		(2,963)		(2,694)
Property, plant and equipment, net ($494 and $516 at December 31, 2011
and 2010, respectively, related to VIE)		10,040		8,553
Total assets	$	13,555	$	12,077
See Notes to Consolidated Financial Statements.

SAN DIEGO GAS & ELECTRIC COMPANY
CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	December 31,		December 31,
	2011		2010
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	375	$	292
Due to unconsolidated affiliate		14		16
Deferred income taxes		62		―
Accrued compensation and benefits		124		115
Regulatory balancing accounts, net		―		61
Current portion of long-term debt		19		19
Fixed-price contracts and other derivatives		55		51
Customer deposits		62		54
Reserve for wildfire litigation		586		639
Other		139		136
Total current liabilities		1,436		1,383
Long-term debt ($345 and $355 at December 31, 2011 and 2010, respectively,
related to VIE)		4,058		3,479

Deferred credits and other liabilities:
Customer advances for construction		20		21
Pension and other postretirement benefit obligations, net of plan assets		342		309
Deferred income taxes		1,167		1,001
Deferred investment tax credits		26		25
Regulatory liabilities arising from removal obligations		1,462		1,409
Asset retirement obligations		693		619
Fixed-price contracts and other derivatives		243		248
Deferred credits and other		188		283
Total deferred credits and other liabilities		4,141		3,915
Contingently redeemable preferred stock		79		79

Commitments and contingencies (Note 15)

Equity:
Common stock (255 million shares authorized; 117 million shares outstanding;
no par value)		1,338		1,138
Retained earnings		2,411		1,980
Accumulated other comprehensive income (loss)		(10)		(10)
Total SDG&E shareholder’s equity		3,739		3,108
Noncontrolling interest		102		113
Total equity		3,841		3,221
Total liabilities and equity	$	13,555	$	12,077
See Notes to Consolidated Financial Statements.

SAN DIEGO GAS & ELECTRIC COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in millions)
	Years ended December 31,
	2011		2010		2009
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	455	$	358	$	373
Adjustments to reconcile net income to net cash provided by
operating activities:
Depreciation and amortization		422		381		329
Deferred income taxes and investment tax credits		290		52		73
Fixed-price contracts and other derivatives		(13)		22		(41)
Other		(68)		(32)		(21)
Changes in other assets		33		14		23
Changes in other liabilities		7		(3)		(53)
Changes in working capital components:
Accounts receivable		6		―		(53)
Due to/from affiliates, net		6		(2)		―
Inventories		(11)		(10)		1
Other current assets		309		343		660
Income taxes		(111)		12		(44)
Accounts payable		68		23		1
Regulatory balancing accounts		(87)		(99)		32
Interest payable		6		10		―
Other current liabilities		(430)		(340)		(639)
Net cash provided by operating activities		882		729		641
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment		(1,831)		(1,210)		(955)
Expenditures for short-term investments		―		―		(152)
Proceeds from sale of short-term investments		―		―		176
Purchases of nuclear decommissioning trust assets		(748)		(362)		(237)
Proceeds from sales by nuclear decommissioning trusts		741		352		230
Decrease in loans to affiliates, net		―		14		20
Proceeds from sale of assets		1		―		1
Decrease in restricted cash		520		152		37
Increase in restricted cash		(447)		(260)		(45)
Net cash used in investing activities		(1,764)		(1,314)		(925)
CASH FLOWS FROM FINANCING ACTIVITIES
Capital contribution		200		―		―
Common dividends paid		―		―		(150)
Preferred dividends paid		(5)		(5)		(5)
Issuances of long-term debt		598		744		439
Payments on long-term debt		(10)		(10)		(2)
Increase in short-term debt, net		―		―		4
Capital contribution received by Otay Mesa VIE		5		―		4
Capital distributions made by Otay Mesa VIE		―		(24)		(9)
Other		(4)		(6)		(3)
Net cash provided by financing activities		784		699		278
(Decrease) increase in cash and cash equivalents		(98)		114		(6)
Cash and cash equivalents, January 1		127		13		19
Cash and cash equivalents, December 31	$	29	$	127	$	13
See Notes to Consolidated Financial Statements.

SAN DIEGO GAS & ELECTRIC COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS (CONTINUED)
(Dollars in millions)
	Years ended December 31,
	2011		2010		2009
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	$	131	$	120	$	99
Income tax payments, net of refunds		59		108		148

SUPPLEMENTAL DISCLOSURE OF NONCASH ACTIVITIES
Increase in capital lease obligations for investments in property, plant
and equipment	$	―	$	188	$	21
Accrued capital expenditures		187		173		157
Dividends declared but not paid		1		1		1
See Notes to Consolidated Financial Statements.

SAN DIEGO GAS & ELECTRIC COMPANY
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME AND CHANGES IN EQUITY
(Dollars in millions)
	Years ended December 2011, 2010 and 2009
					Accumulated
					Other		SDG&E
	Common		Retained		Comprehensive		Shareholder’s		Noncontrolling		Total
	Stock		Earnings		Income (Loss)		Equity		Interests		Equity
Balance at December 31, 2008	$	1,138	$	1,417	$	(13)	$	2,542	$	128	$	2,670

Net income				349				349		24		373
Comprehensive income adjustments:
Pension and other post retirement
benefits						2		2				2
Financial instruments						1		1		(3)		(2)
Comprehensive income						3		352		21		373

Preferred stock dividends declared				(5)				(5)				(5)
Common stock dividends declared				(150)				(150)				(150)
Distributions to noncontrolling interest										(9)		(9)
Equity contributed by noncontrolling interest										6		6
Balance at December 31, 2009		1,138		1,611		(10)		2,739		146		2,885

Net income (loss)				374				374		(16)		358
Comprehensive income adjustments:
Financial instruments										7		7
Comprehensive income (loss)						―		374		(9)		365

Preferred stock dividends declared				(5)				(5)				(5)
Distributions to noncontrolling interest										(24)		(24)
Balance at December 31, 2010		1,138		1,980		(10)		3,108		113		3,221

Net income				436				436		19		455
Comprehensive income adjustments:
Financial instruments										(36)		(36)
Comprehensive income (loss)						―		436		(17)		419

Preferred stock dividends declared				(5)				(5)				(5)
Capital contribution		200						200				200
Equity contributed by noncontrolling interest										6		6
Balance at December 31, 2011	$	1,338	$	2,411	$	(10)	$	3,739	$	102	$	3,841
See Notes to Consolidated Financial Statements.

SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
	Years ended December 31,
	2011		2010		2009

Operating revenues	$	3,816	$	3,822	$	3,355
Operating expenses
Cost of natural gas		1,568		1,699		1,343
Operation and maintenance		1,305		1,174		1,138
Depreciation		331		309		293
Franchise fees and other taxes		126		124		105
Total operating expenses		3,330		3,306		2,879
Operating income		486		516		476
Other income, net		13		12		7
Interest income		1		1		3
Interest expense		(69)		(66)		(68)
Income before income taxes		431		463		418
Income tax expense		(143)		(176)		(144)
Net income		288		287		274
Preferred dividend requirements		(1)		(1)		(1)
Earnings attributable to common shares	$	287	$	286	$	273
See Notes to Consolidated Financial Statements.

SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	December 31,		December 31,
	2011		2010
ASSETS
Current assets:
Cash and cash equivalents	$	36	$	417
Accounts receivable – trade, net		578		534
Accounts receivable – other, net		63		49
Due from unconsolidated affiliates		40		63
Income taxes receivable		17		28
Inventories		151		105
Regulatory assets		9		12
Other		28		39
Total current assets		922		1,247

Other assets:
Regulatory assets arising from pension and other postretirement
benefit obligations		808		586
Other regulatory assets		137		123
Sundry		8		8
Total other assets		953		717

Property, plant and equipment:
Property, plant and equipment		10,565		9,824
Less accumulated depreciation and amortization		(3,965)		(3,802)
Property, plant and equipment, net		6,600		6,022
Total assets	$	8,475	$	7,986
See Notes to Consolidated Financial Statements.

SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	December 31,		December 31,
	2011		2010
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities:
Accounts payable – trade	$	315	$	327
Accounts payable – other		78		79
Due to unconsolidated affiliate		2		11
Deferred income taxes		44		17
Accrued compensation and benefits		99		98
Regulatory balancing accounts, net		105		180
Current portion of long-term debt		257		262
Customer deposits		75		73
Other		172		163
Total current liabilities		1,147		1,210
Long-term debt		1,064		1,320
Deferred credits and other liabilities:
Customer advances for construction		110		133
Pension and other postretirement benefit obligations, net of plan assets		833		613
Deferred income taxes		576		418
Deferred investment tax credits		23		25
Regulatory liabilities arising from removal obligations		1,075		1,208
Asset retirement obligations		1,161		788
Deferred taxes refundable in rates		87		138
Deferred credits and other		206		178
Total deferred credits and other liabilities		4,071		3,501

Commitments and contingencies (Note 15)

Shareholders’ equity:
Preferred stock		22		22
Common stock (100 million shares authorized; 91 million shares outstanding;
no par value)		866		866
Retained earnings		1,326		1,089
Accumulated other comprehensive income (loss)		(21)		(22)
Total shareholders’ equity		2,193		1,955
Total liabilities and shareholders’ equity	$	8,475	$	7,986
See Notes to Consolidated Financial Statements.

SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in millions)
	Years ended December 31,
	2011		2010		2009
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	288	$	287	$	274
Adjustments to reconcile net income to net cash provided by
operating activities:
Depreciation		331		309		293
Deferred income taxes and investment tax credits		130		107		70
Other		(6)		―		8
Changes in other assets		19		(7)		7
Changes in other liabilities		(7)		8		(68)
Changes in working capital components:
Accounts receivable		(57)		18		(30)
Inventories		(46)		(12)		74
Other current assets		5		(2)		10
Accounts payable		(7)		52		(99)
Income taxes		(12)		5		(2)
Due to/from affiliates, net		(18)		11		(10)
Regulatory balancing accounts		(63)		(56)		10
Customer deposits		2		(13)		(28)
Other current liabilities		(5)		29		(69)
Net cash provided by operating activities		554		736		440

CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment		(683)		(503)		(480)
Decrease (increase) in loans to affiliates, net		49		(63)		(16)
Net cash used in investing activities		(634)		(566)		(496)

CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid		(50)		(100)		―
Preferred dividends paid		(1)		(1)		(1)
Issuance of long-term debt		―		299		―
Payment of long-term debt		(250)		―		(100)
Net cash (used in) provided by financing activities		(301)		198		(101)

(Decrease) increase in cash and cash equivalents		(381)		368		(157)
Cash and cash equivalents, January 1		417		49		206
Cash and cash equivalents, December 31	$	36	$	417	$	49

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	$	65	$	54	$	59
Income tax payments, net of refunds		25		64		76

SUPPLEMENTAL DISCLOSURE OF NONCASH ACTIVITIES
Accrued capital expenditures	$	97	$	103	$	75
Increase in capital lease obligations for investments in property, plant and
equipment		―		4		29
See Notes to Consolidated Financial Statements.

SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME AND CHANGES IN SHAREHOLDERS’ EQUITY
(Dollars in millions)
	Years ended December 31, 2011, 2010 and 2009
							Accumulated
							Other		Total
	Preferred		Common		Retained		Comprehensive		Shareholders’
	Stock		Stock		Earnings		Income (Loss)		Equity
Balance at December 31, 2008	$	22	$	866	$	630	$	(28)	$	1,490

Net income						274				274
Comprehensive income adjustments:
Financial instruments								3		3
Comprehensive income								3		277

Preferred stock dividends declared						(1)				(1)
Balance at December 31, 2009		22		866		903		(25)		1,766

Net income						287				287
Comprehensive income adjustments:
Financial instruments								3		3
Comprehensive income								3		290

Preferred stock dividends declared						(1)				(1)
Common stock dividends declared						(100)				(100)
Balance at December 31, 2010		22		866		1,089		(22)		1,955

Net income						288				288
Comprehensive income adjustments:
Pension and other postretirement benefits								(1)		(1)
Financial instruments								2		2
Comprehensive income								1		289

Preferred stock dividends declared						(1)				(1)
Common stock dividends declared						(50)				(50)
Balance at December 31, 2011	$	22	$	866	$	1,326	$	(21)	$	2,193
See Notes to Consolidated Financial Statements.

SEMPRA ENERGY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

NOTE 1. SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA

PRINCIPLES OF CONSOLIDATION

2012 Business Segment Realignment

Effective January 1, 2012, in connection with several key executive appointments made in September 2011, management realigned some of the company’s major subsidiaries to better fit its strategic direction and to enhance the management and integration of our assets. This realignment resulted in a change in reportable segments in 2012. In accordance with accounting principles generally accepted in the United States (GAAP), historical information for Sempra Energy has been restated in its Consolidated Financial Statements and these Notes to the Consolidated Financial Statements to reflect the effect of this change. All discussions of our operating units and reportable segments in these Notes reflect the new segments and operating structure.

Sempra Energy

Sempra Energy’s Consolidated Financial Statements include the accounts of Sempra Energy, a California-based Fortune 500 holding company, and its consolidated subsidiaries and a variable interest entity (VIE). Sempra Energy’s principal operating units are

§	San Diego Gas & Electric Company (SDG&E) and Southern California Gas Company (SoCalGas);

§	Sempra International, which includes our Sempra South American Utilities and Sempra Mexico reportable segments; and

§	Sempra U.S. Gas & Power, which includes our Sempra Renewables and Sempra Natural Gas reportable segments.

We provide descriptions of each of our segments in Note 16.

We refer to SDG&E and SoCalGas collectively as the California Utilities, which do not include the utilities in our Sempra International and Sempra U.S. Gas & Power operating units. Sempra Global is the holding company for most of our subsidiaries that are not subject to California utility regulation. All references in these Notes to “Sempra International,” “Sempra U.S. Gas & Power” and their respective reportable segments are not intended to refer to any legal entity with the same or similar name.

Sempra Energy uses the equity method to account for investments in affiliated companies over which we have the ability to exercise significant influence, but not control. We discuss our investments in unconsolidated subsidiaries in Notes 3 and 4.

SDG&E

SDG&E’s Consolidated Financial Statements include its accounts and the accounts of a VIE of which SDG&E is the primary beneficiary, as we discuss below under “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’ Consolidated Financial Statements include its subsidiaries, which comprise less than one percent of its consolidated financial position and results of operations. SoCalGas’ common stock is wholly owned by Pacific Enterprises (PE), which is a wholly owned subsidiary of Sempra Energy.

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.

We evaluated events and transactions that occurred after December 31, 2011 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.

As we discuss in Note 3, in April 2011, Sempra South American Utilities acquired two electric distribution utilities in South America. Sempra Natural Gas also owns and operates Mobile Gas Service Corporation (Mobile Gas), a natural gas distribution utility in southwest Alabama and Sempra Mexico owns and operates Ecogas Mexico, S de RL de CV (Ecogas), a natural gas distribution utility in Northern Mexico. In prior years, we provided separate revenue and cost of revenue information on our consolidated statements of operations for the California Utilities only, as the amounts for Mobile Gas and Ecogas were immaterial. Due to the addition of the South American utilities, we are now providing separate revenue and cost of revenue information on the Consolidated Statements of Operations on a combined basis for all of our utilities. Accordingly, amounts in the prior periods have been reclassified to conform with the current year presentation.

Use of Estimates in the Preparation of the Financial Statements

We prepare our financial statements in conformity with accounting principles generally accepted in the United States of America (GAAP). This requires us to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes, including the disclosure of contingent assets and liabilities at the date of the financial statements. Although we believe the estimates and assumptions are reasonable, actual amounts ultimately may differ significantly from those estimates.

Change in Accounting Principle

Effective January 1, 2012, we changed our method of accounting for investment tax credits (ITC) from the flow-through method to the deferral method for Sempra Energy. Under the flow-through method, we reduced our income tax expense by the amount of ITC in the year in which the qualifying assets were placed in service. Under the deferral method, we record ITC in the year in which the qualifying assets are placed in service as a reduction to the cost of the asset that generated the ITC. This results in lower book depreciation over the life of the asset. This change has no historical or prospective impact on the California Utilities because ITC is effectively deferred as a result of the application of regulatory accounting required under GAAP.

The flow-through method and the deferral method are both acceptable under GAAP, but the deferral method is the preferred method. We believe that the deferral method is preferable for the ITC we receive because it recognizes ITC benefits over the same periods as the associated costs for which the ITC are intended to compensate.

We applied this change in accounting principle by retrospectively adjusting the financial statement amounts for all periods presented. Upon adopting the deferral method, we reduced Sempra Energy Consolidated retained earnings as of January 1, 2009 by $7 million for the cumulative effect of the change in accounting principle.

The following tables summarize the effects of the change in accounting principle on Sempra Energy Consolidated’s financial statements for 2011 and 2010. The effect on 2009 was negligible.

EFFECT OF CHANGE IN ACCOUNTING PRINCIPLE
(Dollars in millions, except per share amounts)
	As of and for the year ended December 31, 2011
	As
	Originally				Retrospectively
Sempra Energy Consolidated	Reported		Adjustments		Adjusted
CONSOLIDATED STATEMENT OF OPERATIONS
Depreciation and amortization	$	978	$	(2)	$	976
Income before income taxes and equity earnings
of certain unconsolidated subsidiaries		1,721		2		1,723
Income tax expense		366		28		394
Net income		1,407		(26)		1,381
Earnings		1,357		(26)		1,331

Basic earnings per common share	$	5.66	$	(0.11)	$	5.55
Diluted earnings per common share	$	5.62	$	(0.11)	$	5.51

CONSOLIDATED BALANCE SHEET
Property, plant and equipment	$	31,303	$	(111)	$	31,192
Less accumulated depreciation and amortization		(7,731)		4		(7,727)
Property, plant and equipment, net	$	23,572	$	(107)	$	23,465

Income taxes payable	$	16	$	(11)	$	5
Deferred income taxes, noncurrent liability		1,554		(34)		1,520
Deferred credits and other		783		1		784
Retained earnings		8,225		(63)		8,162

CONSOLIDATED STATEMENT OF CASH FLOWS
Net income	$	1,407	$	(26)	$	1,381
Adjustments to reconcile net income to net cash provided by
operating activities:
Depreciation and amortization		978		(2)		976
Deferred income taxes and investment tax credits		(24)		27		3
Net changes in other working capital components (income taxes, net)		(225)		1		(224)

EFFECT OF CHANGE IN ACCOUNTING PRINCIPLE
(Dollars in millions, except per share amounts)
	Year ended December 31, 2010
	As
	Originally				Retrospectively
Sempra Energy Consolidated	Reported		Adjustments		Adjusted
CONSOLIDATED STATEMENT OF OPERATIONS
Depreciation and amortization	$	867	$	(1)	$	866
Income before income taxes and equity earnings
of certain unconsolidated subsidiaries		786		1		787
Income tax expense		102		31		133
Net income		733		(30)		703
Earnings		739		(30)		709

Basic earnings per common share	$	3.02	$	(0.12)	$	2.90
Diluted earnings per common share	$	2.98	$	(0.12)	$	2.86


CONSOLIDATED BALANCE SHEET
Income taxes receivable	$	248	$	9	$	257
Other current assets		192		1		193

Property, plant and equipment	$	27,087	$	(64)	$	27,023
Less accumulated depreciation and amortization		(7,211)		2		(7,209)
Property, plant and equipment, net	$	19,876	$	(62)	$	19,814

Deferred income taxes, noncurrent liability	$	1,561	$	(16)	$	1,545
Deferred credits and other		823		1		824
Retained earnings		7,329		(37)		7,292

CONSOLIDATED STATEMENT OF CASH FLOWS
Net income	$	733	$	(30)	$	703
Adjustments to reconcile net income to net cash provided by
operating activities:
Depreciation and amortization		867		(1)		866
Deferred income taxes and investment tax credits		48		(11)		37
Net changes in other working capital components (income taxes, net)		58		42		100

Adoption of New Accounting Standards

Effective January 1, 2012, the Company adopted Accounting Standards Update (ASU) 2011-05, Presentation of Comprehensive Income (ASU 2011-05) and ASU 2011-12, Deferral of the Effective Date for Amendments to the Presentation of Reclassifications of Items Out of Accumulated Other Comprehensive Income in Accounting Standards Update No. 2011-05 (ASU 2011-12). ASU 2011-05 amends Accounting Standards Codification (ASC) Topic 220, Comprehensive Income, and eliminates the option to report other comprehensive income and its components in the statement of changes in equity. The ASU allows an entity an option to present the components of net income and other comprehensive income in one continuous statement, referred to as the statement of comprehensive income, or in two separate, but consecutive, statements.

ASU 2011-05 does not change the items that must be reported in other comprehensive income, when an item of other comprehensive income must be reclassified to net income, or the earnings per share computation.

ASU 2011-12 defers the requirement to separately present on the face of the financial statements reclassification adjustments for items that are reclassified from other comprehensive income to net income.

We have applied the new standards retrospectively for Sempra Energy by providing the required statements for all periods presented. We have elected to present the components of net income and other comprehensive income in two separate, but consecutive, statements.

REGULATORY MATTERS

Effects of Regulation

The accounting policies of our regulated utility subsidiaries in California, SDG&E and SoCalGas, conform with GAAP for regulated enterprises and reflect the policies of the California Public Utilities Commission (CPUC) and the Federal Energy Regulatory Commission (FERC).

The California Utilities prepare their financial statements in accordance with GAAP provisions governing regulated operations. Under these provisions, a regulated utility records a regulatory asset if it is probable that, through the ratemaking process, the utility will recover that asset from customers. To the extent that recovery is no longer probable, the related regulatory assets are written off. Regulatory liabilities represent amounts collected from customers in advance of the actual expenditure by the utility. If the actual expenditures are less than amounts previously collected from ratepayers, the excess would be refunded to customers, generally by reducing future rates.

Our other natural gas distribution utilities, Mobile Gas and Ecogas, also apply GAAP for regulated utilities to their operations.

We provide information concerning regulatory assets and liabilities below in “Regulatory Balancing Accounts” and “Regulatory Assets and Liabilities.”

Regulatory Balancing Accounts

The following table summarizes our regulatory balancing accounts at December 31. The net payables (payables net of receivables) will be returned to customers by reducing future rates.


SUMMARY OF REGULATORY BALANCING ACCOUNTS AT DECEMBER 31
(Dollars in millions)
		Sempra Energy
		Consolidated				SDG&E				SoCalGas
		2011		2010		2011		2010		2011		2010
Overcollected		$	709	$	733	$	419	$	443	$	290	$	290
Undercollected			(642)		(492)		(457)		(382)		(185)		(110)
Net payable (receivable)(1)		$	67	$	241	$	(38)	$	61	$	105	$	180
(1)	At December 31, 2011, the net receivable at SDG&E and the net payable at SoCalGas are shown separately
	on Sempra Energy’s Consolidated Balance Sheet.

Over- and undercollected regulatory balancing accounts reflect the difference between customer billings and recorded or CPUC-authorized costs, primarily commodity costs. Amounts in the balancing accounts are recoverable or refundable in future rates, subject to CPUC approval. Balancing account treatment eliminates the impact on earnings from variances in the covered costs from authorized amounts. Absent balancing account treatment, variations in the cost of fuel supply and certain operating and maintenance costs from amounts approved by the CPUC would increase volatility in utility earnings.

We provide additional information about regulatory matters in Notes 14 and 15.

Regulatory Assets and Liabilities

We show the details of regulatory assets and liabilities in the following table, and discuss each of them separately below.

REGULATORY ASSETS (LIABILITIES) AT DECEMBER 31
(Dollars in millions)
		2011		2010
SDG&E
Fixed-price contracts and other derivatives		$	258	$	299
Costs related to wildfire litigation			594		364
Deferred taxes recoverable in rates			570		502
Pension and other postretirement benefit obligations			309		279
Removal obligations(1)			(1,462)		(1,409)
Unamortized loss on reacquired debt, net			20		23
Environmental costs			17		17
Legacy meters			91		―
Other			43		38
Total SDG&E			440		113
SoCalGas
Pension and other postretirement benefit obligations			808		586
Employee benefit costs			66		59
Removal obligations(1)			(1,075)		(1,208)
Deferred taxes refundable in rates			(87)		(138)
Unamortized loss on reacquired debt, net			20		23
Environmental costs			21		18
Workers’ compensation			44		41
Other			(5)		(6)
Total SoCalGas			(208)		(625)
Other Sempra Energy
Mobile Gas			(5)		(16)
Ecogas			3		9
Total Other Sempra Energy			(2)		(7)
Total Sempra Energy Consolidated		$	230	$	(519)
(1)	Related to obligations discussed below in “Asset Retirement Obligations.”

NET REGULATORY ASSETS (LIABILITIES) AS PRESENTED ON THE CONSOLIDATED BALANCE SHEETS AT DECEMBER 31
(Dollars in millions)
		2011						2010
		Sempra						Sempra
		Energy						Energy
		Consolidated		SDG&E		SoCalGas		Consolidated		SDG&E		SoCalGas
Current regulatory assets		$	89	$	78	$	9	$	90	$	71	$	12
Noncurrent regulatory assets			2,780		1,824		945		2,167		1,451		709
Current regulatory liabilities(1)			(1)		―		―		(8)		―		―
Noncurrent regulatory liabilities			(2,638)		(1,462)		(1,162)		(2,768)		(1,409)		(1,346)
Total		$	230	$	440	$	(208)	$	(519)	$	113	$	(625)
(1)	Included in Other Current Liabilities.

In the tables above:

Regulatory assets arising from fixed-price contracts and other derivatives are offset by corresponding liabilities arising from purchased power and natural gas commodity and transportation contracts. The regulatory asset is increased/decreased based on changes in the fair market value of the contracts. It is also reduced as payments are made for commodities and services under these contracts.

Deferred taxes recoverable/refundable in rates are based on current regulatory ratemaking and income tax laws. SDG&E and SoCalGas expect to recover/refund net regulatory assets/liabilities related to deferred income taxes over the lives of the assets that give rise to the accumulated deferred income tax liabilities/assets.

§	Regulatory assets related to unamortized losses on reacquired debt are recovered over the remaining original amortization periods of the losses on reacquired debt. These periods range from 9 months to 16 years for SDG&E and from 2 years to 15 years for SoCalGas.

Regulatory assets related to environmental costs represent the portion of our environmental liability recognized at the end of the period in excess of the amount that has been recovered through rates charged to customers. We expect this amount to be recovered in future rates as expenditures are made.

§	Regulatory assets related to pension and other postretirement benefit obligations are offset by corresponding liabilities and are being recovered in rates as the plans are funded.

§	Regulatory assets arising from costs related to wildfire litigation are costs in excess of liability insurance coverage and amounts recovered, and to be recovered, from other potentially responsible parties, as we discuss in Note 15 under “SDG&E—2007 Wildfire Litigation.”

§	The regulatory asset related to the legacy meters removed from service and replaced under the Smart Meter Program is their undepreciated value. SDG&E expects to recover this asset over a remaining life of 28 years.

For substantially all of these assets, the cash has not yet been expended and the assets are offset by liabilities that do not incur a carrying cost.

FAIR VALUE MEASUREMENTS

We apply recurring fair value measurements to certain assets and liabilities, primarily nuclear decommissioning and benefit plan trust assets and other miscellaneous derivatives. “Fair value” is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price).

A fair value measurement reflects the assumptions market participants would use in pricing an asset or liability based on the best available information. These assumptions include the risk inherent in a particular valuation technique (such as a pricing model) and the risks inherent in the inputs to the model. Also, we consider an issuer’s credit standing when measuring its liabilities at fair value.

We establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows:

Level 1 – Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Our Level 1 financial instruments primarily consist of listed equities, U.S. government treasury securities and exchange-traded derivatives.

Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including:

§	quoted forward prices for commodities

§	time value

§	current market and contractual prices for the underlying instruments

§	volatility factors

§	other relevant economic measures

Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Our financial instruments in this category include the Nuclear Decommissioning Trusts’ investments at SDG&E and non-exchange-traded derivatives such as interest rate instruments and over-the-counter (OTC) forwards and options.

Level 3 – Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value from the perspective of a market participant.

CASH AND CASH EQUIVALENTS

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

RESTRICTED CASH

Restricted cash at Sempra Energy, including amounts at SDG&E discussed below, was $46 million and $158 million at December 31, 2011 and 2010, respectively. At December 31, 2010, it included long-term funds held in trust for construction financing of certain natural gas storage facilities of Sempra Natural Gas of $27 million.

We held $3 million and $15 million, respectively, at December 31, 2011 and 2010 of cash collateral received as security for guarantees issued by Sempra Energy related to businesses sold by RBS Sempra Commodities. We discuss RBS Sempra Commodities in Note 4 and our related guarantees in Note 5.

SDG&E had restricted cash at December 31, 2011 of $14 million related to the purchase of a power plant on January 1, 2012. SDG&E had $110 million of restricted cash at December 31, 2010 representing funds received from a wildfire litigation settlement that we describe in Note 15. These funds were restricted to use for 2007 wildfire litigation expenditures. In addition, restricted cash at SDG&E of $29 million and $6 million at December 31, 2011 and 2010, respectively, are funds held by a trustee for Otay Mesa VIE (see “Variable Interest Entities—Otay Mesa VIE” below) to pay certain operating costs.

COLLECTION ALLOWANCES

We record allowances for the collection of trade and other accounts and notes receivable which include allowances for doubtful customer accounts and for other receivables. We show the changes in these allowances in the table below:

COLLECTION ALLOWANCES
(Dollars in millions)
	Years ended December 31,
	2011		2010		2009
Sempra Energy Consolidated
Allowances for collection of receivables at January 1	$	29	$	27	$	29
Provisions for uncollectible accounts		20		22		25
Write-offs of uncollectible accounts		(20)		(20)		(27)
Allowances for collection of receivables at December 31	$	29	$	29	$	27
SDG&E
Allowances for collection of receivables at January 1	$	5	$	4	$	6
Provisions for uncollectible accounts		8		7		8
Write-offs of uncollectible accounts		(7)		(6)		(10)
Allowances for collection of receivables at December 31	$	6	$	5	$	4
SoCalGas
Allowances for collection of receivables at January 1	$	14	$	16	$	18
Provisions for uncollectible accounts		8		8		12
Write-offs of uncollectible accounts		(10)		(10)		(14)
Allowances for collection of receivables at December 31	$	12	$	14	$	16

INVENTORIES

The California Utilities value natural gas inventory by the last-in first-out (LIFO) method. As inventories are sold, differences between the LIFO valuation and the estimated replacement cost are reflected in customer rates. Materials and supplies at the California Utilities are generally valued at the lower of average cost or market.

Sempra Mexico, Sempra South American Utilities and Sempra Natural Gas value natural gas inventory and material and supplies at lower of average cost or market. Sempra Natural Gas and Sempra Mexico value liquefied natural gas (LNG) inventory (categorized as natural gas below) by the first-in first-out method.

INVENTORY BALANCES AT DECEMBER 31
(Dollars in millions)

	Natural Gas				Materials and supplies				Total
	2011		2010		2011		2010		2011		2010
SDG&E	$	6	$	5	$	76	$	66	$	82	$	71
SoCalGas		128		86		23		19		151		105
Sempra South American Utilities		―		―		36		―		36		―
Sempra Mexico		10		23		7		8		17		31
Sempra Natural Gas		51		38		9		13		60		51
Sempra Energy Consolidated	$	195	$	152	$	151	$	106	$	346	$	258

INCOME TAXES

Income tax expense includes current and deferred income taxes from operations during the year. We record deferred income taxes for temporary differences between the book and the tax bases of assets and liabilities. Investment tax credits from prior years are amortized to income by the California Utilities over the estimated service lives of the properties as required by the CPUC. At our other businesses, we reduce the book basis of the related asset by the amount of investment tax credit earned. At Sempra Renewables, production tax credits are recognized in income tax expense as earned.

The California Utilities and Mobile Gas recognize

§	regulatory assets to offset deferred tax liabilities if it is probable that the amounts will be recovered from customers; and

§	regulatory liabilities to offset deferred tax assets if it is probable that the amounts will be returned to customers.

Other than local country withholding tax on current Peruvian earnings, we currently do not record deferred income taxes for basis differences between financial statement and income tax investment amounts in non-U.S. subsidiaries because their cumulative undistributed earnings are indefinitely reinvested.

When there are uncertainties related to potential income tax benefits, in order to qualify for recognition, the position we take has to have at least a “more likely than not” chance of being sustained (based on the position’s technical merits) upon challenge by the respective authorities. The term “more likely than not” means a likelihood of more than 50 percent. Otherwise, we may not recognize any of the potential tax benefit associated with the position. We recognize a benefit for a tax position that meets the “more likely than not” criterion at the largest amount of tax benefit that is greater than 50 percent likely of being realized upon its effective resolution.

Unrecognized tax benefits involve management’s judgment regarding the likelihood of the benefit being sustained. The final resolution of uncertain tax positions could result in adjustments to recorded amounts and may affect our results of operations, financial position and cash flows.

We provide additional information about income taxes in Note 7.

PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment primarily represents the buildings, equipment and other facilities used by the California Utilities to provide natural gas and electric utility services, and by Sempra International and Sempra U.S. Gas & Power. It also reflects projects included in construction work in progress at these operating units.

Our plant costs include

labor

§	materials and contract services

§	expenditures for replacement parts incurred during a major maintenance outage of a generating plant

In addition, the cost of our utility plant includes an allowance for funds used during construction (AFUDC). We discuss AFUDC below. The cost of non-utility plant includes capitalized interest.

Maintenance costs are expensed as incurred. The cost of most retired depreciable utility plant minus salvage value is charged to accumulated depreciation.

PROPERTY, PLANT AND EQUIPMENT BY MAJOR FUNCTIONAL CATEGORY
(Dollars in millions)
		Property, Plant				Depreciation rates for
		and Equipment at				years ended
		December 31,				December 31,
		2011		2010		2011		2010		2009
SDG&E:
Natural gas operations		$	1,349	$	1,280	3.15	%	3.00	%	2.84	%
Electric distribution			4,894		4,700	4.13		4.06		3.97
Electric transmission			1,938		1,795	2.74		2.70		2.67
Electric generation(1)			2,166		1,737	4.92		4.30		3.84
Other electric(2)			604		666	8.26		8.19		8.50
Construction work in progress			2,052		1,069	NA		NA		NA
Total SDG&E			13,003		11,247
SoCalGas:
Natural gas operations(3)			10,055		9,376	3.62		3.54		3.50
Other non-utility			129		126	1.62		1.74		1.41
Construction work in progress			381		322	NA		NA		NA
Total SoCalGas			10,565		9,824

Other operating units and parent(4):						Estimated Useful Lives
Land and land rights			292		194	25 to 50 years(5)
Machinery and equipment:
Utility electric distribution operations			1,267		―	10 to 50 years
Generating plants			1,278		1,604	4 to 35 years
LNG terminals			2,059		2,049	3 to 50 years
Pipelines and storage			1,510		1,375	10 to 50 years
Other			168		97	2 to 50 years
Construction work in progress			849		428			N/A
Other			201		205	3 to 50 years
			7,624		5,952
Total Sempra Energy Consolidated		$	31,192	$	27,023
(1)	Includes capital lease assets of $183 million and $182 million at December 31, 2011 and 2010, respectively.
(2)	Includes capital lease assets of $26 million at both December 31, 2011 and 2010.
(3)	Includes capital lease assets of $33 million at both December 31, 2011 and 2010.
(4)	December 31, 2011 balances include $163 million and $126 million of utility plant, primarily pipelines and other distribution assets, at Mobile Gas and Ecogas, respectively. December 31, 2010 balances include $156 million and $137 million of utility plant, primarily pipelines and other distribution assets, at Mobile Gas and Ecogas, respectively.
(5)	Estimated useful lives are for land rights.

Depreciation expense is based on the straight-line method over the useful lives of the assets or, for the California Utilities, a shorter period prescribed by the CPUC. Depreciation expense is computed using the straight-line method over the asset’s estimated original composite useful life, the CPUC-prescribed period or the remaining term of the site leases, whichever is shortest.

The accumulated depreciation and decommissioning amounts on our Consolidated Balance Sheets are as follows:

ACCUMULATED DEPRECIATION AND DECOMMISSIONING AMOUNTS
(Dollars in millions)
		December 31,
		2011		2010
SDG&E:
Accumulated depreciation and decommissioning of utility plant in service:
Electric(1)		$	2,387	$	2,152
Natural gas			576		542
Total SDG&E			2,963		2,694
SoCalGas:
Accumulated depreciation of natural gas utility plant in service(2)			3,863		3,702
Accumulated depreciation – other non-utility			102		100
Total SoCalGas			3,965		3,802
Other operating units and parent:
Accumulated depreciation – other non-utility(3)			755		713
Accumulated depreciation of utility electric distribution operations			44		―
			799		713
Total Sempra Energy Consolidated		$	7,727	$	7,209
(1)	Includes accumulated depreciation for assets under capital lease of $16 million and $7 million at December 31, 2011 and 2010, respectively.
(2)	Includes accumulated depreciation for assets under capital lease of $22 million and $14 million at December 31, 2011 and 2010, respectively.
(3)	December 31, 2011 balances include $15 million and $28 million of accumulated depreciation for utility plant at Mobile Gas and Ecogas, respectively. December 31, 2010 balances include $9 million and $29 million of accumulated depreciation for utility plant at Mobile Gas and Ecogas, respectively.

The California Utilities finance their construction projects with borrowed funds and equity funds. The CPUC and the FERC allow the recovery of the cost of these funds by the capitalization of AFUDC, calculated using rates authorized by the CPUC and the FERC, as a cost component of property, plant and equipment. The California Utilities earn a return on the allowance after the utility property is placed in service and recover the AFUDC from their customers over the expected useful lives of the assets.

Sempra International and Sempra U.S. Gas & Power businesses capitalize interest costs incurred to finance capital projects. The California Utilities also capitalize certain interest costs.

CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Years ended December 31,
	2011		2010		2009
Sempra Energy Consolidated:
AFUDC related to debt	$	40	$	24	$	15
AFUDC related to equity		99		57		39
Other capitalized financing costs		26		33		73
Total Sempra Energy Consolidated	$	165	$	114	$	127
SDG&E:
AFUDC related to debt	$	33	$	18	$	10
AFUDC related to equity		80		43		29
Other capitalized financing costs		―		―		4
Total SDG&E	$	113	$	61	$	43
SoCalGas:
AFUDC related to debt	$	7	$	6	$	5
AFUDC related to equity		19		14		10
Other capitalized financing costs		―		―		1
Total SoCalGas	$	26	$	20	$	16

ASSETS HELD FOR SALE

At December 31, 2010, we held gas and steam turbine assets for sale of $40 million which were recorded in Other Current Assets on the Sempra Energy Consolidated Balance Sheet. In December 2011, management decided to hold these assets for future use in potential development projects at Sempra Natural Gas. Accordingly, we have reclassified them from assets held for sale to construction work in progress. The assets held for sale had no effect on results of operations for any of the periods presented.

GOODWILL AND OTHER INTANGIBLE ASSETS

Goodwill

Goodwill is the excess of the purchase price over the fair value of the identifiable net assets of acquired companies. Goodwill is not amortized but is tested annually on October 1 for impairment. Impairment of goodwill occurs when the carrying amount (book value) of goodwill exceeds its implied fair value. If the carrying value of the reporting unit, including goodwill, exceeds its fair value, and the book value of goodwill is greater than its fair value on the test date, we record a goodwill impairment loss.

Sempra South American Utilities recorded goodwill of $975 million in April 2011 in connection with the acquisition of AEI’s interests in Chilquinta Energía S.A. (Chilquinta Energía) in Chile, Luz del Sur S.A.A. (Luz del Sur) in Peru, and their subsidiaries. Sempra Mexico recorded $18 million in April 2010 in connection with the acquisition of pipeline and natural gas infrastructure assets of El Paso Corporation, which we discuss in Note 3.

Goodwill on the Sempra Energy Consolidated Balance Sheets is recorded as follows:

GOODWILL
(Dollars in millions)
			Sempra
		South American			Sempra		Sempra
			Utilities		Mexico		Natural Gas		Total
Balance as of December 31, 2009		$	―	$	6	$	62	$	68
Acquisition of Mexican pipeline and natural gas infrastructure assets and other			―		19		―		19
Balance as of December 31, 2010			―		25		62		87
Acquisition of Chilquinta Energía and Luz del Sur			975		―		―		975
Foreign currency translation(1)			(26)		―		―		(26)
Balance at December 31, 2011		$	949	$	25	$	62	$	1,036
(1)	We record the offset of this fluctuation to other comprehensive income.

We provide additional information concerning goodwill related to our equity method investments and the impairment of investments in unconsolidated subsidiaries in Note 4.

Other Intangible Assets

Sempra Natural Gas recorded $460 million of intangible assets in connection with the acquisition of EnergySouth, Inc. in 2008. These intangible assets represent storage and development rights related to the natural gas storage facilities of Bay Gas Storage, LLC (Bay Gas) and Mississippi Hub, LLC (Mississippi Hub) and were recorded at estimated fair value as of the date of the acquisition using discounted cash flows analysis. Our important assumptions in determining fair value include estimated future cash flows, the estimated useful life of the intangible assets and our use of appropriate discount rates. We are amortizing these intangible assets over their estimated useful lives as shown in the table below.

Other Intangible Assets on the Sempra Energy Consolidated Balance Sheets are as follows:

OTHER INTANGIBLE ASSETS
(Dollars in millions)
	Amortization period	December 31,		December 31,
	(years)	2011		2010
Storage rights	46	$	138	$	138
Development rights	50		322		322
Other	11 years to indefinite		21		16
			481		476
Less accumulated amortization:
Storage rights			(21)		(14)
Development rights			(10)		(7)
Other			(2)		(2)
			(33)		(23)
Total		$	448	$	453

Amortization expense related to the above intangible assets was $10 million in each of 2011, 2010 and 2009. We estimate the amortization expense for the next five years to be $10 million per year.

LONG-LIVED ASSETS

We periodically evaluate whether events or circumstances have occurred that may affect the recoverability or the estimated useful lives of long-lived assets, the definition of which includes intangible assets subject to amortization, but does not include unconsolidated subsidiaries. Impairment of long-lived assets occurs when the estimated future undiscounted cash flows are less than the carrying amount of the assets. If that comparison indicates that the assets’ carrying value may not be recoverable, the impairment is measured based on the difference between the carrying amount and the fair value of the assets. This evaluation is performed at the lowest level for which separately identifiable cash flows exist.

In the second quarter of 2009, we recorded a $132 million pretax write-off related to certain assets at one of Sempra Natural Gas’ natural gas storage projects. This amount is recorded as Write-off of Long-Lived Assets on our Consolidated Statement of Operations for the year ended December 31, 2009. Sempra Natural Gas owns 75 percent of Liberty Gas Storage, LLC (Liberty), the partnership that owns the project. Our partner’s 25-percent share of the pretax charge is $33 million, which is included in (Earnings) Losses Attributable to Noncontrolling Interests on our Consolidated Statement of Operations for the year ended December 31, 2009. The impact to our net income and to our earnings is $97 million and $64 million, respectively, for the year ended December 31, 2009. In September 2009, the members of the partnership unanimously voted to proceed with the abandonment of the assets that were written off. The abandonment work began in late 2010 and was completed in early 2011.

VARIABLE INTEREST ENTITIES (VIE)

We consolidate a VIE if we are the primary beneficiary of the VIE. Our determination of whether we are the primary beneficiary is based upon 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 right to receive benefits that could be significant to the VIE.

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 upon our analysis, the ability to direct the dispatch of electricity may have the most significant impacts 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 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, Sempra Energy and SDG&E consolidate the entity that owns the facility as a VIE, as we discuss below.

Otay Mesa VIE

SDG&E has a 10-year agreement to purchase power generated at the Otay Mesa Energy Center (OMEC), a 605-megawatt (MW) generating facility that began commercial operations in October 2009. In addition to tolling, the agreement provides SDG&E with the option to purchase the power plant at the end of the contract term in 2019, or upon earlier termination of the purchased-power agreement, at a predetermined price subject to adjustments based on performance of the facility. If SDG&E does not exercise its option, under certain circumstances, it may be required to purchase the power plant at a predetermined price.

The facility owner, Otay Mesa Energy Center LLC (OMEC LLC), is a VIE (Otay Mesa VIE), of which SDG&E is the primary beneficiary. SDG&E has no OMEC LLC voting rights 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. Sempra Energy and SDG&E have consolidated Otay Mesa VIE since the second quarter of 2007. Otay Mesa VIE’s equity of $102 million at December 31, 2011 and $113 million at December 31, 2010 is included on the Consolidated Balance Sheets in Other Noncontrolling Interests for Sempra Energy and in Noncontrolling Interest for SDG&E.

OMEC LLC has a loan outstanding of $355 million at December 31, 2011, the proceeds of which were used for the construction of OMEC. The loan is with third party lenders and is secured by OMEC’s property, plant and equipment. SDG&E is not a party to the loan agreement and does not have any additional implicit or explicit financial responsibility to OMEC LLC. The loan fully matures in April 2019 and bears interest at rates varying with market rates. In addition, OMEC LLC has entered into interest rate swap agreements to moderate its exposure to interest rate changes. We provide additional information concerning the interest rate swaps in Note 10.

Other Variable Interest Entities

SDG&E’s power procurement is subject to reliability requirements that may require SDG&E to enter into various power purchase arrangements which 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. SDG&E has determined that no contracts, other than the one relating to Otay Mesa VIE mentioned above, result in SDG&E being the primary beneficiary as of December 31, 2011. In addition to the tolling agreements described above, other variable interests involve various elements of fuel and power costs, including certain construction costs, tax credits, and other components of cash flow 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. 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 are not expected to significantly affect the financial position, results of operations, or liquidity of SDG&E. 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.

Sempra Energy’s other business units also enter into arrangements which could include variable interests. We evaluate these arrangements and applicable entities based upon the qualitative and quantitative analyses described above. Certain of these entities are service companies that are VIEs. As the primary beneficiary of these service companies, we consolidate them. In all other cases, we have determined that these contracts are not variable interests in a VIE and therefore are not subject to the requirements of GAAP concerning the consolidation of VIEs.

The Consolidated Financial Statements 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 financial statements of other consolidated VIEs are not material to the financial statements of Sempra Energy. The captions on the tables below correspond to SDG&E’s Consolidated Balance Sheets and Consolidated Statements of Operations.

AMOUNTS ASSOCIATED WITH OTAY MESA VIE
(Dollars in millions)
			December 31,
			2011		2010
Cash and cash equivalents			$	12	$	10
Restricted cash				7		6
Accounts receivable - trade				7		―
Accounts receivable - other				―		(1)
Inventories				2		2
Other				1		1
Total current assets				29		18
Restricted cash				22		―
Sundry				6		6
Property, plant and equipment, net				494		516
Total assets			$	551	$	540

Current portion of long-term debt			$	10	$	10
Fixed-price contracts and other derivatives				16		17
Other				9		1
Total current liabilities				35		28
Long-term debt				345		355
Fixed-price contracts and other derivatives				65		41
Deferred credits and other				4		3
Other noncontrolling interest				102		113
Total liabilities and equity			$	551	$	540


	Years ended December 31,
	2011		2010		2009

Operating revenues
Electric	$	―	$	(1)	$	(1)
Natural gas		―		(3)		―
Total operating revenues		―		(4)		(1)
Operating expenses
Cost of electric fuel and purchased power		(72)		(82)		(13)
Operation and maintenance		19		20		7
Depreciation and amortization		22		26		7
Total operating expenses		(31)		(36)		1
Operating income (loss)		31		32		(2)
Other (expense) income, net		(1)		(34)		27
Interest expense		(11)		(14)		(1)
Income (loss) before income taxes/Net income (loss)		19		(16)		24
(Earnings) losses attributable to noncontrolling interest		(19)		16		(24)
Earnings	$	―	$	―	$	―

ASSET RETIREMENT OBLIGATIONS

For tangible long-lived assets, we record asset retirement obligations for the present value of liabilities of future costs expected to be incurred when assets are retired from service, if the retirement process is legally required and if a reasonable estimate of fair value can be made. We also record a liability if a legal obligation to perform an asset retirement exists and can be reasonably estimated, but performance is conditional upon a future event. We record the estimated retirement cost over the life of the related asset by depreciating the present value of the obligation (measured at the time of the asset’s acquisition) and accreting the discount until the liability is settled. Rate-regulated entities record regulatory assets or liabilities as a result of the timing difference between the recognition of costs in accordance with GAAP and costs recovered through the rate-making process. We have recorded a regulatory liability to show that the California Utilities have collected funds from customers more quickly and for larger amounts than we would accrete the retirement liability and depreciate the asset in accordance with GAAP.

We have recorded asset retirement obligations related to various assets including:

SDG&E and SoCalGas

§	fuel and storage tanks

§	natural gas distribution system

§	hazardous waste storage facilities

§	asbestos-containing construction materials

SDG&E

§	decommissioning of nuclear power facilities

§	electric distribution and transmission systems

§	site restoration of a former power plant

§	power generation plant (natural gas)

SoCalGas

§	natural gas transmission pipelines

§	underground natural gas storage facilities and wells

Sempra Mexico

§	power generation plant (natural gas)

§	natural gas distribution and transportation systems

§	LNG terminal

Sempra Renewables

§	certain power generation plants (solar)

Sempra Natural Gas

§	power generation plant (natural gas)

§	natural gas distribution and transportation systems

§	underground natural gas storage facilities

The changes in asset retirement obligations are as follows:

CHANGES IN ASSET RETIREMENT OBLIGATIONS
(Dollars in millions)
		Sempra Energy
		Consolidated				SDG&E				SoCalGas
		2011		2010		2011		2010		2011		2010
Balance as of January 1(1)		$	1,468	$	1,313	$	623	$	590	$	803	$	676
Accretion expense			82		77		38		37		41		38
Liabilities incurred			12		10		3		―		―		―
Payments			(1)		(17)		―		―		―		(2)
Revisions(2,3)			364		85		34		(4)		331		91
Balance as of December 31(1)		$	1,925	$	1,468	$	698	$	623	$	1,175	$	803
(1)	The current portions of the obligations are included in Other Current Liabilities on the Consolidated Balance Sheets.
(2)	The increase in obligations at SDG&E and SoCalGas for revisions in 2011 resulted from changes in assets in service and a decrease in the discount rate from 5.13 percent in 2010 to 4.00 percent in 2011, based on the risk-free rate plus an estimated credit spread.
(3)	The increase in obligations at SoCalGas for revisions in 2010 resulted from changes in assets in service and a decrease in the discount rate from 5.54 percent in 2009 to 5.13 percent in 2010, based on the risk-free rate plus an estimated credit spread.

CONTINGENCIES

We accrue losses for the estimated impacts of various conditions, situations or circumstances involving uncertain outcomes. For loss contingencies, we accrue the loss if an event has occurred on or before the balance sheet date and:

§	information available through the date we file our financial statements indicates it is probable that a loss has been incurred, given the likelihood of uncertain future events; and

§	the amounts of the loss can be reasonably estimated.

We do not accrue contingencies that might result in gains. We continuously assess contingencies for litigation claims, environmental remediation and other events.

LEGAL FEES

Legal fees that are associated with a past event for which a liability has been recorded are accrued when it is probable that fees also will be incurred.

COMPREHENSIVE INCOME

Comprehensive income includes all changes in the equity of a business enterprise (except those resulting from investments by owners and distributions to owners), including:

§	foreign-currency translation adjustments

§	changes in unamortized net actuarial gain or loss and prior service cost related to pension and other postretirement benefits plans

§	unrealized gains or losses on available-for-sale securities

§	certain hedging activities

The Consolidated Statements of Comprehensive Income show the changes in the components of other comprehensive income (OCI), including the amounts attributable to noncontrolling interests. The components of Accumulated Other Comprehensive Income (Loss) (AOCI), shown net of income taxes on the Consolidated Balance Sheets, and the related income tax balances at December 31, 2011 and 2010 are as follows:

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) AND
ASSOCIATED INCOME TAX EXPENSE (BENEFIT)
(Dollars in millions)
	Accumulated Other Comprehensive Income (Loss)				Income Tax Expense (Benefit)
	2011		2010		2011		2010
Sempra Energy Consolidated
Foreign currency translation loss	$	(359)	$	(229)	$	(3)	$	―
Financial instruments		(31)		(15)		(22)		(12)
Unrealized gains on available-for-sale securities		―		1		―		1
Unamortized net actuarial loss		(100)		(88)		(68)		(60)
Unamortized prior service credit		1		1		1		1
Balance as of December 31	$	(489)	$	(330)	$	(92)	$	(70)
SDG&E
Unamortized net actuarial loss	$	(11)	$	(11)	$	(8)	$	(8)
Unamortized prior service credit		1		1		1		1
Balance as of December 31	$	(10)	$	(10)	$	(7)	$	(7)
SoCalGas
Unamortized net actuarial loss	$	(6)	$	(5)	$	(4)	$	(4)
Unamortized prior service credit		1		1		―		1
Financial instruments		(16)		(18)		(11)		(12)
Balance as of December 31	$	(21)	$	(22)	$	(15)	$	(15)

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 noncontrolling interests. As a result, noncontrolling interests are reported as a separate component of equity on the Consolidated Balance Sheets and Consolidated Statements of Comprehensive Income. Net income or loss attributable to the noncontrolling interests is separately identified on the Consolidated Statements of Operations.

The preferred stock at SoCalGas is presented at Sempra Energy as a noncontrolling interest at December 31, 2011 and 2010. The preferred stock of SDG&E is contingently redeemable preferred stock. At Sempra Energy, the preferred stock dividends of SDG&E, SoCalGas and PE are charges against income related to noncontrolling interests. We provide additional information concerning preferred stock in Note 12. At December 31, 2011 and 2010 we reported the following noncontrolling ownership interests held by others:

OWNERSHIP INTERESTS HELD BY OTHERS AS OF DECEMBER 31
(Dollars in millions)
		Percent Ownership Held by Others			2011		2010
Bay Gas(1)		9	%	$	17	$	15
Southern Gas Transmission(1)		49			1		1
Liberty(1)		25			9		(18)
Tecsur(2)		10			4		-
Luz del Sur(2)		20			216		-
Chilquinta Energía(2)		15 - 43			34		-
Otay Mesa VIE (at SDG&E)		100			102		113
Total Sempra Energy				$	383	$	111
(1)	Part of Sempra Natural Gas.
(2)	Controlling interest acquired in 2011.

REVENUES

Utilities

Our California Utilities generate revenues primarily from deliveries to their customers of electricity by SDG&E and natural gas by both SoCalGas and SDG&E and from related services. They record these revenues following the accrual method and recognize them upon delivery and performance. They also record revenue from CPUC-approved incentive awards, some of which require approval by the CPUC prior to being recognized. We provide additional discussion on utility incentive mechanisms in Note 14.

Under an operating agreement with the California Department of Water Resources (DWR), SDG&E acts as a limited agent on behalf of the DWR in the administration of energy contracts, including natural gas procurement functions under the DWR contracts allocated to SDG&E’s customers. The legal and financial responsibilities associated with these activities continue to reside with the DWR. Accordingly, the commodity costs associated with long-term contracts allocated to SDG&E from the DWR (and the revenues to recover those costs) are not included in our Consolidated Statements of Operations. We provide discussion on electric industry regulation related to the DWR in Note 14.

On a monthly basis, SoCalGas accrues natural gas storage contract revenues, which consist of storage reservation and variable charges based on negotiated agreements with terms of up to 15 years.

Our natural gas utilities outside of California, Mobile Gas and Ecogas, apply GAAP for regulated utilities consistent with the California Utilities.

Our utilities in South America, which were consolidated as part of our Sempra South American Utilities segment beginning April 6, 2011 as we discuss in Note 3, are Chilquinta Energía and Luz del Sur. Chilquinta Energía is an electric distribution utility serving customers in the cities of Valparaiso and Viña del Mar in central Chile. Luz del Sur is an electric distribution utility in the southern zone of metropolitan Lima, Peru. The companies serve primarily regulated customers, and their revenues are based on tariffs that are set by the National Energy Commission (Comisión Nacional de Energía, or CNE) in Chile and the Energy and Mining Investment Supervisory Body (Organismo Supervisor de la Inversión en Energía y Minería, or OSINERGMIN) of the National Electricity Office under the Ministry of Energy and Mines in Peru.

The tariffs charged are based on an efficient model distribution company defined by Chilean law in the case of Chilquinta Energía, and OSINERGMIN in the case of Luz del Sur. The tariffs include operation and maintenance costs, an internal rate of return on the new replacement value (Valor Nuevo de Reemplazo, or VNR) of depreciable assets, charges for the use of transmission systems, and a component for the value added by the distributor. Tariffs are designed to provide for a pass-through to customers of the main noncontrollable cost items (mainly power purchases and transmission charges), recovery of reasonable operating and administrative costs, incentives to reduce costs and make needed capital investments and a regulated rate of return on the distributor’s regulated asset base. Because the tariffs are based on a model and are intended to cover the costs of the model company, but are not based on the costs of the specific utility and may not result in full cost recovery, they do not meet the requirement necessary for treatment under applicable GAAP for regulatory accounting.

For Chilquinta Energía, rates for four-year periods related to distribution and transmission are reviewed separately on an alternating basis every two years. Their next review is scheduled to be completed, with tariff adjustments also going into effect, in November 2012 for distribution and November 2014 for transmission.

The components of tariffs above for Luz del Sur are reviewed and adjusted every four years. Their next review is scheduled to be completed, with tariff adjustments also going into effect, in November 2013.

The table below shows the total utilities revenues in Sempra Energy’s Consolidated Statements of Operations for each of the last three years. The revenues include amounts for services rendered but unbilled (approximately one-half month’s deliveries) at the end of each year.

TOTAL UTILITIES REVENUES AT SEMPRA ENERGY CONSOLIDATED(1)
(Dollars in millions)
		Years ended December 31,
		2011		2010		2009
Natural gas revenues		$	4,489	$	4,491	$	4,002
Electric revenues			3,833		2,528		2,419
Total		$	8,322	$	7,019	$	6,421
(1)	Excludes intercompany revenues.

As we discuss in Note 14, the SDG&E and SoCalGas core natural gas supply portfolios are combined. SoCalGas manages the combined portfolio and procures natural gas for SDG&E’s core customers. Core customers are primarily residential and small commercial and industrial customers. This core gas procurement function is considered a shared service, therefore amounts related to SDG&E are not included in SoCalGas’ Consolidated Statements of Operations.

We provide additional information concerning utility revenue recognition in “Regulatory Matters” above.

Energy-Related Businesses

Sempra Natural Gas

Sempra Natural Gas generates revenues from selling electricity to governmental, public utility and wholesale power marketing entities. These revenues are recognized as the electricity is delivered. In each of 2011, 2010 and 2009, Sempra Natural Gas’ electricity sales to the DWR accounted for a significant portion of its revenues. This contract ended September 30, 2011. Sempra Natural Gas recognizes revenues on natural gas storage and transportation operations when services are provided in accordance with contractual agreements for the storage and transportation services. Sempra Natural Gas revenues also include net realized gains and losses and the net change in the fair value of unrealized gains and losses on derivative contracts for power and natural gas. Related to its LNG terminal and marketing operations, Sempra Natural Gas recognizes revenues from the sale of LNG and natural gas as deliveries are made to counterparties and from reservation and usage fees under terminal capacity agreements.

Sempra Mexico

Sempra Mexico’s pipeline operations recognize revenues from the sale and transportation of natural gas as deliveries are made and from fixed capacity payments. Sempra Mexico also recognizes revenues from (1) the sale of LNG and natural gas as deliveries are made to counterparties and (2) from reservation and usage fees under terminal capacity agreements, nitrogen injection service agreements and tug service agreements. It reports revenue net of value added taxes in Mexico. Sempra Mexico’s revenues also include net realized gains and losses and the net change in the fair value of unrealized gains and losses on derivative contracts for natural gas.

Sempra Commodities

On April 1, 2008, our commodities-marketing businesses, previously wholly owned subsidiaries of Sempra Energy, were sold into RBS Sempra Commodities LLP (RBS Sempra Commodities), a partnership jointly owned by Sempra Energy and The Royal Bank of Scotland. Therefore, beginning April 1, 2008, we have accounted for our earnings in the partnership under the equity method. In 2010 and early 2011, the partnership divested its principal businesses and assets. We provide more information on these matters in Notes 3 and 4.

RBS Sempra Commodities generated most of its revenues from trading and marketing activities in natural gas, electricity, petroleum, petroleum products, base metals and other commodities. RBS Sempra Commodities quoted bid and ask prices to end users and other market makers. It also earned trading profits as a dealer by structuring and executing transactions. Principal transaction revenues were recognized on a trade-date basis and included realized gains and losses and the net change in unrealized gains and losses.

RBS Sempra Commodities used derivative instruments to reduce its exposure to unfavorable changes in market prices. Non-derivative contracts were accounted for on an accrual basis and the related profit or loss was recognized as the contracts were settled.

OTHER COST OF SALES

Other Cost of Sales primarily includes pipeline capacity marketing costs, and pipeline transportation and natural gas marketing costs incurred at Sempra Natural Gas and electrical construction costs at Sempra South American Utilities. The costs at Sempra South American Utilities are related to the energy-services companies in South America that we discuss in Note 3.

OPERATION AND MAINTENANCE EXPENSES

Operation and Maintenance includes operating and maintenance costs, and general and administrative costs, which consist primarily of personnel costs, purchased materials and services, and rent. SDG&E’s and SoCalGas’ Operation and Maintenance includes litigation expense, which is shown separately on Sempra Energy’s Consolidated Statements of Operations.

FOREIGN CURRENCY TRANSLATION

Our operations in South America and our natural gas distribution utility in Mexico use their local currency as their functional currency. The assets and liabilities of their foreign operations are translated into U.S. dollars at current exchange rates at the end of the reporting period, and revenues and expenses are translated at average exchange rates for the year. The resulting noncash translation adjustments do not enter into the calculation of earnings or retained earnings (unless the operation is being discontinued), but are reflected in Comprehensive Income and in Accumulated Other Comprehensive Income (Loss), a component of shareholders’ equity.

To reflect the fluctuations in the values of functional currencies of our South American investments, which were accounted for under the equity method prior to April 6, 2011, the following adjustments were made to the carrying value of these investments (dollars in millions):

			Upward (downward) adjustment to investments
Investment		Currency	2011(1)		2010		2009
Chilquinta Energía		Chilean Peso	$	(10)	$	34	$	85
Luz del Sur		Peruvian Nuevo Sol		―		5		13
(1)	As discussed in Note 3, the cumulative foreign currency translation adjustment balances totaling $54 million in Accumulated Other Comprehensive Income (Loss) as of April 6, 2011 were reclassified to net income as a result of the gain on the remeasurement of our equity method investments in Chilquinta Energía and Luz del Sur during the second quarter of 2011.

Smaller adjustments have been made to other operations where the U.S. dollar is not the functional currency. We provide additional information concerning these investments in Note 4.

Currency transaction gains and losses in a currency other than the entity’s functional currency are included in the calculation of Other Income, Net, at Sempra Energy as follows:

	Years ended December 31,
(Dollars in millions)	2011		2010		2009
Currency transaction gain	$	11	$	4	$	3

TRANSACTIONS WITH AFFILIATES

Loans to Unconsolidated Affiliates

Sempra South American Utilities has a U.S. dollar-denominated loan to Camuzzi Gas del Sur S.A., an affiliate of the segment’s Argentine investments which we discuss in Note 4. The loan has an $18 million principal balance outstanding plus $6 million of accumulated interest at a variable interest rate (7.377 percent at December 31, 2011). In June 2011, the maturity date of the loan was extended from June 2011 to June 30, 2012. The loan was fully reserved at December 31, 2010 and 2011.

Investments

Sempra Energy, at Parent and Other, has an investment in bonds issued by Chilquinta Energía that we discuss in Note 5.

Other Affiliate Transactions

Sempra Energy, SDG&E and SoCalGas provide certain services to each other and are charged an allocable share of the cost of such services. Amounts due to/from affiliates are as follows:

AMOUNTS DUE TO AND FROM AFFILIATES AT SDG&E AND SOCALGAS
(Dollars in millions)
		December 31,
		2011		2010
SDG&E
Current:
Due from SoCalGas		$	2	$	11
Due from various affiliates			65		1
		$	67	$	12

Due to Sempra Energy		$	14	$	16

Income taxes due from Sempra Energy(1)		$	97	$	25

SoCalGas
Current:
Due from Sempra Energy		$	23	$	60
Due from various affiliates			17		―
Due from RBS Sempra Commodities			―		3
		$	40	$	63

Due to SDG&E		$	2	$	11

Income taxes due from (to) Sempra Energy(1)		$	17	$	(3)
(1)	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 the companies’ having always filed a separate return.

Revenues from unconsolidated affiliates at our utility businesses are as follows:

Transactions with RBS Sempra Commodities

Several of our segments have engaged in transactions with RBS Sempra Commodities. As a result of the divestiture of substantially all of RBS Sempra Commodities’ businesses, transactions between our segments and RBS Sempra Commodities were assigned over time to the buyers of the joint venture businesses. The assignments of the related contracts were substantially completed by May 1, 2011. Amounts in our Consolidated Financial Statements related to these transactions are as follows:

AMOUNTS RECORDED FOR TRANSACTIONS WITH RBS SEMPRA COMMODITIES
(Dollars in millions)
		Years ended December 31,
		2011(1)		2010			2009
Revenues:
SoCalGas		$	―	$	14	$	13
Sempra Mexico			37		82		39
Sempra Natural Gas			7		184		35

Cost of natural gas:
SDG&E		$	―	$	3	$	4
SoCalGas			―		36		19
Sempra Mexico			74		193		67
Sempra Natural Gas			3		177		20
(1)	With the exception of Sempra Mexico, whose contract with RBS Sempra Commodities expired in July 2011, amounts only include activities prior to May 1, 2011, the date by which substantially all the contracts with RBS Sempra Commodities were assigned to buyers of the joint venture businesses.

				December 31,
				2010
Fixed-price contracts and other derivatives - Net Asset (Liability):
Sempra Mexico				$	(6)
Sempra Natural Gas					(12)
Total				$	(18)

Due to unconsolidated affiliates:
Sempra Mexico				$	11
Sempra Natural Gas					13
Sempra Commodities					11
Total				$	35

Due from unconsolidated affiliates:
SoCalGas				$	3
Sempra Mexico					12
Sempra Natural Gas					14
Parent and other					5
Total				$	34

RESTRICTED NET ASSETS

Sempra Energy Consolidated

As we discuss below, the California Utilities have restrictions on the amount of funds that can be transferred to Sempra Energy by dividend, advance or loan as a result of conditions imposed by various regulators. Additionally, certain other Sempra Energy subsidiaries are subject to various financial and other covenants and other restrictions contained in debt and credit agreements described in Note 5 and in other agreements that limit the amount of funds that can be transferred to Sempra Energy. At December 31, 2011, Sempra Energy was in compliance with all covenants related to its debt agreements.

At December 31, 2011, the amount of restricted net assets of wholly owned subsidiaries of Sempra Energy, including the California Utilities discussed below, that may not be distributed to Sempra Energy in the form of a loan or dividend is $4.8 billion. Although the restrictions cap the amount of funding that the various operating subsidiaries can provide to Sempra Energy, we do not believe these restrictions will have a significant impact on our ability to access cash to pay dividends.

As we discuss in Note 4, $78 million of Sempra Energy’s consolidated retained earnings balance represents undistributed earnings of equity method investments at December 31, 2011.

Significant restrictions of subsidiaries include

§	Wholly owned Mobile Gas has long-term debt instruments containing restrictions relating to the payment of dividends and other distributions with respect to capital stock. Under these restrictions, net assets of approximately $116 million are restricted at December 31, 2011.

§	91-percent owned Bay Gas has long-term debt instruments containing restrictions relating to the payment of dividends and other distributions if Bay Gas does not maintain a specified debt service coverage ratio. Bay Gas had no restricted net assets at December 31, 2011.

50-percent owned Fowler Ridge 2 Wind Farm (Fowler Ridge 2) and Cedar Creek 2 Wind Farm (Cedar Creek 2) have debt agreements which require each joint venture to maintain reserve accounts in order to pay the projects’ debt service and operation and maintenance requirements. As a result of these requirements, total joint venture net assets of approximately $23 million at Fowler Ridge 2 and $18 million at Cedar Creek 2, respectively, are restricted at December 31, 2011. We discuss Sempra Energy guarantees associated with these requirements in Note 5.

§	Peru and Mexico require domestic corporations to maintain minimum reserves for future litigation expense as a percentage of capital stock, resulting in restricted net assets of $35 million at Luz del Sur and $22 million at Sempra Energy’s Mexican subsidiaries as of December 31, 2011.

California Utilities

The CPUC’s regulation of the California Utilities’ capital structures limits the amounts that are available for dividends and loans to Sempra Energy. At December 31, 2011, Sempra Energy could have received combined loans and dividends of approximately $969 million from SoCalGas and approximately $400 million from SDG&E.

The payment and amount of future dividends for SDG&E and SoCalGas are within the discretion of their board of directors. The following restrictions limit the amount of retained earnings that may be dividended or loaned to Sempra Energy from either utility:

§	The CPUC requires that SDG&E’s and SoCalGas’ common equity ratios be no lower than one percentage point below the CPUC authorized percentage of each entity’s authorized capital structure, which is currently:

§	49 percent at SDG&E

§	48 percent at SoCalGas

§	The FERC requires SDG&E to maintain a common equity ratio of 30 percent or above

§	The California Utilities have a combined revolving credit line that requires each utility to maintain a ratio of consolidated indebtedness to consolidated capitalization (as defined in the agreement) of no more than 65 percent, as we discuss in Note 5

Based upon these restrictions, $3.3 billion of SDG&E’s and $1.2 billion of SoCalGas’ net assets are restricted as of December 31, 2011 and may not be transferred to Sempra Energy.

OTHER INCOME, NET

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

OTHER INCOME, NET
(Dollars in millions)
		Years ended December 31,
		2011		2010		2009
Sempra Energy Consolidated:
Allowance for equity funds used during construction		$	99	$	57	$	39
Investment gains(1)			22		35		55
(Losses) gains on interest rate and foreign exchange instruments(2)			(14)		(24)		33
Regulatory interest income, net(3)			2		1		4
Sundry, net(4)			21		71		18
	Total	$	130	$	140	$	149
SDG&E:
Allowance for equity funds used during construction		$	80	$	43	$	29
Regulatory interest income, net(3)			2		―		5
(Losses) gains on interest rate instruments(5)			(1)		(34)		27
Sundry, net			(2)		1		3
	Total	$	79	$	10	$	64
SoCalGas:
Allowance for equity funds used during construction		$	19	$	14	$	10
Regulatory interest income (expense), net(3)			―		1		(1)
Sundry, net			(6)		(3)		(2)
	Total	$	13	$	12	$	7
(1)	Represents investment gains 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.
(2)	Sempra Energy Consolidated includes Otay Mesa VIE and additional instruments.
(3)	Interest on regulatory balancing accounts.
(4)	Amount in 2010 includes proceeds of $48 million from a legal settlement.
(5)	Related to Otay Mesa VIE.

NOTE 2. NEW ACCOUNTING STANDARDS

We describe below recent pronouncements that have had or may have a significant effect on our financial statements. We do not discuss recent pronouncements that are not anticipated to have an impact on or are unrelated to our financial condition, results of operations, cash flows or disclosures.

SEMPRA ENERGY, SDG&E AND SOCALGAS

ASU 2011-04, “Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and International Financial Reporting Standards (IFRSs)” (ASU 2011-04): ASU 2011-04 amends ASC Topic 820, Fair Value Measurements and Disclosures, and provides changes in the wording used to describe the requirements for measuring fair value and disclosing information about fair value measurement. ASU 2011-04 results in common fair value measurement and disclosure requirements under both GAAP and IFRSs.

ASU 2011-04 expands fair value measurement disclosures for Level 3 instruments to require

§	quantitative information about the unobservable inputs

§	a description of the valuation process

§	a qualitative discussion about the sensitivity of the measurements

We will adopt ASU 2011-04 on January 1, 2012 as required and do not expect it to affect our financial position, results of operations or cash flows. We will provide the additional disclosure in our 2012 interim financial statements.

ASU 2011-05, “Presentation of Comprehensive Income” (ASU 2011-05) and ASU 2011-12, “Deferral of the Effective Date for Amendments to the Presentation of Reclassifications of Items Out of Accumulated Other Comprehensive Income in Accounting Standards Update No. 2011-05” (ASU 2011-12): We discuss ASU 2011-05 and ASU 2011-12 in Note 1.

ASU 2011-08, “Testing Goodwill for Impairment” (ASU 2011-08): ASU 2011-08 amends ASC Topic 350, Intangibles—Goodwill and Other, to provide an option to first make a qualitative assessment of whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount before applying the two-step, quantitative goodwill impairment test. An entity is required to perform the two-step, quantitative impairment test only if it determines that it is more likely than not that the fair value of a reporting unit is less than its carrying amount.

We adopted ASU 2011-08 for our annual goodwill impairment testing as of October 1, 2011. It did not significantly affect our testing of goodwill.

ASU 2011-11, “Disclosures about Offsetting Assets and Liabilities” (ASU 2011-11): In order to allow for balance sheet comparison between GAAP and IFRSs, ASU 2011-11 requires enhanced disclosures related to financial assets and liabilities eligible for offsetting in the statement of financial position. An entity will have to disclose both gross and net information about financial instruments and transactions subject to a master netting arrangement and eligible for offset, including cash collateral received and posted.

We will adopt ASU 2011-11 on January 1, 2013 as required and do not expect it to affect our financial position, results of operations or cash flows. We will provide the additional disclosure in our 2013 interim financial statements.

NOTE 3. ACQUISITION AND INVESTMENT ACTIVITY

SEMPRA SOUTH AMERICAN UTILITIES

Chilquinta Energía and Luz del Sur

On April 6, 2011, Sempra South American Utilities acquired from AEI its interests in Chilquinta Energía in Chile and Luz del Sur in Peru, and their subsidiaries. Prior to the acquisition, Sempra South American Utilities and AEI each owned 50 percent of Chilquinta Energía and approximately 38 percent of Luz del Sur. Upon completion of the acquisition, Sempra South American Utilities owned 100 percent of Chilquinta Energía and approximately 76 percent of Luz del Sur, with the remaining shares of Luz del Sur held by institutional investors and the general public. As part of the transaction, Sempra South American Utilities also acquired AEI’s interests in two energy-services companies, Tecnored S.A. and Tecsur S.A. The adjusted purchase price of $888 million resulted from valuing the net assets in Chile, Peru and other holding companies at $495 million, $385 million and $8 million, respectively. We paid $611 million in cash ($888 million less $245 million of cash acquired and $32 million of consideration withheld for a liability related to the purchase).

As part of our acquisition of AEI’s interest in Luz del Sur, we were required to launch a tender offer to the minority shareholders of Luz del Sur to purchase their shares (up to a maximum 14.73 percent interest in Luz del Sur). On August 8, 2011, we initiated a public tender offer for up to 14.73 percent of Luz del Sur’s stock that began on August 9, 2011 and concluded on September 6, 2011 at a price of $2.29 per share. The per share value, computed according to procedures established by the local securities regulatory agency, was based on an independent appraiser’s valuation of $2.22 per share as of April 6, 2011, the date of acquisition, adjusted by an interest rate factor to the value as of August 1, 2011. The interest rate factor is published daily by the Central Bank of Peru. On September 13, 2011, we purchased 18,918,954 additional Luz del Sur shares for $43 million in settlement of the mandatory public tender offer, bringing Sempra South American Utilities’ ownership to 79.82 percent. This equity transaction is presented as Purchase of Noncontrolling Interests on our Consolidated Statement of Cash Flows.

We expect the acquisition to be accretive to our earnings per share in 2012 and beyond, based on historically strong operating performance of the companies and assuming the continuation of sound regulatory environments within stable, growing countries. We provide additional information about Sempra South American Utilities’ investments in Chilquinta Energía and Luz del Sur in Note 4.

We allocated the purchase price on a preliminary basis in the second quarter of 2011. In the third and fourth quarters of 2011, we adjusted the preliminary allocation for additional assets and liabilities identified, including an $11 million premium related to long-term debt at Chilquinta Energía. The retrospective application of these adjustments to prior quarters was de minimus. During the measurement period, up to one year from the acquisition date, we may obtain additional information that allows us to more accurately allocate the purchase price. We will make appropriate adjustments to the purchase price allocation during the measurement period as required. At this time, we do not expect material changes to the value of the assets acquired or liabilities assumed in conjunction with this transaction as presented below. The following table summarizes the consideration paid in the acquisition and the recognized amounts of the assets acquired and liabilities assumed, as well as the fair value at the acquisition date of the noncontrolling interests:

PURCHASE PRICE ALLOCATION
(Dollars in millions)
			At April 6, 2011
								Other
				Chilean		Peruvian		holding		Preliminary		Adjust-		Adjusted
				entities		entities		companies		Allocation		ments		Allocation
Fair value of businesses acquired:
	Cash consideration (fair value of total
	consideration)		$	495	$	385	$	8	$	888	$	―	$	888
	Fair value of equity method
	investments immediately prior to
	the acquisition			495		385		2		882		―		882
	Fair value of noncontrolling interests			37		242		―		279		―		279
Total fair value of businesses acquired				1,027		1,012		10		2,049		―		2,049

Recognized amounts of identifiable assets
	acquired and liabilities assumed:
		Cash		219		22		4		245		―		245
		Accounts receivable(1)		159		101		6		266		(2)		264
		Other current assets		20		19		―		39		2		41
		Property, plant and equipment		554		931		―		1,485		1		1,486
		Other noncurrent assets		66		―		―		66		1		67
		Accounts payable		(79)		(59)		―		(138)		6		(132)
		Short-term debt and current portion
		of long-term debt		―		(47)		―		(47)		―		(47)
		Other current liabilities		(29)		(56)		―		(85)		(4)		(89)
		Long-term debt		(294)		(179)		―		(473)		(11)		(484)
		Other noncurrent liabilities		(90)		(178)		―		(268)		(9)		(277)
Total identifiable net assets				526		554		10		1,090		(16)		1,074
Goodwill			$	501	$	458	$	―	$	959	$	16	$	975

Acquisition-related costs (included in Other
	Operation and Maintenance expense on
	the Consolidated Statement of
	Operations for the year ended
	December 31, 2011)		$	1	$	1	$	―	$	2	$	―	$	2
(1)		We expect acquired accounts receivable to be substantially realizable in cash. Accounts receivable are net of collection allowances of $6 million for Chile and $1 million for Peru.

Our results for the year ended December 31, 2011 include a $277 million gain (both pretax and after-tax) related to the remeasurement of equity method investments, included as Remeasurement of Equity Method Investments on our Consolidated Statement of Operations. We calculated the gain as the difference between the acquisition-date fair value ($882 million) and the book value ($605 million) of our equity interests in Chilquinta Energía and Luz del Sur immediately prior to the acquisition date. This book value of our equity interests included currency translation adjustment balances in Accumulated Other Comprehensive Income (Loss). The valuation techniques we used to allocate the purchase price to the businesses included discounted cash flow analysis and the market multiple approach (enterprise value to earnings before interest, taxes, depreciation and amortization (EBITDA)). Our assumptions for these measures included estimated future cash flows, use of appropriate discount rates, market trading multiples and market transaction multiples. Discount rates used reflect consideration of risk free rates, as well as country and company risk. Methodologies used to determine fair values of material assets as of the date of the acquisition included

§	the replacement cost approach for property, plant and equipment; and

§	goodwill associated primarily with the value of residual future cash flows that we believe these businesses will generate, to be tested annually for impairment. For income tax purposes, none of the goodwill recorded is deductible in Chile, Peru or the United States.

For substantially all other assets and liabilities, our analysis of fair value factors indicated that book value approximates fair value. We valued noncontrolling interests based on the fair value of tangible assets and an allocation of goodwill based on relative enterprise value.

Our Consolidated Statement of Operations includes 100 percent of the acquired companies’ revenues, net income and earnings from the date of acquisition of $1.1 billion, $160 million and $135 million, respectively, for the year ended December 31, 2011. These amounts do not include the remeasurement gain.

Following are pro forma revenues and earnings for Sempra Energy had the acquisition occurred on January 1, 2010, which primarily reflect the incremental increase to revenues and earnings from our increased ownership and consolidation of the entities acquired. Although some short-term debt borrowings may have resulted from the actual acquisition in 2011, we have not assumed any additional interest expense in the pro forma impact on earnings below, as the amounts would be immaterial due to the low interest rates available to us on commercial paper. The pro forma amounts do not include the impact of the increased ownership in Luz del Sur resulting from the tender offer completed in September 2011 discussed above.

		Years ended December 31,
(Dollars in millions)		2011		2010
Revenues		$	10,379	$	10,277
Earnings(1)			1,079		1,062
(1)	Pro forma earnings for 2010 include the $277 million gain related to the remeasurement of equity method investments, and accordingly, pro forma earnings for 2011 exclude the gain.

The companies use their local currency, the Chilean Peso or the Peruvian Nuevo Sol, as their functional currency, and we account for them as discussed above in Note 1 under “Foreign Currency Translation.”

SEMPRA MEXICO

Acquisition of Mexican Pipeline and Natural Gas Infrastructure

On April 30, 2010, Sempra Mexico completed an acquisition resulting in the purchase of the Mexican pipeline and natural gas infrastructure assets of El Paso Corporation for $307 million ($292 million, net of cash acquired).

The acquisition consists of El Paso Corporation’s wholly owned natural gas pipeline and compression assets in the Mexican border state of Sonora and its 50-percent interest in Gasoductos de Chihuahua, a joint venture with PEMEX, the Mexican state-owned oil company. The joint venture operates two natural gas pipelines and a propane system in northern Mexico. The acquisition expands our scale and geographic footprint in a strong growth region in Mexico. The pipeline assets are backed substantially by long-term contracts with a history of consistent revenue streams, allowing us to expand our natural gas infrastructure business in northern Mexico.

The following table summarizes the consideration paid in the acquisition and the recognized amounts of the assets acquired and liabilities assumed:

(Dollars in millions)			At April 30, 2010
Cash consideration (fair value of total consideration)			$	307
Recognized amounts of identifiable assets acquired and liabilities assumed:
	Cash			15
	Accounts receivable			4
	Investment in equity method investee			256
	Property, plant & equipment			25
	Other liabilities			(11)
Total identifiable net assets				289
Goodwill(1)			$	18

Acquisition-related costs (included in Other Operation and Maintenance expense
	on the Consolidated Statement of Operations for the year ended
	December 31, 2010)		$	1
(1)		The goodwill, which represents the residual of the consideration paid over the identifiable net assets, is assigned to the Sempra Mexico segment and is attributed to the strategic value of the transaction. None of the goodwill recorded is deductible in Mexico for income tax purposes.

Included in our Consolidated Statements of Operations are revenues and earnings of $10 million and $33 million, respectively, for the year ended December 31, 2011 and $6 million and $21 million, respectively, for the period May 1, 2010 to December 31, 2010 related to the assets acquired from El Paso Corporation. Proforma impacts on revenues and earnings for Sempra Energy had the acquisition occurred on January 1, 2009 were: additional revenues of $3 million and earnings of $7 million in 2010 and additional revenues of $10 million and earnings of $24 million for 2009.

SEMPRA RENEWABLES

We provide information about investment activity at Sempra Renewables in Note 4.

SEMPRA NATURAL GAS

Purchase of Noncontrolling Interest in Mississippi Hub

In October 2008, Sempra Natural Gas acquired EnergySouth, Inc., an energy-services holding company based in Mobile, Alabama. The principal holdings of EnergySouth, Inc. were EnergySouth Midstream, including Mississippi Hub, and Mobile Gas.

Sempra Natural Gas owned 60 percent of Mississippi Hub through December 31, 2008. On January 16, 2009, Sempra Natural Gas purchased the remaining 40-percent ownership interest of Mississippi Hub for $94 million in cash.

Rockies Express

We discuss Sempra Natural Gas’ investment in Rockies Express Pipeline LLC (Rockies Express) in Note 4.

SEMPRA COMMODITIES

In 2010 and early 2011, Sempra Energy and The Royal Bank of Scotland plc (RBS) sold substantially all of the businesses and assets within RBS Sempra Commodities, a partnership formed in 2008.

We provide additional information concerning RBS Sempra Commodities and these transactions in Notes 4 and 5.

NOTE 4. INVESTMENTS IN UNCONSOLIDATED ENTITIES

We generally account for investments under the equity method when we have an ownership interest of 20 to 50 percent. In these cases, our pro rata shares of the subsidiaries’ net assets are included in Other Investments and in Investment in RBS Sempra Commodities LLP on the Consolidated Balance Sheets. These investments are adjusted for our share of each investee’s earnings or losses, dividends, and other comprehensive income or loss.

The carrying value of unconsolidated subsidiaries is evaluated for impairment under the GAAP provisions for equity method investments. We account for certain investments in housing partnerships made before May 19, 1995 under the cost method, whereby the costs were amortized over ten years down to the expected residual value.

We summarize our investment balances and earnings below:

EQUITY METHOD AND OTHER INVESTMENTS ON THE CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
		Investment at December 31,
		2011		2010
Parent and other:
Investment in RBS Sempra Commodities LLP		$	126	$	787
Other equity method investments:
Sempra Mexico:
Gasoductos de Chihuahua		$	302	$	275
Sempra Renewables:
Auwahi Wind			11		―
Cedar Creek 2 Wind Farm			95		113
Fowler Ridge 2 Wind Farm			50		72
Flat Ridge 2 Wind Farm			146		―
Mehoopany Wind Farm			88		―
Sempra Natural Gas:
Rockies Express			800		854
Sempra South American Utilities:
Chilquinta Energía(1)			―		432
Luz del Sur(1)			―		216
Parent and other:
Housing partnerships			11		16
Total other equity method investments			1,503		1,978
Cost method investments - housing partnerships			10		12
Other(2)			32		174
Total		$	1,545	$	2,164
(1)	Sempra South American Utilities' interests in Chilquinta Energía and Luz del Sur are no longer recorded as equity method investments, but are consolidated effective April 6, 2011 (discussed below and in Note 3).
(2)	Other includes Sempra South American Utilities' $11 million in real estate investments at December 31, 2011; Parent and Other's $57 million investment in Chilquinta Energía bonds at December 31, 2010 (discussed in Note 5); and Sempra Natural Gas' $21 million and $117 million investment in industrial development bonds at Mississippi Hub at December 31, 2011 and 2010, respectively.

EQUITY METHOD INVESTMENTS ON THE CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
		Years ended December 31,
		2011		2010		2009
Earnings (losses) recorded before income tax:
Sempra Renewables:
Fowler Ridge 2 Wind Farm		$	(4)	$	1	$	1
Cedar Creek 2 Wind Farm			(2)		―		―
Sempra Natural Gas:
Rockies Express			43		43		50
Elk Hills Power			―		(13)		(3)
Parent and other:
RBS Sempra Commodities LLP			(24)		(314)		463
Housing partnerships			(4)		(9)		(12)
		$	9	$	(292)	$	499

Earnings (losses) recorded net of income tax:
Sempra South American Utilities:
Sodigas Pampeana and Sodigas Sur		$	(1)	$	(44)	$	7
Chilquinta Energía(1)			12		33		23
Luz del Sur(1)			12		41		38
Sempra Mexico:
Gasoductos de Chihuahua			29		19		―
		$	52	$	49	$	68
(1)	These investments were accounted for under the equity method until April 6, 2011, when they became consolidated entities upon our acquisition of additional ownership interests.

Our share of the undistributed earnings of equity method investments was $78 million and $570 million at December 31, 2011 and 2010, respectively. Our undistributed earnings decreased in 2011 due to our consolidation of Chilquinta Energía and Luz del Sur. The December 31, 2011 balance also does not include remaining distributions of $126 million associated with our investment in RBS Sempra Commodities, which we expect to receive from the partnership in 2012. However, minor amounts may be retained by the partnership beyond 2012 to help offset unanticipated future general and administrative costs necessary to complete the dissolution of the partnership.

Equity method goodwill related to our unconsolidated subsidiaries located in Mexico and in South America (prior to the acquisition of AEI’s interests in Chilquinta Energía and Luz del Sur, as discussed in Note 3), is included in Other Investments on the Sempra Energy Consolidated Balance Sheets. These amounts, before foreign currency translation adjustments, were $64 million at December 31, 2011 and $317 million at December 31, 2010. Including foreign currency translation adjustments, these amounts were

§	$64 million at December 31, 2011

§	$333 million at December 31, 2010

We discuss our equity method investments below.

SEMPRA SOUTH AMERICAN UTILITIES

As discussed in Note 3, on April 6, 2011, Sempra South American Utilities acquired from AEI its interests in Chilquinta Energía in Chile and Luz del Sur in Peru, and their subsidiaries. Prior to the acquisition, Sempra South American Utilities and AEI each owned 50 percent of Chilquinta Energía and approximately 38 percent of Luz del Sur. Chilquinta Energía and Luz del Sur are consolidated effective April 6, 2011 and are no longer recorded as equity method investments.

Sempra South American Utilities owns 43 percent of two Argentine natural gas utility holding companies, Sodigas Pampeana and Sodigas Sur. As a result of the devaluation of the Argentine peso at the end of 2001 and subsequent changes in the value of the peso, Sempra South American Utilities reduced the carrying value of its investment by a cumulative total of $270 million as of December 31, 2011. These noncash adjustments, based on fluctuations in the value of the Argentine peso, did not affect earnings, but were recorded in Comprehensive Income and Accumulated Other Comprehensive Income (Loss). The Argentine economic decline and government responses (including Argentina’s unilateral, retroactive abrogation of utility agreements early in 2002) continue to adversely affect the operations of these Argentine utilities. In 2002, Sempra South American Utilities initiated arbitration proceedings at the International Center for the Settlement of Investment Disputes (ICSID) under the 1994 Bilateral Investment Treaty between the United States and Argentina for recovery of the diminution of the value of its investments that has resulted from Argentine governmental actions. In September 2007, the tribunal awarded us compensation of $172 million, which included interest up to the award date. In January 2008, Argentina filed an action at the ICSID seeking to annul the award. In June 2010, the Annulment Committee granted Argentina’s petition for annulment of the award. This action did not impact our earnings, as we did not record the original award pending assurance of collectability. On November 3, 2010, Sempra South American Utilities resubmitted arbitration proceedings against Argentina before the ICSID on the same and similar grounds as the 2002 filing.

In a separate but related proceeding related to our political risk insurance policy, we negotiated a $48 million settlement that was collected in September 2010. The proceeds from the settlement are reported in Other Income, Net, on the Consolidated Statement of Operations for the year ended December 31, 2010.

In December 2006, we decided to sell our Argentine investments, and we continue to actively pursue their sale. We adjusted our investments to estimated fair value and recorded a noncash impairment charge to 2006 earnings of $221 million. In September 2010, we concluded that, although the ICSID claim had been annulled as discussed above, rate increases sought in Argentina would continue to be delayed. We believe this continued uncertainty has impacted the fair value of our net investment in the two Argentine companies, and recorded a noncash impairment charge of $24 million in the third quarter of 2010. The Sodigas Pampeana and Sodigas Sur fair value was significantly impacted by unobservable inputs (i.e., Level 3 inputs) as defined by the accounting guidance for fair value measurements, which we discuss in Note 11. The inputs included discount rates and estimated future cash flows. Such cash flows considered the value of those businesses with positive cash flows, the value of the non-operating assets, and the probability-weighted value of anticipated rate increases, considering both the timing and magnitude of such increases. In the fourth quarter of 2010, based on our continuing intention to sell the investments and recent comparable transactions in the Argentine energy market, we recorded an additional noncash impairment charge of $20 million. Also in the fourth quarter of 2010, we recorded an income tax benefit of $15 million related to the impairment charges. These pretax adjustments to fair value are reported in Equity Earnings, Net of Income Tax, while the related tax benefit is reported in Income Tax Expense on the Consolidated Statement of Operations for the year ended December 31, 2010.

SEMPRA MEXICO

Sempra Mexico owns a 50-percent interest in Gasoductos de Chihuahua, a joint venture with PEMEX. The joint venture operates two natural gas pipelines and a propane system in northern Mexico. Sempra Mexico acquired its investment in Gasoductos de Chihuahua as part of the purchase of Mexican pipeline and natural gas infrastructure assets that we discuss in Note 3.

SEMPRA RENEWABLES

Sempra Renewables accounts for its investments in all of the following projects using the equity method.

In December 2011, Sempra Renewables invested $146 million in a joint venture with BP Wind Energy, a wholly owned subsidiary of BP p.l.c., to develop the planned 419-MW Flat Ridge 2 Wind Farm project near Wichita, Kansas.

In December 2011, Sempra Renewables invested $88 million in a joint venture with BP Wind Energy to develop the planned 141-MW Mehoopany Wind Farm project near Wyoming County, Pennsylvania.

In October 2011, Sempra Renewables formed a joint venture with BP Wind Energy to develop the Auwahi Wind project in the southeastern region of Maui, a project that was previously wholly owned by Sempra Renewables.

In October 2010, Sempra Renewables invested $209 million to become an equal partner with BP Wind Energy to develop the 250-MW Cedar Creek 2 project near New Raymer, Colorado, which became operational in June 2011. Upon obtaining a construction loan in December 2010, the joint venture returned $96 million of Sempra Renewables’ investment.

During 2009, Sempra Renewables invested $235 million to become an equal partner with BP Wind Energy to develop the 200-MW Fowler Ridge 2 project near Indianapolis, Indiana, which became operational in December 2009. In August 2010, Sempra Renewables received a $180 million return of capital from Fowler Ridge 2.

We discuss Cedar Creek 2 and Fowler Ridge 2 further in Note 5.

SEMPRA NATURAL GAS

Sempra Natural Gas owns a 25-percent interest in Rockies Express, a partnership that operates a natural gas pipeline, the Rockies Express Pipeline (REX), that links producing areas in the Rocky Mountain region to the upper Midwest and the eastern United States. Kinder Morgan Energy Partners, L.P. (KMP) and ConocoPhillips (Conoco) own the remaining interests of 50 percent and 25 percent, respectively. Our total investment in Rockies Express is accounted for as an equity method investment. We made investments in Rockies Express of $65 million in 2010 and $625 million in 2009.

The 550-MW Elk Hills Power (Elk Hills) plant located near Bakersfield, California began commercial operations in July 2003. On December 31, 2010, Sempra Natural Gas sold its 50-percent interest to Occidental Petroleum Corporation, Inc. for a cash purchase price plus year-end cash distribution totaling $179 million. In connection with the sale, Sempra Natural Gas recorded a $10 million pretax loss that is included in Equity Earnings (Losses), Before Income Tax — Other on the Consolidated Statement of Operations for the year ended December 31, 2010.

RBS SEMPRA COMMODITIES

RBS Sempra Commodities is a United Kingdom limited liability partnership formed by Sempra Energy and RBS in 2008 to own and operate the commodities-marketing businesses previously operated through wholly owned subsidiaries of Sempra Energy. We account for our investment in RBS Sempra Commodities under the equity method. Our share of partnership earnings is reported in the Parent and Other business unit. Prior to September 1, 2010, subject to certain limited exceptions, partnership pretax income was allocated each year as follows:

§	First, we received a preferred 15-percent return on our adjusted equity capital.

§	Next, RBS received a preferred 15-percent return on any capital in excess of capital attributable to us that was required by the U.K. Financial Services Authority to be maintained by RBS in respect of the operations of the partnership.

§	Next, we received 70 percent of the next $500 million in pretax income; RBS received the remaining 30 percent.

§	Then, we received 30 percent and RBS received 70 percent of any remaining pretax income.

§	Any losses of the partnership were shared equally between us and RBS.

Subsequent to September 1, 2010, partnership pretax income or loss is allocated equally between us and RBS.

Pretax equity earnings (losses) from RBS Sempra Commodities were $(24) million, $(314) million, and $463 million for the years ended December 31, 2011, 2010 and 2009, respectively. The partnership income that is distributable to us on an annual basis is computed on the partnership’s basis of accounting, IFRS, as adopted by the European Union. For the year ended December 31, 2011, our share of net loss on an IFRS basis was $30 million. For the years ended December 31, 2010, and 2009 our share of distributable income, on an IFRS basis, was $53 million and $300 million, respectively. Included in our pretax equity losses are impairment charges of $16 million in 2011 and $305 million in 2010. These impairments resulted from adjustments to the carrying value of our investment in the partnership at certain reporting dates. We recorded the $305 million charge ($139 million after-tax) to reduce the investment in the partnership in the third quarter of 2010, as projected cash distributions from RBS Sempra Commodities, including proceeds from the sale of the partnership’s businesses and net of expected transition costs, were not expected to fully recover the goodwill included in the carrying value of our investment in the partnership. We recorded a pretax noncash charge of $16 million ($10 million after-tax) in the third quarter of 2011 to further reduce our investment, primarily to reflect additional amounts incurred to conclude the sales of the partnership’s businesses. These charges are included in Equity Earnings (Losses), Before Income Tax — RBS Sempra Commodities LLP, on our Consolidated Statements of Operations. In 2011 and 2010, the fair value of our investment in RBS Sempra Commodities was significantly impacted by unobservable inputs (i.e. Level 3 inputs) as defined by the accounting guidance for fair value measurements, which we discuss in Note 11. The inputs included estimated future cash distributions expected from the partnership, excluding the impact of costs anticipated for transactions that had not closed at the time of fair value measurement. The investment balance of $126 million at December 31, 2011 reflects remaining distributions expected to be received from the partnership in 2012, although minor amounts may be retained by the partnership beyond 2012 to help offset unanticipated future general and administrative costs necessary to complete the dissolution of the partnership.

In November 2009, our partner in the joint venture, RBS, announced its intention to divest its interest in RBS Sempra Commodities in connection with a directive from the European Commission to dispose of certain assets. In February 2010, Sempra Energy, RBS and the partnership entered into an agreement with J.P. Morgan Ventures Energy Corporation (J.P. Morgan Ventures), a unit of J.P. Morgan Chase & Co. (JP Morgan), for J.P. Morgan Ventures to purchase the global metals and oil businesses and the European natural gas and power business from the joint venture. This transaction was completed on July 1, 2010, and we received our share of the proceeds in the third quarter of 2010. The purchase price was $1.6 billion, and our share of the proceeds was approximately $1 billion, including distributions of 2009 partnership income attributable to the businesses sold, which were $134 million of the $198 million in distributions we received in April 2010 discussed below.

This sale to J.P. Morgan Ventures did not include RBS Sempra Commodities’ North American power and natural gas trading businesses and its retail energy solutions business. In September 2010, Noble Group Ltd. (Noble Group) agreed to acquire the U.S. retail commodity marketing business of the RBS Sempra Commodities joint venture for $318 million in cash, plus assumption of all debt, and the transaction closed on November 1, 2010. In October 2010, J.P. Morgan Ventures agreed to purchase most of the remaining assets of RBS Sempra Commodities. The assets sold included the joint venture’s wholesale natural gas and power trading agreements, as well as over-the-counter and exchange-traded transactions, with counterparties across North America. This transaction closed on December 1, 2010 and essentially completed the divestiture of the joint venture’s principal businesses and assets. In February 2011, the partnership’s remaining trading systems and certain residual assets were sold to Société Générale. Distributions in 2010 related to the completed sales transactions were $849 million.

On April 15, 2011, we and RBS entered into a letter agreement (Letter Agreement) which amended certain provisions of the agreements that formed RBS Sempra Commodities. The Letter Agreement addresses the wind-down of the partnership and the distribution of the partnership’s remaining assets. In accordance with the Letter Agreement, we received distributions of $623 million in 2011. These distributions included sales proceeds and our portion of 2010 distributable income totaling $651 million, less amounts to settle certain liabilities that we owed to RBS of $28 million. We received cash distributions of earnings from the partnership of $198 million and $407 million in 2010 and 2009, respectively. The Letter Agreement affirms that RBS Sempra Commodities will consider additional distributions of capital after taking into account various factors including available cash, the need for prudent reserves, potential payouts to the purchasers of the partnership’s businesses, and any accrued or projected future operating losses or other wind-down expenses of the partnership. At December 31, 2011, the transfer of trading accounts to the buyers of the businesses, including J.P. Morgan Ventures, is essentially complete, including the collection of accounts receivable and trading margin, as applicable. Accordingly, cash availability is not significantly impacted by remaining trading accounts. Under the Letter Agreement, future distributions will generally be made 51 percent to RBS, and 49 percent to us. The Letter Agreement also allows RBS Sempra Commodities to make capital calls to us, subject to certain limits, if necessary to support the remaining operations, for other liabilities or for other payments owed in connection with the sales transactions (subject to additional limitations). We do not anticipate any such capital calls.

In connection with the Letter Agreement described above, we also released RBS from its indemnification obligations with respect to the items for which JP Morgan has agreed to indemnify us.

The following table shows summarized financial information for RBS Sempra Commodities (on a GAAP basis):

RBS SEMPRA COMMODITIES SUMMARIZED FINANCIAL INFORMATION
(Dollars in millions)
	Years ended December 31,
		2011		2010		2009
Gross revenues and fee income	$	59	$	1,028	$	2,179
Gross profit		8		553		1,461
Partnership net (loss) income		(14)		(169)		639

	At December 31,
	2011		2010
Current assets	$	389	$	4,522
Noncurrent assets		2		27
Current liabilities		152		2,898
Members’ capital		239		1,651

Sempra Financial

Prior to June 2006, Sempra Financial (a former Sempra Energy business unit) invested as a limited partner in affordable-housing properties. Sempra Financial’s portfolio included 1,300 properties throughout the United States that provided income tax benefits (primarily from income tax credits). In June 2006, Sempra Financial effectively sold the majority of its interests in affordable-housing projects to an unrelated party subject to certain guarantees. Because of the guarantees, the transaction was recorded as a financing transaction rather than as a sale, and we continue to consolidate the investments in the housing partnerships. The transaction almost completely eliminated the income tax benefits from the investments.

OTHER EQUITY METHOD INFORMATION

We present aggregated information below for:

§	Chilquinta Energía (prior to acquisition in April 2011)

§	Luz del Sur (prior to acquisition in April 2011)

§	Sodigas Pampeana and Sodigas Sur

§	Gasoductos de Chihuahua

§	Auwahi Wind

§	Cedar Creek 2

§	Fowler Ridge 2

§	Flat Ridge 2 Wind Farm

§	Mehoopany Wind Farm

§	Rockies Express

§	Elk Hills Power (through December 31, 2010)

§	Sempra Energy’s housing partnerships (accounted for under the equity method)

OTHER EQUITY METHOD INFORMATION
(Dollars in millions)
	Years ended December 31,
	2011		2010		2009
Gross revenues	$	798	$	1,829	$	1,433
Gross profit		391		728		529
Income from operations		189		332		224
Gain on sale of assets		4		2		1
Net income		155		256		192

			At December 31,
			2011		2010
Current assets			$	506	$	1,372
Noncurrent assets				2,750		4,264
Current liabilities				234		503
Noncurrent liabilities				750		1,458

NOTE 5. DEBT AND CREDIT FACILITIES

COMMITTED LINES OF CREDIT

At December 31, 2011, Sempra Energy Consolidated had $3.8 billion in committed lines of credit to provide liquidity and to support commercial paper and variable-rate demand notes, the major components of which we detail below. Available unused credit on these lines at December 31, 2011 was $2.7 billion.

Sempra Energy

Sempra Energy has a $1 billion, four-year syndicated revolving credit agreement expiring in October 2014. Citibank, N.A. serves as administrative agent for the syndicate of 23 lenders. No single lender has greater than a 7-percent share.

Borrowings bear interest at benchmark rates plus a margin that varies with market index rates and Sempra Energy’s credit ratings. The facility requires Sempra Energy to maintain a ratio of total indebtedness to total capitalization (as defined in the agreement) of no more than 65 percent at the end of each quarter. The actual ratio at December 31, 2011, calculated as defined in the agreement, was 50.9 percent. 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.

At December 31, 2011, Sempra Energy had $8 million of variable-rate demand notes outstanding supported by the facility.

Sempra Global

Sempra Global has a $2 billion, four-year syndicated revolving credit agreement expiring in October 2014. Citibank, N.A. serves as administrative agent for the syndicate of 23 lenders. No single lender has greater than a 7-percent share.

Sempra Energy guarantees Sempra Global’s obligations under the credit facility. Borrowings bear interest at benchmark rates plus a margin that varies with market index rates and Sempra Energy’s credit ratings. The facility requires Sempra Energy to maintain a ratio of total indebtedness to total capitalization (as defined in the agreement) of no more than 65 percent at the end of each quarter.

At December 31, 2011, Sempra Global had $821 million of commercial paper outstanding supported by the facility. At December 31, 2011 and 2010, respectively, $400 million and $800 million of commercial paper outstanding is classified as long-term debt based on management’s intent and ability to maintain this level of borrowing on a long-term basis either supported by this credit facility or by issuing long-term debt. This classification has no impact on cash flows.

California Utilities

SDG&E and SoCalGas have a combined $800 million, four-year syndicated revolving credit agreement expiring in October 2014. JPMorgan Chase Bank serves as administrative agent for the syndicate of 22 lenders. No single lender has greater than a 7-percent share. The agreement permits each utility to individually borrow up to $600 million, subject to a combined limit of $800 million for both utilities. It also provides for the issuance of letters of credit on behalf of each utility subject to a combined letter of credit commitment of $200 million for both utilities. The amount of borrowings otherwise available under the facility is reduced by the amount of outstanding letters of credit.

Borrowings under the facility bear interest at benchmark rates plus a margin that varies with market index rates and the borrowing utility’s credit ratings. The agreement requires each utility to maintain a ratio of total indebtedness to total capitalization (as defined in the agreement) of no more than 65 percent at the end of each quarter. The actual ratios for SDG&E and SoCalGas at December 31, 2011, calculated as defined in the agreement, were 49.2 percent and 37.6 percent, respectively.

Each utility’s obligations under the agreement are individual obligations, and a default by one utility would not constitute a default by the other utility or preclude borrowings by, or the issuance of letters of credit on behalf of, the other utility.

At December 31, 2011, SDG&E and SoCalGas had no outstanding borrowings and SDG&E had $237 million variable-rate demand notes outstanding supported by the facility. Available unused credit on the lines at December 31, 2011 was $363 million at SDG&E and $563 million at SoCalGas. SoCalGas’ availability reflects the impact of SDG&E’s use of the combined credit available on the line.

GUARANTEES

RBS Sempra Commodities

As we discuss in Note 4, in 2010 and early 2011, Sempra Energy, RBS and RBS Sempra Commodities sold substantially all of the businesses and assets within the partnership in four separate transactions. In connection with each of these transactions, the buyers were, subject to certain qualifications, obligated to replace any guarantees that we had issued in connection with the applicable businesses sold with guarantees of their own. At December 31, 2011, the buyers have substantially completed this process for those counterparties with existing, open positions. For those guarantees which have not been replaced, the buyers are obligated to indemnify us in accordance with the applicable transaction documents for any claims or losses in connection with the guarantees that we issued associated with the businesses sold. We provide additional information in Note 1.

At December 31, 2011, RBS Sempra Commodities no longer requires significant working capital support. However, we have provided back-up guarantees for a portion of RBS Sempra Commodities’ remaining trading obligations. A few of these back-up guarantees may continue for a prolonged period of time. RBS has fully indemnified us for any claims or losses in connection with these arrangements, with the exception of those obligations for which JP Morgan has agreed to indemnify us. We discuss the indemnification release in Note 4.

RBS Sempra Commodities’ net trading liabilities supported by Sempra Energy’s guarantees at December 31, 2011 were $1 million, consisting of guaranteed trading obligations net of collateral. The amount of guaranteed net trading liabilities varies from day to day with the value of the trading obligations and related collateral.

Other Guarantees

Sempra Renewables and BP Wind Energy currently hold 50-percent interests in Fowler Ridge 2 and Cedar Creek 2. After completion of these projects and obtaining term financing in 2010, proceeds from the term loans were used to return $180 million and $95 million, respectively, of each owner’s investments in the joint venture. The term loan of $348 million obtained by Fowler Ridge 2 expires in August 2022, and the $275 million term loan obtained by Cedar Creek 2 expires in June 2029. The term loan agreements require Sempra Renewables and BP Wind Energy to return cash to the projects in the event that the projects do not meet certain cash flow criteria or in the event that the projects’ debt service and operation and maintenance reserve accounts are not maintained at specific thresholds. Sempra Renewables recorded liabilities of $9 million in 2010 and $3 million in 2011 for the fair value of its obligations associated with the cash flow requirements, which constitute guarantees. The liabilities are being amortized over their expected lives. The outstanding loans are not guaranteed by the partners.

WEIGHTED AVERAGE INTEREST RATES

The weighted average interest rates on the total short-term debt outstanding at Sempra Energy were 0.93 percent and 0.46 percent at December 31, 2011 and December 31, 2010, respectively. The weighted average interest rates at December 31, 2011 and 2010 include interest rates for commercial paper borrowings classified as long-term, as we discuss above.

LONG-TERM DEBT

The following tables show the detail and maturities of long-term debt outstanding:

LONG-TERM DEBT
(Dollars in millions)
		December 31,
		2011		2010
SDG&E
First mortgage bonds:
	6.8% June 1, 2015	$	14	$	14
	5.3% November 15, 2015		250		250
	Variable rate (0.08% at December 31, 2011) July 1, 2018(1)		161		161
	5.85% June 1, 2021(1)		60		60
	3% August 15, 2021		350		―
	6% June 1, 2026		250		250
	5% to 5.25% December 1, 2027(1)		150		150
	5.875% January and February 2034(1)		176		176
	5.35% May 15, 2035		250		250
	6.125% September 15, 2037		250		250
	Variable rate (0.90% at December 31, 2011) May 1, 2039(1)		75		75
	6% June 1, 2039		300		300
	5.35% May 15, 2040		250		250
	4.5% August 15, 2040		500		500
	3.95% November 15, 2041		250		―
			3,286		2,686
Other long-term debt (unsecured unless otherwise noted):
	5.9% Notes June 1, 2014		130		130
	5.3% Notes July 1, 2021(1)		39		39
	5.5% Notes December 1, 2021(1)		60		60
	4.9% Notes March 1, 2023(1)		25		25
	OMEC LLC loan at variable rates (5.2925% at December 31, 2011)
	payable 2012 through April 2019 (secured by plant assets)		355		365
Capital lease obligations:
	Purchased-power agreements		180		182
	Other		13		20
			802		821
			4,088		3,507
Current portion of long-term debt			(19)		(19)
Unamortized discount on long-term debt			(11)		(9)
Total SDG&E			4,058		3,479

SoCalGas
First mortgage bonds:
	4.375% January 15, 2011, including $150 at variable rates after
	fixed-to-floating rate swaps		―		250
	4.8% October 1, 2012		250		250
	5.5% March 15, 2014		250		250
	5.45% April 15, 2018		250		250
	5.75% November 15, 2035		250		250
	5.125% November 15, 2040		300		300
			1,300		1,550
Other long-term debt (unsecured):
	4.75% Notes May 14, 2016(1)		8		8
	5.67% Notes January 18, 2028		5		5
Capital lease obligations			11		19
Market value adjustments for interest rate swap, net (expired January 18, 2011)			―		3
			24		35
			1,324		1,585
Current portion of long-term debt			(257)		(262)
Unamortized discount on long-term debt			(3)		(3)
Total SoCalGas			1,064		1,320

LONG-TERM DEBT (Continued)
(Dollars in millions)
		December 31,
		2011		2010
Sempra Energy
Other long-term debt (unsecured):
	6% Notes February 1, 2013		400		400
	8.9% Notes November 15, 2013, including $200 at variable rates after fixed-to-floating
	rate swaps effective January 2011 (8.19% at December 31, 2011)		250		250
	2% Notes March 15, 2014		500		―
	Notes at variable rates (1.22% at December 31, 2011) March 15, 2014		300		―
	6.5% Notes June 1, 2016, including $300 at variable rates after fixed-to-floating
	rate swaps effective January 2011 (4.86% at December 31, 2011)		750		750
	6.15% Notes June 15, 2018		500		500
	9.8% Notes February 15, 2019		500		500
	6% Notes October 15, 2039		750		750
	Employee Stock Ownership Plan Bonds at variable rates payable on demand
	(0.40% at December 31, 2011) November 1, 2014(1)		8		32
Market value adjustments for interest rate swaps, net (expire November 2013 and June 2016)			16		―

Sempra Global
Other long-term debt (unsecured):
	Commercial paper borrowings at variable rates, classified as long-term debt
	(0.74% weighted average at December 31, 2011)		400		800

Sempra South American Utilities
Other long-term debt (unsecured):
Chilquinta Energía
	2.75% Series A Bonds October 30, 2014(1)		24		―
	4.25% Series B Bonds October 30, 2030(1)		202		―
Luz del Sur
	Notes at 5.72% to 7.91% payable 2012 through 2021		185		―
	Bank loans 5.45% to 6.75% payable 2012 through 2016		41		―

Sempra Natural Gas
First mortgage bonds (Mobile Gas):
	6.9% payable 2011 through 2017		―		7
	8.75% payable 2011 through 2022		―		8
	7.48% payable 2011 through 2023		―		5
	4.14% September 30, 2021		20		―
	5% September 30, 2031		42		―
Other long-term debt (unsecured unless otherwise noted):
	Notes at 2.87% to 5.05% payable 2012 through 2013(1)		24		52
	9% Notes May 13, 2013		1		1
	8.45% Notes payable 2012 through 2017, secured		29		32
	4.5% Notes July 1, 2024, secured(1)		21		117
	Industrial development bonds at variable rates (0.08% at December 31, 2011)
	August 1, 2037, secured(1)		55		55
			5,018		4,259
Current portion of long-term debt			(60)		(68)
Unamortized discount on long-term debt			(9)		(10)
Unamortized premium on long-term debt			7		―
Total other Sempra Energy			4,956		4,181
Total Sempra Energy Consolidated		$	10,078	$	8,980
(1)	Callable long-term debt.

MATURITIES OF LONG-TERM DEBT(1)
(Dollars in millions)
								Total
						Other		Sempra
						Sempra		Energy
		SDG&E		SoCalGas		Energy		Consolidated
2012		$	10	$	250	$	60	$	320
2013			10		―		706		716
2014			140		250		881		1,271
2015			274		―		42		316
2016			10		8		768		786
Thereafter			3,451		805		2,545		6,801
Total		$	3,895	$	1,313	$	5,002	$	10,210
(1)	Excludes capital lease obligations and market value adjustments for interest rate swaps.

Various long-term obligations totaling $5.1 billion at Sempra Energy at December 31, 2011 are unsecured. This includes unsecured long-term obligations totaling $254 million at SDG&E and $13 million at SoCalGas.

CALLABLE LONG-TERM DEBT

At the option of Sempra Energy, SDG&E and SoCalGas, certain debt is callable subject to premiums at various dates:

CALLABLE LONG-TERM DEBT
(Dollars in millions)
							Total
					Other		Sempra
					Sempra		Energy
	SDG&E		SoCalGas		Energy		Consolidated
2012	$	221	$	―	$	132	$	353
2013		45		―		―		45
2014		124		―		202		326
2015		105		―		―		105
2016		―		8		―		8
after 2016		251		―		―		251
Total	$	746	$	8	$	334	$	1,088
Callable bonds subject to make-whole provisions	$	2,650	$	1,300	$	3,741	$	7,691

In addition, the OMEC LLC project financing loan discussed in Note 1, with $355 million of borrowings at December 31, 2011, may be prepaid at the borrowers’ option.

FIRST MORTGAGE BONDS

The California Utilities issue first mortgage bonds which are secured by a lien on utility plant. The California Utilities may issue additional first mortgage bonds upon compliance with the provisions of their bond agreements (indentures). These indentures require, among other things, the satisfaction of pro forma earnings-coverage tests on first mortgage bond interest and the availability of sufficient mortgaged property to support the additional bonds, after giving effect to prior bond redemptions. The most restrictive of these tests (the property test) would permit the issuance, subject to CPUC authorization, of an additional $3.3 billion of first mortgage bonds at SDG&E and $817 million at SoCalGas at December 31, 2011.

Mobile Gas also issues first mortgage bonds secured by utility plant.

In August 2011, SDG&E publicly offered and sold $350 million of 3-percent first mortgage bonds maturing in 2021. In November 2011, SDG&E publicly offered and sold $250 million of 3.95-percent first mortgage bonds maturing in 2041.

In September 2011, Mobile Gas privately placed $20 million of 4.14-percent first mortgage bonds and $42 million of 5-percent first mortgage bonds, maturing in 2021 and 2031, respectively.

INDUSTRIAL DEVELOPMENT BONDS

SDG&E

In June 2009, SDG&E remarketed $176 million of industrial development bonds at a fixed rate of 5.875 percent, maturing in 2034. The bonds were initially issued as insured, auction-rate securities, the proceeds of which were loaned to SDG&E, and are repaid with payments on SDG&E first mortgage bonds that have terms corresponding to those of the industrial development bonds that they secure. Prior to SDG&E’s remarketing of the remaining bonds in 2009, SDG&E had purchased $152 million of the bonds from Sempra Energy. SDG&E also has $161 million of industrial development bonds outstanding with a variable interest rate that resets on a weekly basis.

Sempra Natural Gas

To secure an approved exemption from sales and use tax, Sempra Natural Gas has incurred through December 31, 2011, $201 million ($84 million in 2011, $42 million in 2010, and $75 million in 2009) out of a maximum available $265 million of long-term debt related to the construction and equipping of its Mississippi Hub natural gas storage facility. After a redemption of $180 million in December 2011, the debt balance remaining at December 31, 2011, is $21 million. The debt is payable to the Mississippi Business Finance Corporation (MBFC), and we recorded bonds receivable from the MBFC for the same amount. Both the financing obligation and the bonds receivable have interest rates of 4.5 percent and are due on July 1, 2024.

OTHER LONG-TERM DEBT

In March 2011, Sempra Energy publicly offered and sold $500 million of 2-percent notes and $300 million of floating rate notes (1.22 percent as of December 31, 2011), both maturing in 2014. The floating rate notes bear interest at a rate equal to the three-month London interbank offered rate (LIBOR) plus 0.76 percent. The interest rate is reset quarterly.

Chilquinta Energía has outstanding Series A and Series B Chilean public bonds with maturity dates in 2014 and 2030, respectively, and stated interest rates of 2.75 percent and 4.25 percent, respectively. The bonds and related interest are denominated in Chilean Unidades de Fomento. The Chilean Unidad de Fomento is a unit of account used in Chile that is adjusted for inflation, and its value is quoted in Chilean Pesos. In 2009, Parent and Other purchased $58 million of the 2.75-percent bonds, which are eliminated in consolidation. Net of this elimination, as of December 31, 2011, the outstanding balance on these bonds was $226 million ($24 million of Series A and $202 million of Series B).

Luz del Sur has outstanding Peruvian corporate bonds, denominated in the local currency, with maturity dates ranging from 2012 through 2021 at fixed interest rates ranging from 5.72 percent to 7.91 percent. As of December 31, 2011, the outstanding balance on these bonds was $185 million. Additionally, Luz del Sur has outstanding bank loans with maturity dates ranging from 2012 through 2016 at interest rates ranging from 5.45 percent to 6.75 percent. As of December 31, 2011, the outstanding balance on the bank loans was $41 million.

DEBT OF EMPLOYEE STOCK OWNERSHIP PLAN (ESOP) AND TRUST (TRUST)

The ESOP covers substantially all U.S. based Sempra Energy employees, including those of SDG&E and SoCalGas. The Trust is used to fund part of the retirement savings plan described in Note 8. The bonds of the ESOP are payable by the Trust and mature in 2014. Because the bonds outstanding at December 31, 2011 are payable on demand, we have classified them as short-term.

The remaining $8 million of these bonds are being repriced weekly through maturity. ESOP debt was paid down by a total of $64 million during the last three years when 1 million shares of Sempra Energy common stock were released from the Trust in order to fund employer contributions to the Sempra Energy savings plan trust. Interest on the ESOP debt was a negligible amount in 2011, $2 million in 2010 and $3 million in 2009. Dividends used for debt service amounted to $1 million in 2011, $1 million in 2010 and $2 million in 2009.

INTEREST RATE SWAPS

We discuss our fair value interest rate swaps and interest rate swaps to hedge cash flows in Note 10.

NOTE 6. FACILITIES UNDER JOINT OWNERSHIP

San Onofre Nuclear Generating Station (SONGS) and the Southwest Powerlink transmission line are owned jointly by SDG&E with other utilities. SDG&E’s interests at December 31, 2011 were as follows:

				Southwest
(Dollars in millions)	SONGS			Powerlink
Percentage ownership		20	%		91	%
Utility plant in service	$	308		$	323
Accumulated depreciation and amortization		59			191
Construction work in progress		129			22

SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for financing its share of each project and participates in decisions concerning operations and capital expenditures.

SDG&E’s share of operating expenses is included in Sempra Energy’s and SDG&E’s Consolidated Statements of Operations.

SONGS DECOMMISSIONING

Objectives, work scope, and procedures for the dismantling and decontamination of SONGS’ three units must meet the requirements of the Nuclear Regulatory Commission (NRC), the Environmental Protection Agency (EPA), the U.S. Department of the Navy (the land owner), the CPUC and other regulatory bodies.

SDG&E’s asset retirement obligation related to decommissioning costs for the SONGS units was $524 million at December 31, 2011. 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 remaining work on Unit 1 will be completed when Units 2 and 3 are decommissioned. Southern California Edison Company (Edison), the operator of SONGS, updates decommissioning cost studies every three years. Rate recovery of decommissioning costs is allowed until the time that the costs are fully recovered and is subject to adjustment every three years based on the costs allowed by regulators. Collections are authorized to continue until 2022. The most recent cost study was approved by the CPUC in July 2010. SDG&E’s share of decommissioning costs under the approved study is approximately $768 million.

Unit 1 was permanently shut down in 1992, and physical decommissioning began in January 2000. Most structures, foundations and large components have been dismantled, removed and disposed of. Spent nuclear fuel has been removed from the Unit 1 Spent Fuel Pool and stored on-site in an independent spent fuel storage installation (ISFSI) licensed by the NRC. The decommissioning of Unit 1 remaining structures (subsurface and intake/discharge) will take place when Units 2 and 3 are decommissioned. The ISFSI will be decommissioned after a permanent storage facility becomes available and the U.S. Department of Energy (DOE) removes the spent fuel from the site. The Unit 1 reactor vessel is expected to remain on site until Units 2 and 3 are decommissioned.

SPENT NUCLEAR FUEL

SONGS owners are responsible for interim storage of spent nuclear fuel generated at SONGS until the DOE accepts it for final disposal. Spent nuclear fuel has been stored in the SONGS Units 1, 2 and 3 spent fuel pools and in the ISFSI, as follows:

§	Movement of all Unit 1 spent fuel to the ISFSI was completed in 2005.

§	Spent fuel for Unit 2 is being stored in both the Unit 2 spent fuel pool and the ISFSI.

§	Spent fuel for Unit 3 is being stored in both the Unit 3 spent fuel pool and the ISFSI.

A second ISFSI pad, completed in 2009, will provide sufficient storage capacity to allow for the continued operation of SONGS through 2022.

The amounts collected in rates for SONGS’ decommissioning are invested in externally managed trust funds. Amounts held by the trusts are invested in accordance with CPUC regulations. These trusts are shown on the Sempra Energy and SDG&E Consolidated Balance Sheets at fair value with the offsetting credits recorded in Regulatory Liabilities Arising from Removal Obligations.

The following table shows the fair values and gross unrealized gains and losses for the securities held in the trust funds.

NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
				Gross		Gross		Estimated
				Unrealized		Unrealized		Fair
		Cost		Gains		Losses		Value
As of December 31, 2011:
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies(1)		$	157	$	13	$	―	$	170
Municipal bonds(2)			72		5		―		77
Other securities(3)			76		3		(1)		78
Total debt securities			305		21		(1)		325
Equity securities			246		227		(5)		468
Cash and cash equivalents			11		―		―		11
Total		$	562	$	248	$	(6)	$	804

As of December 31, 2010:
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies		$	162	$	14	$	(2)	$	174
Municipal bonds			101		2		(3)		100
Other securities			22		3		―		25
Total debt securities			285		19		(5)		299
Equity securities			219		242		(1)		460
Cash and cash equivalents			10		―		―		10
Total		$	514	$	261	$	(6)	$	769
(1)	Maturity dates are 2012-2042
(2)	Maturity dates are 2012-2057
(3)	Maturity dates are 2012-2051

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

SALES OF SECURITIES
(Dollars in millions)
		Years ended December 31,
		2011		2010		2009
Proceeds from sales(1)		$	715	$	351	$	224
Gross realized gains			75		11		6
Gross realized losses			(52)		(11)		(33)
(1)	Excludes securities that are held to maturity.

The increase in sales in 2011 was predominantly due to a restructuring of investments within the trust to achieve a more broadly diversified asset mix. Within the fixed income portfolio, the allocation to U.S. Treasury debt-securities was reduced, while holdings of other fixed income securities, including corporate and municipal bonds, and investments in mortgage- and asset-backed securities, were increased. The international equity portfolio was restructured to invest in both developed and emerging market equity securities.

Net unrealized gains (losses) are included in Regulatory Liabilities Arising from Removal Obligations on the Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification.

Customer contribution amounts are determined by the CPUC using estimates of after-tax investment returns, decommissioning costs, and decommissioning cost escalation rates. Changes in investment returns and decommissioning costs may result in a change in future customer contributions.

We discuss the impact of asset retirement obligations in Note 1. We provide additional information about SONGS in Notes 14 and 15.

NOTE 7. INCOME TAXES

Reconciliation of net U.S. statutory federal income tax rates to the effective income tax rates is as follows:

RECONCILIATION OF FEDERAL INCOME TAX RATES TO EFFECTIVE INCOME TAX RATES

	Years ended December 31,
	2011		2010		2009
Sempra Energy Consolidated
U.S. federal statutory income tax rate	35	%	35	%	35	%
Utility depreciation	3		6		3
State income taxes, net of federal income tax benefit	2		―		3
Tax credits	(1)		(3)		(1)
Allowance for equity funds used during construction	(2)		(3)		(1)
Non-U.S. earnings taxed at lower statutory income tax rates	(8)		(12)		(5)
Adjustments to prior years’ tax issues	―		(3)		(2)
Utility repair allowance	(1)		(2)		(1)
Self-developed software expenditures	(3)		(5)		(3)
Mexican foreign exchange and inflation effects	(1)		2		1
Variable interest entities	―		1		(1)
Noncontrolling interests	―		―		1
Impact of change in income tax law	―		2		―
Impact of impairment of an equity method investment	―		(2)		―
Other, net	(1)		1		―
Effective income tax rate	23	%	17	%	29	%
SDG&E
U.S. federal statutory income tax rate	35	%	35	%	35	%
Depreciation	4		5		4
State income taxes, net of federal income tax benefit	5		4		4
Allowance for equity funds used during construction	(4)		(3)		(2)
Adjustments to prior years’ tax issues	―		(3)		(1)
Utility repair allowance	(1)		(2)		(1)
Self-developed software expenditures	(3)		(2)		(2)
Variable interest entity	(1)		1		(2)
Impact of change in income tax law	―		1		―
Other, net	(1)		(3)		(3)
Effective income tax rate	34	%	33	%	32	%
SoCalGas
U.S. federal statutory income tax rate	35	%	35	%	35	%
Depreciation	6		5		6
State income taxes, net of federal income tax benefit	4		4		4
Self-developed software expenditures	(7)		(6)		(6)
Allowance for equity funds used during construction	(2)		(1)		(1)
Impact of change in income tax law	―		3		―
Other, net	(3)		(2)		(4)
Effective income tax rate	33	%	38	%	34	%

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 taxes are not recorded to deferred income tax expense, but rather to a regulatory asset or liability. As a result, changes in the relative size of these items compared to pretax income, from period to period, can cause variations in the effective income tax rate. The following items are subject to flow-through treatment:

§	the equity portion of AFUDC

§	cost of removal of utility plant assets

§	self-developed software costs

§	depreciation on a certain portion of utility plant assets

The geographic components of Income Before Income Taxes and Equity Earnings of Certain Unconsolidated Subsidiaries at Sempra Energy are as follows:

	Years ended December 31,
(Dollars in millions)	2011		2010		2009
U.S.	$	1,011	$	448	$	1,007
Non-U.S.		712		339		469
Total	$	1,723	$	787	$	1,476

The components of income tax expense are as follows:

INCOME TAX EXPENSE
(Dollars in millions)
	Years ended December 31,
	2011		2010		2009
Sempra Energy Consolidated
Current:
U.S. Federal	$	76	$	69	$	39
U.S. State		(3)		(3)		40
Non-U.S.		149		30		48
Total		222		96		127
Deferred:
U.S. Federal		176		(18)		216
U.S. State		43		32		24
Non-U.S.		(45)		27		58
Total		174		41		298
Deferred investment tax credits		(2)		(4)		(3)
Total income tax expense	$	394	$	133	$	422
SDG&E
Current:
U.S. Federal	$	(59)	$	69	$	70
U.S. State		6		52		34
Total		(53)		121		104
Deferred:
U.S. Federal		253		75		75
U.S. State		36		(21)		(2)
Total		289		54		73
Deferred investment tax credits		1		(2)		―
Total income tax expense	$	237	$	173	$	177
SoCalGas
Current:
U.S. Federal	$	(6)	$	43	$	52
U.S. State		19		26		22
Total		13		69		74
Deferred:
U.S. Federal		128		108		67
U.S. State		5		2		6
Total		133		110		73
Deferred investment tax credits		(3)		(3)		(3)
Total income tax expense	$	143	$	176	$	144

We show the components of deferred income taxes at December 31 for Sempra Energy, SDG&E and SoCalGas in the tables below:

DEFERRED INCOME TAXES FOR SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
	December 31,
	2011		2010
Deferred income tax liabilities:
Differences in financial and tax bases of depreciable and amortizable assets	$	2,360	$	1,949
Regulatory balancing accounts		456		535
Unrealized revenue		13		23
Loss on reacquired debt		12		15
Property taxes		43		38
Difference in financial and tax bases of partnership interests		152		―
Other deferred income tax liabilities		30		72
Total deferred income tax liabilities		3,066		2,632
Deferred income tax assets:
Investment tax credits		22		34
Equity losses		16		3
Net operating losses		811		40
Compensation-related items		140		158
Postretirement benefits		361		467
Difference in financial and tax bases of partnership interests		―		83
Other deferred income tax assets		34		52
State income taxes		58		73
Bad debt allowance		8		10
Litigation and other accruals not yet deductible		5		304
Deferred income tax assets before valuation allowances		1,455		1,224
Less: valuation allowances		82		62
Total deferred income tax assets		1,373		1,162
Net deferred income tax liability	$	1,693	$	1,470
Our policy is to show deferred taxes of VIEs on a net basis, including valuation allowances. See table “Amounts Associated with Otay Mesa VIE” in Note 1 for further information on VIEs.

DEFERRED INCOME TAXES FOR SDG&E AND SOCALGAS
(Dollars in millions)
	SDG&E				SoCalGas
	December 31,				December 31,
	2011		2010		2011		2010
Deferred income tax liabilities:
Differences in financial and tax bases of
utility plant and other assets	$	1,152	$	982	$	632	$	483
Regulatory balancing accounts		230		230		236		316
Loss on reacquired debt		5		7		8		10
Property taxes		30		25		14		14
Other		19		17		1		(1)
Total deferred income tax liabilities		1,436		1,261		891		822
Deferred income tax assets:
Postretirement benefits		115		126		161		272
Investment tax credits		17		17		16		17
Compensation-related items		15		14		39		41
State income taxes		24		33		18		18
Litigation and other accruals not yet deductible		33		192		22		20
Hedging transaction		―		―		7		9
Other		3		7		8		10
Total deferred income tax assets		207		389		271		387
Net deferred income tax liability	$	1,229	$	872	$	620	$	435
Our policy is to show deferred taxes of VIEs on a net basis, including valuation allowances. See table “Amounts Associated with Otay Mesa VIE” in Note 1 for further information on VIEs.

The net deferred income tax liabilities are recorded on the Consolidated Balance Sheets at December 31 as follows:

NET DEFERRED INCOME TAX LIABILITY
(Dollars in millions)
	Sempra Energy
	Consolidated				SDG&E				SoCalGas
	2011		2010		2011		2010		2011		2010
Current (asset) liability	$	173	$	(75)	$	62	$	(129)	$	44	$	17
Noncurrent liability		1,520		1,545		1,167		1,001		576		418
Total	$	1,693	$	1,470	$	1,229	$	872	$	620	$	435

At December 31, 2011, Sempra Energy has recorded a valuation allowance against a portion of its total deferred income tax assets, as shown above in the “Deferred Income Taxes for Sempra Energy Consolidated” table. A valuation allowance is recorded when, based on more-likely-than-not criteria, negative evidence outweighs positive evidence with regard to our ability to realize a deferred tax asset in the future. Of the valuation allowances recorded to date, the negative evidence outweighs the positive evidence primarily due to cumulative pretax losses in various U.S. state and non-U.S. jurisdictions resulting in net operating losses (NOLs), as discussed below, that we currently do not believe will be realized. At both Sempra Energy and SDG&E, deferred income taxes for variable interest entities are shown on a net basis. Therefore, a valuation allowance of $116 million related to variable interest entities is not reflected in the tables above. Of Sempra Energy’s total valuation allowance of $82 million, $14 million is related to non-U.S. NOLs, $8 million to other future non-U.S. deductions, and $60 million to U.S. state NOLs. The total valuation allowance increased by $20 million during 2011 when compared to 2010, primarily due to the increase in the valuation allowance established for U.S. state NOLs. We believe that it is more likely than not that the remainder of the total deferred income tax asset is realizable.

At December 31, 2011, Sempra Energy’s non-U.S. subsidiaries had $52 million of unused NOLs available to utilize in the future to reduce Sempra Energy’s future non-U.S. income tax expense, which is in Denmark, Mexico, the Netherlands and Spain. The carryforward periods for our non-U.S. unused NOLs are as follows: $7 million does not expire and $45 million expires between 2012 and 2026. As of December 31, 2011, our Mexican subsidiaries have NOLs of $176 million, of which $163 million have been utilized on a consolidated level. These NOLs are subject to recapture between 2012 and 2016 if the Mexican subsidiary that generated them does not have sufficient taxable income itself to realize them within 5 years. These NOLs expire between 2016 and 2021. Sempra Energy’s U.S. subsidiaries had $768 million of unused U.S. state NOLs, primarily in Alabama, Connecticut, District of Columbia, Indiana, Louisiana, Minnesota, New Jersey, New York and Oklahoma. These U.S. state NOLs expire between 2012 and 2031. We have not recorded income tax benefits on a portion of Sempra Energy’s total NOLs because they were incurred in jurisdictions where we currently believe they will not be realized, as discussed above. Sempra Energy’s consolidated U.S. subsidiaries had $1.8 billion of unused U.S. federal consolidated NOLs and $798 million of unused California combined NOLs. We have recorded income tax benefits on these NOLs, in total, because they were incurred in jurisdictions where we currently believe they will be realized.

At December 31, 2011, Sempra Energy had not recognized a U.S. deferred income tax liability related to a $2.6 billion basis difference between its financial statement and tax investment amount in its non-U.S. subsidiaries. This basis difference consists of $2.6 billion of cumulative undistributed earnings that we expect to reinvest indefinitely outside of the U.S., which includes the $0.3 billion gain related to the remeasurement of equity method investments in Chilquinta Energía and Luz del Sur, as we discuss in Note 3. These cumulative undistributed earnings have previously been reinvested or will be reinvested in active non-U.S. operations, thus we do not intend to use these earnings as a source of funding for U.S. operations. It is not practical to determine the amount of U.S. income taxes that might be payable if the cumulative undistributed earnings were eventually distributed or the investments were sold. U.S. deferred income taxes would be recorded on $2.6 billion of the basis difference related to cumulative undistributed earnings if we no longer intend to indefinitely reinvest all, or a part, of the cumulative undistributed earnings.

Following is a summary of unrecognized income tax benefits:

SUMMARY OF UNRECOGNIZED INCOME TAX BENEFITS
(Dollars in millions)
	Sempra Energy
	Consolidated						SDG&E						SoCalGas
	2011		2010		2009		2011		2010		2009		2011		2010		2009
Total	$	72	$	97	$	94	$	7	$	5	$	14	$	―	$	8	$	11
Of the total, amounts related to tax
positions that, if recognized, in
future years, would:
decrease the effective tax rate	$	(72)	$	(76)	$	(76)	$	(7)	$	(5)	$	(13)	$	―	$	(1)	$	(1)
increase the effective tax rate		7		5		13		7		5		13		―		―		―

Following is a reconciliation of the changes in unrecognized income tax benefits for the years ended December 31:

RECONCILIATION OF UNRECOGNIZED INCOME TAX BENEFITS
(Dollars in millions)
	2011		2010		2009
Sempra Energy Consolidated:
Balance as of January 1	$	97	$	94	$	104
Increase in prior period tax positions		7		29		44
Decrease in prior period tax positions		(26)		(4)		(3)
Increase in current period tax positions		3		5		15
Settlements with taxing authorities		(9)		(9)		(54)
Expirations of statutes of limitations		―		(18)		(12)
Balance as of December 31	$	72	$	97	$	94
SDG&E:
Balance as of January 1	$	5	$	14	$	18
Increase in prior period tax positions		―		―		1
Decrease in prior period tax positions		―		(3)		―
Increase in current period tax positions		2		3		3
Settlements with taxing authorities		―		(9)		(8)
Balance as of December 31	$	7	$	5	$	14
SoCalGas:
Balance as of January 1	$	8	$	11	$	19
Increase in prior period tax positions		2		5		1
Settlements with taxing authorities		(10)		―		(1)
Expirations of statutes of limitations		―		(8)		(8)
Balance as of December 31	$	―	$	8	$	11

It is reasonably possible that within the next 12 months unrecognized income tax benefits could decrease due to the following:

POSSIBLE DECREASES IN UNRECOGNIZED INCOME TAX BENEFITS WITHIN 12 MONTHS
(Dollars in millions)
	At December 31,
	2011		2010		2009
Sempra Energy Consolidated:
Expiration of statutes of limitations on tax assessments	$	(7)	$	(6)	$	(7)
Potential resolution of audit issues with various
U.S. federal, state and local and non-U.S. taxing authorities		―		(35)		(24)
	$	(7)	$	(41)	$	(31)
SDG&E	$	―	$	―	$	―
SoCalGas:
Expiration of statutes of limitations on tax assessments	$	―	$	(5)	$	(6)
Potential resolution of audit issues with various
U.S. federal, state and local taxing authorities		―		―		(1)
	$	―	$	(5)	$	(7)

Amounts accrued for interest expense and penalties associated with unrecognized income tax benefits are included in income tax expense in the Consolidated Statements of Operations for the years ended December 31 as follows:

INTEREST EXPENSE AND PENALTIES ASSOCIATED WITH UNRECOGNIZED INCOME TAX BENEFITS
(Dollars in millions)
	Sempra Energy
	Consolidated						SDG&E						SoCalGas
	2011		2010		2009		2011		2010		2009		2011		2010		2009
Interest expense (benefit)	$	(3)	$	4	$	(16)	$	―	$	3	$	(4)	$	(1)	$	1	$	(3)
Penalties		(1)		―		3		―		―		―		―		―		1

Amounts accrued at December 31 on the Consolidated Balance Sheets for interest expense and penalties associated with unrecognized income tax benefits are as follows:

ACCRUED INTEREST EXPENSE AND PENALTIES ASSOCIATED WITH UNRECOGNIZED INCOME TAX BENEFITS
(Dollars in millions)
	Sempra Energy
	Consolidated				SDG&E				SoCalGas
	2011		2010		2011		2010		2011		2010
Interest expense (benefit)	$	3	$	6	$	1	$	1	$	1	$	2
Penalties		3		4		―		―		―		―

INCOME TAX AUDITS

Sempra Energy is subject to U.S. federal income tax as well as to income tax of multiple state and non-U.S. jurisdictions. We remain subject to examination for U.S. federal tax years after 2006. We are subject to examination by major state tax jurisdictions for tax years after 2005. Certain major non-U.S. income tax returns from 2002 through the present are open to examination.

In addition, we have filed state refund claims for tax years back to 1998, and PE has filed state refund claims for tax years back to 1993. The pre-2006 tax years are closed to new issues; therefore, no additional tax may be assessed by the taxing authorities for these years.

SDG&E and SoCalGas are subject to U.S. federal income tax as well as income tax of state jurisdictions. They remain subject to examination for U.S. federal years after 2006 and by major state tax jurisdictions for years after 2005.

NOTE 8. EMPLOYEE BENEFIT PLANS

We are required by applicable GAAP to:

§	recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status in the statement of financial position;

§	measure a plan’s assets and its obligations that determine its funded status as of the end of the fiscal year (with limited exceptions); and

§	recognize changes in the funded status of a defined benefit postretirement plan in the year in which the changes occur. Generally, those changes are reported in other comprehensive income and as a separate component of shareholders’ equity.

The information presented below covers the employee benefit plans of Sempra Energy and its principal subsidiaries, as detailed following.

Sempra Energy has funded and unfunded noncontributory defined benefit plans, including separate plans for SDG&E and SoCalGas, which collectively cover all domestic and certain foreign employees, and Sempra Energy’s board of directors. The plans generally provide defined benefits based on years of service and either final average or career salary.

Chilquinta Energía, which was acquired by Sempra Energy in 2011, has an unfunded contributory defined benefit plan covering all employees hired before October 1, 1981 and an unfunded noncontributory termination indemnity obligation covering all employees. The plans generally provide defined benefits to retirees based on date of hire, years of service and final average salary.

Sempra Energy also has other postretirement benefit plans (PBOP), including separate plans for SDG&E and SoCalGas, which collectively cover all domestic and certain foreign employees, and Sempra Energy’s board of directors. The life insurance plans are both contributory and noncontributory, and the health care plans are contributory. Participants’ contributions are adjusted annually. Other postretirement benefits include medical benefits for retirees’ spouses.

Chilquinta Energía also has two noncontributory postretirement benefit plans which cover substantially all employees – a health care plan and an energy subsidy plan that provides for reduced energy rates. The health care plan includes benefits for retirees’ spouses and dependents.

Pension and other postretirement benefits costs and obligations are dependent on assumptions used in calculating such amounts. These assumptions include

§	discount rates

§	expected return on plan assets

§	health-care cost trend rates

§	mortality rates

§	compensation increase rates

§	payout elections (lump sum or annuity)

We review these assumptions on an annual basis prior to the beginning of each year and update them as appropriate. We consider current market conditions, including interest rates, in making these assumptions. We use a December 31 measurement date for all of our plans.

In support of its Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans, Sempra Energy maintains dedicated assets, including investments in life insurance contracts, which totaled $478 million and $442 million at December 31, 2011 and 2010, respectively.

PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS

Benefit Plan Amendments Affecting 2011

Effective January 1, 2011, for certain postretirement health plans, the employer contribution was increased to maintain the grandfathered retiree plan status under the Patient Protection and Affordable Care Act (PPACA) discussed below. This increased the benefit obligation by approximately $4 million for Sempra Energy Consolidated, $2 million for SDG&E, and $1 million for SoCalGas.

Benefit Obligations and Assets

The following three tables provide a reconciliation of the changes in the plans’ projected benefit obligations and the fair value of assets during 2011 and 2010, and a statement of the funded status at December 31, 2011 and 2010:

PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
(Dollars in millions)
	Pension Benefits				Other Postretirement Benefits
Sempra Energy Consolidated	2011		2010		2011		2010
CHANGE IN PROJECTED BENEFIT OBLIGATION:
Net obligation at January 1	$	3,124	$	3,083	$	1,139	$	985
Service cost		83		83		31		26
Interest cost		168		167		65		57
Plan amendments		―		1		4		―
Impact of PPACA excise tax		―		―		―		31
Actuarial loss (gain)		224		―		(42)		81
Contributions from plan participants		―		―		15		13
Benefit payments		(177)		(210)		(59)		(56)
Acquisitions		20		―		5		―
Foreign currency adjustments		(2)		―		―		―
Settlements		(34)		―		―		―
Federal subsidy (Medicare Part D)		―		―		2		2
Net obligation at December 31		3,406		3,124		1,160		1,139

CHANGE IN PLAN ASSETS:
Fair value of plan assets at January 1		2,354		2,130		746		658
Actual return on plan assets		(23)		275		4		79
Employer contributions		212		159		72		52
Contributions from plan participants		―		―		15		13
Benefit payments		(177)		(210)		(59)		(56)
Settlements		(34)		―		―		―
Fair value of plan assets at December 31		2,332		2,354		778		746
Funded status at December 31	$	(1,074)	$	(770)	$	(382)	$	(393)
Net recorded liability at December 31	$	(1,074)	$	(770)	$	(382)	$	(393)

PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
(Dollars in millions)
	Pension Benefits				Other Postretirement Benefits
SDG&E	2011		2010		2011		2010
CHANGE IN PROJECTED BENEFIT OBLIGATION:
Net obligation at January 1	$	949	$	908	$	175	$	160
Service cost		28		27		7		6
Interest cost		49		47		10		9
Plan amendments		―		―		2		―
Actuarial loss (gain)		27		1		(5)		3
Settlements		(1)		―		―		―
Transfer of liability (to) from other plans		(19)		17		(2)		2
Contributions from plan participants		―		―		7		6
Benefit payments		(52)		(51)		(12)		(11)
Net obligation at December 31		981		949		182		175

CHANGE IN PLAN ASSETS:
Fair value of plan assets at January 1		713		615		99		81
Actual return on plan assets		(7)		79		(1)		7
Employer contributions		69		61		15		15
Transfer of assets (to) from other plans		(10)		9		(2)		1
Settlements		(1)		―		―		―
Contributions from plan participants		―		―		7		6
Benefit payments		(52)		(51)		(12)		(11)
Fair value of plan assets at December 31		712		713		106		99
Funded status at December 31	$	(269)	$	(236)	$	(76)	$	(76)
Net recorded liability at December 31	$	(269)	$	(236)	$	(76)	$	(76)

PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
(Dollars in millions)
	Pension Benefits				Other Postretirement Benefits
SoCalGas	2011		2010		2011		2010
CHANGE IN PROJECTED BENEFIT OBLIGATION:
Net obligation at January 1	$	1,786	$	1,764	$	920	$	780
Service cost		46		46		22		18
Interest cost		99		98		53		46
Plan amendments		―		―		1		―
Impact of PPACA excise tax		―		―		―		31
Actuarial loss (gain)		171		(3)		(46)		77
Contributions from plan participants		―		―		9		8
Benefit payments		(107)		(126)		(45)		(43)
Settlements		(4)		―		―		―
Transfer of liability from other plans		26		7		5		1
Federal subsidy (Medicare Part D)		―		―		2		2
Net obligation at December 31		2,017		1,786		921		920

CHANGE IN PLAN ASSETS:
Fair value of plan assets at January 1		1,456		1,332		632		562
Actual return on plan assets		(12)		171		4		70
Employer contributions		95		71		55		35
Transfer of assets from other plans		15		7		3		―
Settlements		(4)		―		―		―
Contributions from plan participants		―		―		9		8
Benefit payments		(107)		(125)		(45)		(43)
Fair value of plan assets at December 31		1,443		1,456		658		632
Funded status at December 31	$	(574)	$	(330)	$	(263)	$	(288)
Net recorded liability at December 31	$	(574)	$	(330)	$	(263)	$	(288)

The actuarial losses for pension plans in 2011 were primarily due to a decrease in the weighted average discount rate and the rate used to convert monthly annuity-type benefits to a lump sum benefit payment.

The actuarial gains for other postretirement plans in 2011 resulted from a decrease in assumed participation rates and claims costs and the impact of the adoption of the Employer Group Waiver Plan, partially offset by actuarial losses from a decrease in the weighted average discount rate. The Employer Group Waiver Plan is an alternative means of providing the existing pharmacy benefit.

The actuarial losses in 2010 for other postretirement plans were primarily due to higher medical premiums and higher health care trend rates for the SoCalGas other postretirement benefit plans.

Net Assets and Liabilities

The assets and liabilities of the pension and other postretirement benefit plans are affected by changing market conditions as well as when actual plan experience is different than assumed. Such events result in investment gains and losses, which we defer and recognize in pension and other postretirement benefit costs over a period of years. Sempra Energy uses the asset smoothing method for its pension and other postretirement plans, except for the SDG&E plans. This method develops an asset value that recognizes realized and unrealized investment gains and losses over a three-year period. This adjusted asset value, known as the market-related value of assets, is used in conjunction with an expected long-term rate of return to determine the expected return-on-assets component of net periodic cost. SoCalGas also uses the asset smoothing method.

The 10-percent corridor accounting method is used at Sempra Energy, SDG&E and SoCalGas. Under the corridor accounting method, if as of the beginning of a year, unrecognized net gain or loss exceeds 10 percent of the greater of the projected benefit obligation or the market-related value of plan assets, the excess is amortized over the average remaining service period of active participants. The asset smoothing and 10-percent corridor accounting methods help mitigate volatility of net periodic costs from year to year.

We recognize the overfunded or underfunded status of defined benefit pension and other postretirement plans as assets or liabilities, respectively; unrecognized changes in these assets and/or liabilities are normally recorded to other comprehensive income (loss) on the balance sheet. The California Utilities and Mobile Gas record regulatory assets and liabilities that offset the funded pension and other postretirement plans’ assets or liabilities, as these costs are expected to be recovered in future utility rates based on agreements with regulatory agencies.

The California Utilities record annual pension and other postretirement net periodic benefit costs equal to the contributions to their plans as authorized by the CPUC. The annual contributions to the pension plans are limited to a minimum required funding amount as determined by the Internal Revenue Service. The annual contributions to the other postretirement plans are equal to the lesser of the maximum tax deductible amount or the net periodic cost calculated in accordance with GAAP for pension and other postretirement benefit plans. Mobile Gas records annual pension and other postretirement net periodic benefit costs based on an estimate of the net periodic cost at the beginning of the year calculated in accordance with GAAP for pension and other postretirement benefit plans, as authorized by the Alabama Public Service Commission. Any differences between booked net periodic benefit cost and amounts contributed to the pension and other postretirement plans for the California Utilities are disclosed as regulatory adjustments in accordance with GAAP for regulated entities.

The net liability is included in the following captions on the Consolidated Balance Sheets at December 31:

	Pension Benefits				Other Postretirement Benefits
(Dollars in millions)	2011		2010		2011		2010
Sempra Energy Consolidated
Current liabilities	$	(31)	$	(57)	$	(2)	$	(1)
Noncurrent liabilities		(1,043)		(713)		(380)		(392)
Net recorded liability	$	(1,074)	$	(770)	$	(382)	$	(393)
SDG&E
Current liabilities	$	(3)	$	(3)	$	―	$	―
Noncurrent liabilities		(266)		(233)		(76)		(76)
Net recorded liability	$	(269)	$	(236)	$	(76)	$	(76)
SoCalGas
Current liabilities	$	(4)	$	(5)	$	―	$	―
Noncurrent liabilities		(570)		(325)		(263)		(288)
Net recorded liability	$	(574)	$	(330)	$	(263)	$	(288)

Amounts recorded in Accumulated Other Comprehensive Income (Loss) as of December 31, 2011 and 2010, net of income tax effects and amounts recorded as regulatory assets, are as follows:

AMOUNTS IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
	Pension Benefits				Other Postretirement Benefits
	2011		2010		2011		2010
Sempra Energy Consolidated
Net actuarial loss	$	(92)	$	(85)	$	(8)	$	(3)
Prior service credit		1		1		―		―
Total	$	(91)	$	(84)	$	(8)	$	(3)
SDG&E
Net actuarial loss	$	(11)	$	(11)
Prior service credit		1		1
Total	$	(10)	$	(10)
SoCalGas
Net actuarial loss	$	(6)	$	(5)
Prior service credit		1		1
Total	$	(5)	$	(4)

The accumulated benefit obligation for defined benefit pension plans at December 31, 2011 and 2010 was as follows:

	Sempra Energy Consolidated				SDG&E				SoCalGas
(Dollars in millions)	2011		2010		2011		2010		2011		2010
Accumulated benefit obligation	$	3,176	$	2,933	$	962	$	935	$	1,845	$	1,623

Sempra Energy has unfunded and funded pension plans. SDG&E and SoCalGas each have an unfunded and a funded pension plan. The following table shows the obligations of funded pension plans with benefit obligations in excess of plan assets as of December 31:

(Dollars in millions)	2011		2010
Sempra Energy Consolidated
Projected benefit obligation	$	3,150	$	2,880
Accumulated benefit obligation		2,958		2,702
Fair value of plan assets		2,332		2,354
SDG&E
Projected benefit obligation	$	944	$	917
Accumulated benefit obligation		928		906
Fair value of plan assets		712		713
SoCalGas
Projected benefit obligation	$	1,987	$	1,755
Accumulated benefit obligation		1,818		1,594
Fair value of plan assets		1,443		1,456

Net Periodic Benefit Cost, 2009-2011

The following three tables provide the components of net periodic benefit cost and amounts recognized in other comprehensive income for the years ended December 31:

NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME
(Dollars in millions)
	Pension Benefits						Other Postretirement Benefits
Sempra Energy Consolidated	2011		2010		2009		2011		2010		2009
Net Periodic Benefit Cost
Service cost	$	83	$	83	$	74	$	31	$	26	$	26
Interest cost		168		167		170		65		57		56
Expected return on assets		(144)		(143)		(139)		(48)		(46)		(45)
Amortization of:
Prior service cost (credit)		4		4		7		―		(1)		(1)
Actuarial loss		34		30		23		17		8		3
Regulatory adjustment		43		19		28		7		7		7
Settlement charge		13		―		14		―		―		―
Total net periodic benefit cost		201		160		177		72		51		46

Other Changes in Plan Assets and Benefit Obligations
Recognized in Other Comprehensive Income
Net loss (gain)		23		(12)		9		7		(1)		3
Amortization of prior service credit		―		―		―		―		1		1
Amortization of actuarial loss		(10)		(10)		(8)		―		―		―
Total recognized in other comprehensive income		13		(22)		1		7		―		4
Total recognized in net periodic benefit cost and other comprehensive income	$	214	$	138	$	178	$	79	$	51	$	50

NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME
(Dollars in millions)
	Pension Benefits						Other Postretirement Benefits
SDG&E	2011		2010		2009		2011		2010		2009
Net Periodic Benefit Cost
Service cost	$	28	$	27	$	23	$	7	$	6	$	5
Interest cost		49		47		48		10		9		9
Expected return on assets		(46)		(40)		(32)		(8)		(5)		(3)
Amortization of:
Prior service cost		1		1		4		4		4		4
Actuarial loss		9		12		16		―		―		―
Regulatory adjustment		31		13		2		2		2		2
Settlement charge		1		―		2		―		―		―
Total net periodic benefit cost		73		60		63		15		16		17

Other Changes in Plan Assets and Benefit Obligations
Recognized in Other Comprehensive Income
Net loss (gain)		1		2		(1)		―		―		―
Amortization of actuarial loss		(1)		(1)		(2)		―		―		―
Total recognized in other comprehensive income		―		1		(3)		―		―		―
Total recognized in net periodic benefit cost and other comprehensive income	$	73	$	61	$	60	$	15	$	16	$	17

NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME
(Dollars in millions)
	Pension Benefits						Other Postretirement Benefits
SoCalGas	2011		2010		2009		2011		2010		2009
Net Periodic Benefit Cost
Service cost	$	46	$	46	$	42	$	22	$	18	$	18
Interest cost		99		98		98		53		46		45
Expected return on assets		(85)		(90)		(94)		(40)		(40)		(41)
Amortization of:
Prior service cost (credit)		2		2		2		(4)		(4)		(4)
Actuarial loss		17		10		1		17		7		3
Settlement charge		1		―		1		―		―		―
Regulatory adjustment		12		6		28		5		5		6
Total net periodic benefit cost		92		72		78		53		32		27

Other Changes in Plan Assets and Benefit Obligations
Recognized in Other Comprehensive Income
Net loss		2		―		1		―		―		―
Amortization of actuarial loss		(1)		(1)		(1)		―		―		―
Total recognized in other comprehensive income		1		(1)		―		―		―		―
Total recognized in net periodic benefit cost and other comprehensive income	$	93	$	71	$	78	$	53	$	32	$	27

The estimated net loss for the pension plans that will be amortized from Accumulated Other Comprehensive Income (Loss) into net periodic benefit cost in 2012 is $10 million for Sempra Energy Consolidated and $1 million at both SDG&E and SoCalGas. Negligible amounts of prior service credit for the pension plans will be similarly amortized in 2012.

The estimated net loss for the PBOP plans that will be amortized from Accumulated Other Comprehensive Income (Loss) into net periodic cost benefit in 2012 is $1 million for Sempra Energy Consolidated.

Negligible amounts of estimated prior service credit for the other postretirement benefit plans will be amortized from Accumulated Other Comprehensive Income (Loss) into net periodic benefit cost in 2012 at Sempra Energy Consolidated.

Patient Protection and Affordable Care Act (PPACA) of 2010

The PPACA was enacted in March 2010. The key aspects of this legislation affecting Sempra Energy’s cost of providing retiree medical benefits are

§	Availability of subsidies from the Early Retiree Reinsurance Program (ERRP)

§	Mandatory coverage for adult children until age 26 beginning in 2011

§	Changes to the Prescription Drug Plan and Medicare Advantage programs beginning in 2011 and extending through 2020

§	Loss of the tax free status of the Retiree Drug Subsidy (RDS) beginning in 2013

§	Availability of coverage through health care exchanges beginning in 2014

§	Excise tax on high-cost plans, as defined in the legislation, beginning in 2018

In determining the projected benefit obligation for our other postretirement benefit plans, we took mandatory coverage for adult children, changes to the Prescription Drug Plan and Medicare Advantage programs, and availability of health care exchanges into consideration in the development of future claims costs and health care trend rates as of December 31, 2011 and 2010. Subsidies received through the ERRP will be reflected when received. We measured loss of the tax free status of RDS separately as described in the following section. We determined the impact of the excise tax provision separately for each of Sempra Energy’s plans, as explained below.

With the exception of SoCalGas’ represented employees and Mobile Gas, we provide most of our employer subsidy in the form of a defined dollar benefit. Once the premium exceeds our stated benefit level, the retirees pay the difference between the premium amount and the subsidy. Under this arrangement, our obligation doesn’t change with the excise tax, since by 2018 the premium both before and after inclusion of the excise tax will exceed our defined dollar benefit.

SoCalGas’ union retirees are provided a subsidy as a percentage of the premium. For those retirees, we estimated an increase in SoCalGas’ and Sempra Energy’s obligations as of December 31, 2010 for the excise tax. However, it is likely that some retirees will move to less expensive plans as a result of the excise tax and lower Sempra Energy’s composite plan cost. The net effect of the increase in obligation from the excise tax, partially offset by the lower composite plan cost, was estimated to be $31 million.

Mobile Gas offers only a pre-age 65 plan. As such, future retirees will only have a limited period when the excise tax may apply. All current retirees will no longer be eligible for benefits once the excise tax is effective in 2018.

Medicare Prescription Drug, Improvement and Modernization Act of 2003

The Medicare Prescription Drug, Improvement and Modernization Act of 2003 establishes a prescription drug benefit under Medicare (Medicare Part D) and a tax-exempt federal subsidy to sponsors of retiree health-care benefit plans that provide a benefit that actuarially is at least equivalent to Medicare Part D. We have determined that benefits provided to certain participants actuarially will be at least equivalent to Medicare Part D. Thus, we are entitled to a tax-exempt subsidy that reduced our accumulated postretirement benefit obligation under our plans at January 1, 2011 and reduced the net periodic cost for 2011 by the following amounts:

	Sempra Energy
(Dollars in millions)	Consolidated		SDG&E		SoCalGas
Net periodic benefit cost reduction	$	4	$	―	$	4

Assumptions for Pension and Other Postretirement Benefit Plans

Benefit Obligation and Net Periodic Benefit Cost

Except for the Chilquinta Energía plans, we develop the discount rate assumptions based on the results of a third party modeling tool that develops the discount rate by matching each plan’s expected cash flows to interest rates and expected maturity values of individually selected bonds in a hypothetical portfolio. The model controls the level of accumulated surplus that may result from the selection of bonds based solely on their premium yields by limiting the number of years to look back for selection to 3 years for pre-30-year and 6 years for post-30-year benefit payments. Additionally, the model ensures that an adequate number of bonds are selected in the portfolio by limiting the amount of the plan’s benefit payments that can be met by a single bond to 7.5 percent.

We selected individual bonds from a universe of Bloomberg AA-rated bonds which:

§	have an outstanding issue of at least $50 million;

§	are non-callable (or callable with make whole provisions);

§	exclude collateralized bonds; and

§	exclude the top and bottom 10 percent of yields to avoid relying on bonds which might be mispriced or misgraded.

This selection methodology also mitigates the impact of market volatility on the portfolio by excluding bonds with the following characteristics:

§	The issuer is on review for downgrade by a major rating agency if the downgrade would eliminate the issuer from the portfolio.

§	Recent events have caused significant price volatility to which rating agencies have not reacted.

§	Lack of liquidity is causing price quotes to vary significantly from broker to broker.

We believe that this bond selection approach provides the best estimate of discount rates to estimate settlement values for our plans’ benefit obligations as required by the applicable GAAP.

We develop the discount rate assumptions for the plans at Chilquinta Energía based on 10-year Chilean government bond yields and the expected local long-term rate of inflation. This method for developing the discount rate is required when there is no deep market for high quality corporate bonds.

Long-term return on assets is based on the weighted-average of the plans’ investment allocation as of the measurement date and the expected returns for those asset types.

The significant assumptions affecting benefit obligation and net periodic benefit cost are as follows:

WEIGHTED-AVERAGE ASSUMPTIONS

		Pension Benefits				Other Postretirement Benefits
		2011		2010		2011		2010
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE
BENEFIT OBLIGATION AS OF DECEMBER 31:
Discount rate		4.95	%	5.61	%	5.11	%	5.77	%
Rate of compensation increase		4.50	%	4.50	%	(1)		(1)

WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET
PERIODIC BENEFIT COST FOR YEARS ENDED DECEMBER 31:
Sempra Energy Consolidated
Discount rate		(2)		(3)		(4)		(5)
Expected return on plan assets		7.00	%	7.00	%	6.25	%	6.22	%
Rate of compensation increase		(6)		(6)		(1)		(1)
SDG&E
Discount rate		(7)		5.40	%	5.05	%	5.75	%
Expected return on plan assets		7.00	%	7.00	%	6.69	%	6.49	%
Rate of compensation increase		(8)		(8)		N/A		N/A
SoCalGas
Discount rate		(9)		5.75	%	5.15	%	5.90	%
Expected return on plan assets		7.00	%	7.00	%	7.00	%	7.00	%
Rate of compensation increase		(6)		(6)		(1)		(1)
(1)	4.50% and 4.00% as of December 31, 2011 and 2010, respectively, for the life insurance and Health Reimbursement Arrangement benefits for SoCalGas’ represented employees. No other PBOP benefits are compensation-based.
(2)	In addition to rates for SDG&E and SoCalGas plans, 5.14% for Mobile Gas pension plan, 4.40% for Directors’ plan, 4.70% for other unfunded plans, and 4.90% for Sempra Energy funded plan.
(3)	In addition to rates for SDG&E and SoCalGas plans, 5.95% for Mobile Gas pension plans, 4.85% for Directors’ plan, 5.45% for other unfunded plans, and 5.55% for Sempra Energy funded plan.
(4)	In addition to rates for SDG&E and SoCalGas plans, 4.10% for the Executive Life Plan, 4.80% for Mobile Gas, and 4.65% for Sempra Energy.
(5)	In addition to rates for SDG&E and SoCalGas plans, 4.60% for the Executive Life Plan, 5.70% for Mobile Gas, and 5.40% for Sempra Energy.
(6)	4.50% for the unfunded pension plans. 3.50% to 5.00% for the funded pension plan for SoCalGas’ represented participants and 3.50% to 8.50% for all the other funded pension plans’ participants using an age-based formula.
(7)	4.70% for the unfunded pension plan. 4.80% for the funded pension plan.
(8)	4.50% for the unfunded pension plan. 3.50% to 8.50% for the funded pension plan using an age-based formula.
(9)	4.70% for the unfunded pension plan. 5.05% for the funded pension plan.

Health Care Cost Trend Rates

Assumed health-care cost trend rates have a significant effect on the amounts that we report for the health care plan costs. Following are the health-care cost trend rates applicable to our postretirement benefit plans:

	2011		2010
ASSUMED HEALTH CARE COST TREND RATES AT DECEMBER 31:
Health-care cost trend rate	10.00	%	8.50	%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	5.00	%	5.50	%
Year that the rate reaches the ultimate trend	2019		2016

A one-percent change in assumed health care cost trend rates would have the following effects:

	Sempra Energy
	Consolidated				SDG&E				SoCalGas
	1%		1%		1%		1%		1%		1%
(Dollars in millions)	Increase		Decrease		Increase		Decrease		Increase		Decrease
Effect on total of service and interest
cost components of net periodic
postretirement health care benefit cost	$	13	$	(10)	$	1	$	(1)	$	12	$	(9)
Effect on the health care component of the
accumulated other postretirement
benefit obligations	$	116	$	(95)	$	9	$	(8)	$	105	$	(85)

Plan Assets

Investment Allocation Strategy for Sempra Energy’s Pension Master Trust

Sempra Energy’s pension master trust holds the investments for the pension and other postretirement benefit plans. We maintain additional trusts as we discuss below for certain of the California Utilities’ other postretirement plans. Other than index weight, the trusts do not invest in securities of Sempra Energy.

The current asset allocation objective for the pension master trust is to protect the funded status of the plans while generating sufficient returns to cover future benefit payments and accruals. We assess the portfolio performance by comparing actual returns with relevant benchmarks, such as the Morgan Stanley Capital International (MSCI) US Investable Index, the MSCI Pacific Rim and Europe Indices, the MSCI Emerging Markets Index, and the Barclays Aggregate and Long Government Credit Indices.

Primarily passive investment strategies were used for both the equity and fixed income portions of the asset allocation in 2010, and active management was added in 2011 to achieve risk and return exposures consistent with these indices. The fixed income asset allocation consists of some longer-duration fixed income securities in order to reduce plan exposure to interest rate variation. The foreign equity components provide a growth element, diversification and exposure to different currencies and economies.

The asset allocation of the plans is reviewed by our Pension and Benefits Investment Committee (the Committee) on a regular basis. When evaluating its strategic asset allocation, the Committee considers many variables, including:

§	long-term cost

§	variability and level of contributions

§	funded status

§	a range of expected outcomes over varying confidence levels

We maintain allocations at strategic levels with reasonable bands of variance. When asset class exposure reaches a minimum or maximum level, we generally rebalance the portfolio back to target allocations, unless the Committee determines otherwise.

Rate of Return Assumption

For all plans except the SDG&E postretirement health plans, we base the long-term rate of return assumption on the asset-weighted-average of the expected return for each asset class. We develop the expected returns from examining periods of historical returns and expectations for future returns from several investment and actuarial consultants. Specifically, we reached a 7.0 percent return expectation by assuming a 4.5 percent yield/return on a risk-free bond portfolio (treasury securities), adding a 50 basis point risk premium for our investment grade bond portfolio and another 300 basis point risk premium for equity securities. A 65 percent equity/35 percent fixed income mix results in a total portfolio return expectation of approximately 7.0 percent.

The expected rate of return for the SDG&E postretirement health plan assets is the weighted average of the assumed rate of return for those plan assets in the pension master trust and the Voluntary Employee Beneficiary Association (VEBA) trust for the collectively bargained plan developed using the methodology described above, and the rate of return for the assets of the non-collectively bargained plans described below. The rate of return for the assets of the non-collectively bargained plan is based on the weighted average after-tax expected return of the portfolio’s target asset allocation of 35 percent equity/65 percent fixed income. The fixed-income portfolio is invested in tax-exempt municipal bond securities, while the equity portfolio is invested 25 percent Standard & Poor’s (S&P) 500 index/5 percent MSCI Index for equity market performance in Europe, Australasia and Far East (MSCI EAFE index).

Concentration of Risk

Plan assets are fully diversified across global equity and bond markets, and other than what is indicated by the target asset allocations, contain no concentration of risk in any one economic, industry, maturity, or geographic sector.

Investment Strategy for SoCalGas’ Other Postretirement Benefit Plans

SoCalGas’ other postretirement benefit plans are funded by cash contributions from SoCalGas and current retirees. The assets of these plans are placed in the pension master trust and other VEBA trusts, as we detail below. The assets in the VEBA trusts are invested at identical allocations to the pension master trust, 65 percent equities/35 percent fixed income, using primarily index funds. This allocation has been formulated to best suit the long-term nature of the obligations.

Investment Strategy for SDG&E’s Postretirement Health Plans

SDG&E’s postretirement health plans are funded by cash contributions from SDG&E and current retirees. The assets are placed in the pension master trust and a VEBA trust, as we detail below. Assets in the pension master trust are invested at the 70 percent equity/30 percent fixed income mix using index funds. Assets in the VEBA trust for non-collectively bargained post retirement health and welfare benefit plans are taxable and therefore have a different asset allocation strategy. These assets are invested with a target asset allocation of 30 percent equity/70 percent fixed income, with a large portion of the bond portfolio placed in actively managed tax-exempt municipal bonds. The equity portfolio is indexed.

Fair Value of Pension and Other Postretirement Benefit Plan Assets

We classify the investments in Sempra Energy’s pension master trust and the trusts for the California Utilities’ other postretirement benefit plans into:

§	Level 1, for securities valued using quoted prices from active markets for identical assets;

§	Level 2, for securities not traded on an active market but for which observable market inputs are readily available; and

§	Level 3, for securities and investments valued based on significant inputs that are generally less observable from objective sources.

We provide more discussion of fair value measurements in Notes 1, 2 and 11. The following tables set forth by level within the fair value hierarchy a summary of the investments in our pension and other postretirement benefit plan trusts measured at fair value on a recurring basis.

The fair values of our pension plan assets by asset category are as follows:

FAIR VALUE MEASUREMENTS — SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
		At fair value as of December 31, 2011
PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
SDG&E (see table below)		$	466	$	244	$	7	$	717
SoCalGas (see table below)			919		484		15		1,418
Other Sempra Energy
Equity securities:
Domestic large-cap(1)			50		―		―		50
Domestic mid-cap(1)			10		―		―		10
Domestic small-cap(1)			12		―		―		12
Foreign large-cap			32		―		―		32
Foreign mid-cap			7		―		―		7
Foreign small-cap			6		―		―		6
Foreign preferred small-cap			1		―		―		1
Registered investment companies			1		―		―		1
Fixed income securities:
Domestic municipal bonds			―		2		―		2
Foreign government bonds			―		5		―		5
Domestic corporate bonds(2)			―		36		―		36
Foreign corporate bonds			―		12		―		12
Common/collective trusts(3)			―		6		―		6
Other types of investments:
Private equity funds(4) (stated at net asset value)			1		―		2		3
Total other Sempra Energy(5)			120		61		2		183
Total Sempra Energy Consolidated(6)		$	1,505	$	789	$	24	$	2,318

		At fair value as of December 31, 2010
PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
SDG&E (see table below)		$	450	$	245	$	8	$	703
SoCalGas (see table below)			924		501		17		1,442
Other Sempra Energy
Equity securities:
Domestic large-cap(1)			54		―		―		54
Domestic mid-cap(1)			11		―		―		11
Domestic small-cap(1)			12		―		―		12
Foreign emerging market funds			―		13		―		13
Foreign large-cap			31		―		―		31
Foreign mid-cap			8		―		―		8
Foreign small-cap			5		―		―		5
Fixed income securities:
U.S. Treasury securities			5		―		―		5
Other U.S. government securities			―		9		―		9
Domestic municipal bonds			―		2		―		2
Foreign government bonds			―		2		―		2
Domestic corporate bonds(2)			―		31		―		31
Foreign corporate bonds			―		9		―		9
Common/collective trusts(3)			―		3		―		3
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		2		2
Total other Sempra Energy(7)			126		69		2		197
Total Sempra Energy Consolidated(6)		$	1,500	$	815	$	27	$	2,342
(1)	Investments in common stock of domestic corporations stratified according to the MSCI 2500 index.
(2)	Investment-grade bonds of U.S. issuers from diverse industries.
(3)	Investments in common/collective trusts held in Sempra Energy’s Pension Master Trust.
(4)	Investments in venture capital and real estate funds.
(5)	Excludes cash and cash equivalents of $1 million and transfers payable to other plans of $7 million.
(6)	Excludes cash and cash equivalents of $14 million and $12 million at December 31, 2011 and 2010, respectively.
(7)	Excludes transfers payable to other plans of $12 million.

FAIR VALUE MEASUREMENTS — SDG&E
(Dollars in millions)
		At fair value as of December 31, 2011
PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic large-cap(1)		$	199	$	―	$	―	$	199
Domestic mid-cap(1)			39		―		―		39
Domestic small-cap(1)			45		―		―		45
Foreign large-cap			125		―		―		125
Foreign mid-cap			31		―		―		31
Foreign small-cap			22		―		―		22
Foreign preferred large-cap			1		―		―		1
Registered investment companies			4		―		―		4
Fixed income securities:
Domestic municipal bonds			―		9		―		9
Foreign government bonds			―		25		―		25
Domestic corporate bonds(2)			―		139		―		139
Foreign corporate bonds			―		48		―		48
Common/collective trusts(3)			―		23		―		23
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		7		7
Total investment assets(5)		$	466	$	244	$	7	$	717

		At fair value as of December 31, 2010
PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic large-cap(1)		$	198	$	―	$	―	$	198
Domestic mid-cap(1)			39		―		―		39
Domestic small-cap(1)			42		―		―		42
Foreign emerging market funds			―		46		―		46
Foreign large-cap			108		―		―		108
Foreign mid-cap			25		―		―		25
Foreign small-cap			19		―		―		19
Foreign preferred large-cap			1		―		―		1
Fixed income securities:
U.S. Treasury securities			18		―		―		18
Other U.S. government securities			―		32		―		32
Domestic municipal bonds			―		8		―		8
Foreign government bonds			―		9		―		9
Domestic corporate bonds(2)			―		111		―		111
Foreign corporate bonds			―		33		―		33
Common/collective trusts(3)			―		6		―		6
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		8		8
Total investment assets(6)		$	450	$	245	$	8	$	703
(1)	Investments in common stock of domestic corporations stratified according to the MSCI 2500 index.
(2)	Investment-grade bonds of U.S. issuers from diverse industries.
(3)	Investments in common/collective trusts held in Sempra Energy’s Pension Master Trust.
(4)	Investments in venture capital and real estate funds.
(5)	Excludes cash and cash equivalents of $4 million and $9 million of transfers payable to other plans.
(6)	Excludes cash and cash equivalents of $4 million and transfers receivable from other plans of $6 million.

FAIR VALUE MEASUREMENTS — SOCALGAS
(Dollars in millions)
		At fair value as of December 31, 2011
PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic large-cap(1)		$	393	$	―	$	―	$	393
Domestic mid-cap(1)			76		―		―		76
Domestic small-cap(1)			89		―		―		89
Foreign large-cap			247		―		―		247
Foreign mid-cap			61		―		―		61
Foreign small-cap			43		―		―		43
Foreign preferred large-cap			1		―		―		1
Registered investment companies			8		―		―		8
Fixed income securities:
Domestic municipal bonds			―		18		―		18
Foreign government bonds			―		49		―		49
Domestic corporate bonds(2)			―		275		―		275
Foreign corporate bonds			―		96		―		96
Common/collective trusts(3)			―		46		―		46
Other types of investments:
Private equity funds(4) (stated at net asset value)			1		―		15		16
Total investment assets(5)		$	919	$	484	$	15	$	1,418

		At fair value as of December 31, 2010
PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic large-cap(1)		$	409	$	―	$	―	$	409
Domestic mid-cap(1)			80		―		―		80
Domestic small-cap(1)			86		―		―		86
Foreign emerging market funds			―		95		―		95
Foreign large-cap			221		―		―		221
Foreign mid-cap			52		―		―		52
Foreign small-cap			39		―		―		39
Foreign preferred large-cap			1		―		―		1
Fixed income securities:
U.S. Treasury securities			36		―		―		36
Other U.S. government securities			―		65		―		65
Domestic municipal bonds			―		16		―		16
Foreign government bonds			―		18		―		18
Domestic corporate bonds(2)			―		227		―		227
Foreign corporate bonds			―		67		―		67
Common/collective trusts(3)			―		13		―		13
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		17		17
Total investment assets(6)		$	924	$	501	$	17	$	1,442
(1)	Investments in common stock of domestic corporations stratified according to the MSCI 2500 index.
(2)	Investment-grade bonds of U.S. issuers from diverse industries.
(3)	Investments in common/collective trusts held in Sempra Energy’s Pension Master Trust.
(4)	Investments in venture capital and real estate funds.
(5)	Excludes cash and cash equivalents of $9 million and transfers receivable from other plans of $16 million.
(6)	Excludes cash and cash equivalents of $8 million and transfers receivable from other plans of $6 million.

The fair values by asset category of the postretirement benefit plan assets held in the pension master trust and in the additional trusts for SoCalGas’ postretirement benefit plans and SDG&E’s postretirement benefit plans (PBOP plan trusts) are as follows:

FAIR VALUE MEASUREMENTS — SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
		At fair value as of December 31, 2011
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
SDG&E (see table below)		$	47	$	24	$	1	$	72
SoCalGas (see table below)			176		390		3		569
Other Sempra Energy
Equity securities:
Domestic large-cap(1)			4		―		―		4
Domestic mid-cap(1)			1		―		―		1
Domestic small-cap(1)			1		―		―		1
Foreign large-cap			2		―		―		2
Foreign small-cap			1		―		―		1
Fixed income securities:
Domestic corporate bonds(2)			―		4		―		4
Foreign government bonds			―		1		―		1
Foreign corporate bonds			―		1		―		1
Total other Sempra Energy(3)			9		6		―		15
Total Sempra Energy Consolidated(4)		$	232	$	420	$	4	$	656

		At fair value as of December 31, 2010
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
SDG&E (see table below)		$	45	$	24	$	1	$	70
SoCalGas (see table below)			184		395		3		582
Other Sempra Energy
Equity securities:
Domestic large-cap(1)			3		―		―		3
Domestic mid-cap(1)			1		―		―		1
Domestic small-cap(1)			1		―		―		1
Foreign large-cap			2		―		―		2
Foreign mid-cap			1		―		―		1
Foreign small-cap			1		―		―		1
Fixed income securities:
U.S. Treasury securities			1		―		―		1
Domestic corporate bonds(2)			―		3		―		3
Total other Sempra Energy(5)			10		3		―		13
Total Sempra Energy Consolidated(6)		$	239	$	422	$	4	$	665
(1)	Investments in common stock of domestic corporations stratified according to the MSCI 2500 index.
(2)	Investment-grade bonds of U.S. issuers from diverse industries.
(3)	Excludes transfers payable to other plans of $1 million.
(4)	Excludes cash and cash equivalents of $122 million, $86 million and $36 million of which is held in SoCalGas and SDG&E
	PBOP plan trusts, respectively.
(5)	Excludes cash and cash equivalents of $2 million.
(6)	Excludes cash and cash equivalents of $81 million, $50 million and $29 million of which is held in SoCalGas and SDG&E
	PBOP plan trusts, respectively.

FAIR VALUE MEASUREMENTS — SDG&E
(Dollars in millions)
		At fair value as of December 31, 2011
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic large-cap(1)		$	17	$	―	$	―	$	17
Domestic mid-cap(1)			3		―		―		3
Domestic small-cap(1)			4		―		―		4
Foreign large-cap			11		―		―		11
Foreign mid-cap			3		―		―		3
Foreign small-cap			2		―		―		2
Registered investment company			7		―		―		7
Fixed income securities:
Domestic municipal bonds(2)			―		4		―		4
Domestic corporate bonds(3)			―		12		―		12
Foreign government bonds			―		2		―		2
Foreign corporate bonds			―		4		―		4
Common/collective trusts(4)			―		2		―		2
Other types of investments:
Private equity funds(5) (stated at net asset value)			―		―		1		1
Total investment assets(6)		$	47	$	24	$	1	$	72

		At fair value as of December 31, 2010
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic large-cap(1)		$	16	$	―	$	―	$	16
Domestic mid-cap(1)			3		―		―		3
Domestic small-cap(1)			3		―		―		3
Foreign emerging market funds			―		4		―		4
Foreign large-cap			8		―		―		8
Foreign mid-cap			2		―		―		2
Foreign small-cap			1		―		―		1
Registered investment company			11		―		―		11
Fixed income securities:
U.S. Treasury securities			1		―		―		1
Other U.S. government securities			―		2		―		2
Foreign government bonds			―		1		―		1
Domestic municipal bonds(2)			―		6		―		6
Domestic corporate bonds(3)			―		9		―		9
Foreign corporate bonds			―		2		―		2
Other types of investments:
Private equity funds(5) (stated at net asset value)			―		―		1		1
Total investment assets(7)		$	45	$	24	$	1	$	70
(1)	Investments in common stock of domestic corporations stratified according to the MSCI 2500 index.
(2)	Bonds of California municipalities held in SDG&E PBOP plan trusts.
(3)	Investment-grade bonds of U.S. issuers from diverse industries.
(4)	Investment in common/collective trusts held in PBOP plan VEBA trusts.
(5)	Investments in venture capital and real estate funds.
(6)	Excludes cash and cash equivalents of $36 million, all of which is held in SDG&E PBOP plan trusts, and transfers payable to other plans of $2 million.
(7)	Excludes cash and cash equivalents of $29 million, all of which is held in SDG&E PBOP plan trusts.

FAIR VALUE MEASUREMENTS — SOCALGAS
(Dollars in millions)
		At fair value as of December 31, 2011
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic large-cap(1)		$	75	$	―	$	―	$	75
Domestic mid-cap(1)			15		―		―		15
Domestic small-cap(1)			17		―		―		17
Foreign large-cap			47		―		―		47
Foreign mid-cap			12		―		―		12
Foreign small-cap			8		―		―		8
Registered investment company			2		―		―		2
Fixed income securities:
Domestic municipal bonds			―		3		―		3
Foreign government bonds			―		9		―		9
Domestic corporate bonds(2)			―		52		―		52
Foreign corporate bonds			―		18		―		18
Common/collective trusts(3)			―		308		―		308
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		3		3
Total investment assets(5)		$	176	$	390	$	3	$	569

		At fair value as of December 31, 2010
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic large-cap(1)		$	82	$	―	$	―	$	82
Domestic mid-cap(1)			16		―		―		16
Domestic small-cap(1)			17		―		―		17
Foreign emerging market funds			―		19		―		19
Broad market fund(6)			―		220		―		220
Foreign large-cap			44		―		―		44
Foreign mid-cap			10		―		―		10
Foreign small-cap			8		―		―		8
Fixed income securities:
U.S. Treasury securities			7		―		―		7
Other U.S. government securities			―		14		―		14
Domestic municipal bonds			―		3		―		3
Foreign government bonds			―		3		―		3
Domestic corporate bonds(2)			―		45		―		45
Foreign corporate bonds			―		14		―		14
Common/collective trusts(3)			―		77		―		77
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		3		3
Total investment assets(7)		$	184	$	395	$	3	$	582
(1)	Investments in common stock of domestic corporations stratified according to the MSCI 2500 index.
(2)	Investment-grade bonds of U.S. issuers from diverse industries.
(3)	Investments in common/collective trusts held in PBOP plan VEBA trusts.
(4)	Investments in venture capital and real estate funds.
(5)	Excludes cash and cash equivalents of $86 million, all of which is held in SoCalGas PBOP plan trusts, and transfers receivable from other plans of $3 million.
(6)	A passively managed broad market fund held in SoCalGas PBOP plan trusts.
(7)	Excludes cash and cash equivalents of $50 million, all of which is held in SoCalGas PBOP plan trusts.

The investments of the pension master trust allocated to the pension and postretirement benefit plans classified as Level 3 are private equity funds and represent a percentage of each plan’s total allocated assets as follows at December 31:

	Private Equity Funds
	2011				2010
(Dollars in millions)	SDG&E	SoCalGas	All Other	Sempra Energy Consolidated	SDG&E	SoCalGas	All Other	Sempra Energy Consolidated
PENSION PLANS
Total Level 3 investment assets	$7	$15	$2	$24	$8	$17	$2	$27
Percentage of total investment assets	1%	1%	-%	1%	1%	1%	-%	1%
OTHER POSTRETIREMENT BENEFIT PLANS
Total Level 3 investment assets	$1	$3	$-	$4	$1	$3	$-	$4
Percentage of total investment assets	1%	-%	-%	1%	1%	-%	-%	1%

The following table provides a reconciliation of changes in the fair value of investments classified as Level 3:

LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Private Equity Funds
		SDG&E		SoCalGas		All Other		Sempra Energy Consolidated
PENSION PLANS
Balance as of January 1, 2010	$	9	$	19	$	2	$	30
Actual returns on plan assets		―		1		―		1
Purchases		―		1		―		1
Sales		(1)		(4)		―		(5)
Balance as of December 31, 2010		8		17		2		27
Realized gains		1		1		―		2
Purchases		―		1		―		1
Sales		(2)		(4)		―		(6)
Balance as of December 31, 2011	$	7	$	15	$	2	$	24
OTHER POSTRETIREMENT BENEFIT PLANS
Balance as of January 1, 2010	$	1	$	4	$	―	$	5
Sales		―		(1)		―		(1)
Balance as of December 31, 2010 and 2011	$	1	$	3	$	―	$	4

Valuation Techniques Used to Determine Fair Value

The following descriptions of the valuation methods and assumptions used to estimate the fair values of investments apply to investments held directly by the plans and those held as underlying investments of the master trust:

Equity Securities — Equity securities are valued using quoted prices listed on nationally recognized securities exchanges.

Fixed Income Securities — Certain fixed income securities are valued at the closing price reported in the active market in which the security is traded. Other fixed income securities are valued based on yields currently available on comparable securities of issuers with similar credit ratings. When quoted prices are not available for identical or similar securities, the security is valued under a discounted cash flows approach that maximizes observable inputs, such as current yields of similar instruments, but includes adjustments for certain risks that may not be observable, such as credit and liquidity risks.

Common/Collective Trusts — Investments in common/collective trust funds are valued based on the redemption price of units owned, which is based on the current fair value of the fund’s underlying assets.

Private Equity Funds — Investments in private equity funds do not trade in active markets. Fair value is determined by the fund managers, based upon their review of the underlying investments as well as their utilization of discounted cash flows and other valuation models.

Real Estate — Real estate investments are valued on the basis of a discounted cash flow approach, which includes the future rental receipts, expenses, and residual values for the highest and best use of the real estate from a market participant view as rental property.

The methods described are intended to produce a fair value calculation that is indicative of net realizable value or reflective of future fair values. However, while management believes the valuation methods are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date.

Derivative Financial Instruments

In accordance with the Sempra Energy pension investment guidelines, derivative financial instruments are used by the pension master trust’s equity and fixed income portfolio investment managers. Futures and foreign currency exchange contracts are used primarily to rebalance the fixed income/equity allocation of the pension master trust’s portfolio and to hedge all or a portion of the currency risk component of the foreign equity investments. Currency hedge positions are not permitted to exceed the level of underlying foreign security exposure in the pension master trust’s related assets. Some of the fixed income investment managers are permitted to use certain specified types of derivative instruments as part of their respective strategies. These strategies include the use of futures and options as substitutes for certain types of fixed income securities. During 2011 and 2010, the pension master trust owned shares in funds that held futures contracts and foreign currency forward contracts. In 2011 and 2010, such funds in which the pension master trust owned shares were the S&P 1500 Index and the Foreign Equity Index managed by Barclay’s Global Investors. As these futures contracts are not held directly by the pension master trust, they are not included in the following discussion.

At December 31, 2011 and 2010, the pension master trust did not directly hold any futures or currency forward contracts. As we discuss above, interest rate swaps are used indirectly through an index fund in the pension master trust.

Future Payments

We expect to contribute the following amounts to our pension and other postretirement benefit plans in 2012:

	Sempra Energy
(Dollars in millions)	Consolidated		SDG&E		SoCalGas
Pension plans	$	215	$	67	$	113
Other postretirement benefit plans		59		14		40

The following table shows the total benefits we expect to pay for the next 10 years to current employees and retirees from the plans or from company assets.

	Sempra Energy Consolidated				SDG&E				SoCalGas
			Other				Other				Other
	Pension		Postretirement		Pension		Postretirement		Pension		Postretirement
(Dollars in millions)	Benefits		Benefits		Benefits		Benefits		Benefits		Benefits
2012	$	302	$	49	$	89	$	7	$	173	$	37
2013		309		52		91		8		183		40
2014		313		56		91		9		185		43
2015		304		60		89		10		179		46
2016		302		64		82		11		182		49
2017-2021		1,344		373		377		67		806		283

PROFIT SHARING PLANS

Under Chilean law, Chilquinta Energía is required to pay all employees either (1) 30 percent of Chilquinta Energía’s taxable income after deducting a 10 percent return on equity, allocated in proportion to the annual salary of each employee or (2) 25 percent of each employee’s annual salary, with a maximum mandatory profit sharing of 4.75 months of Chile’s legal minimum salary. Chilquinta Energía has elected the second option but calculates the profit sharing amounts with actual employee salaries instead of the legal minimum salary, resulting in a higher cost. The amounts are paid out each pay period. Chilquinta Energía recorded annual profit sharing expense of $5 million for 2011 related to this plan.

Under Peruvian law, Luz del Sur is required to pay their employees 5 percent of Luz del Sur’s taxable income, paid once a year and allocated as follows: 50 percent based on each employee’s annual hours worked and 50 percent based on each employee’s annual salary. Luz del Sur recorded annual profit sharing expense of $9 million for 2011 related to this plan.

SAVINGS PLANS

Sempra Energy offers trusteed savings plans to all domestic employees. Participation in the plans is immediate for salary deferrals for all employees except for the represented employees at SoCalGas, who are eligible upon completion of one year of service. Subject to plan provisions, employees may contribute from one percent to 25 percent of their regular earnings when they begin employment. After one year of the employee’s completed service, Sempra Energy makes matching contributions. Employer contribution amounts and methodology vary by plan, but generally the contributions are equal to 50 percent of the first 6 percent of eligible base salary contributed by employees and, if certain company goals are met, an additional amount related to incentive compensation payments.

Employer contributions are initially invested in Sempra Energy common stock, but the employee may transfer the contribution to other investments. Employee contributions are invested in Sempra Energy common stock, mutual funds or institutional trusts (the same investments to which employees may direct the employer contributions), which the employee selects. In Sempra Energy plans, employee contributions may also be invested in guaranteed investment contracts. Employer contributions for substantially all plans are partially funded by the ESOP referred to below.

Contributions to the savings plans were as follows:

(Dollars in millions)	2011		2010		2009
Sempra Energy Consolidated	$	32	$	31	$	31
SDG&E		14		14		13
SoCalGas		14		13		13

The market value of Sempra Energy common stock held by the savings plans was $883 million and $847 million at December 31, 2011 and 2010, respectively.

EMPLOYEE STOCK OWNERSHIP PLAN

All contributions to the ESOP Trust (described in Note 5) are made by Sempra Energy; there are no contributions made by the participants. As Sempra Energy makes contributions, the ESOP debt service is paid and shares are released in proportion to the total expected debt service. We charge compensation expense and credit equity for the market value of the released shares. Dividends on unallocated shares are used to pay debt service and are applied against the liability. The shares held by the Trust are unallocated and consist of 0.2 million shares of Sempra Energy common stock with a fair value of $8 million at December 31, 2011, and 0.5 million shares of Sempra Energy common stock with a fair value of $27 million at December 31, 2010.

NOTE 9. SHARE-BASED COMPENSATION

SEMPRA ENERGY EQUITY COMPENSATION PLANS

Sempra Energy has share-based compensation plans intended to align employee and shareholder objectives related to the long-term growth of Sempra Energy. The plans permit a wide variety of share-based awards, including:

§	non-qualified stock options

§	incentive stock options

§	restricted stock

§	restricted stock units

§	stock appreciation rights

§	performance awards

§	stock payments

§	dividend equivalents

Eligible California Utilities employees participate in Sempra Energy’s share-based compensation plans as a component of their compensation package.

At December 31, 2011, Sempra Energy had the following types of equity awards outstanding:

Non-Qualified Stock Options: Options have an exercise price equal to the market price of the common stock at the date of grant, are service-based, become exercisable over a four-year period, and expire 10 years from the date of grant. Vesting and/or the ability to exercise may be accelerated upon a change in control, in accordance with severance pay agreements or upon eligibility for retirement. Options are subject to forfeiture or earlier expiration when an employee terminates employment.

Restricted Stock: Substantially all restricted stock awards vest at the end of four-year performance periods based on Sempra Energy’s total return to shareholders relative to that of market indices. Vesting is subject to earlier forfeiture upon termination of employment and accelerated vesting upon a change in control, in accordance with severance pay agreements or upon eligibility for retirement. Holders of restricted stock have full voting rights. They also have full dividend rights; however, dividends paid on restricted stock held by officers are reinvested to purchase additional shares that become subject to the same vesting conditions as the restricted stock to which the dividends relate.

Restricted Stock Units: Restricted stock unit awards vest at the end of four-year performance periods based on Sempra Energy’s total return to shareholders relative to that of market indices. If Sempra Energy’s total return to shareholders exceeds the target levels established under the 2008 Long Term Incentive Plan for awards granted beginning in 2008 and each year since, up to an additional 50 percent of the number of granted restricted stock units may be issued. If Sempra Energy’s total return to shareholders is below the target levels, shares are subject to partial vesting on a pro rata basis. Vesting is subject to earlier forfeiture upon termination of employment and accelerated vesting upon a change in control, in accordance with severance pay agreements or upon eligibility for retirement. Dividend equivalents on shares subject to restricted stock units are reinvested to purchase additional shares that become subject to the same vesting conditions as the restricted stock units to which the dividends relate.

The Sempra Energy 2008 Long Term Incentive Plan for EnergySouth, Inc. Employees and Other Eligible Individuals (the Plan) authorizes the issuance of up to 302,478 shares of Sempra Energy common stock. In connection with the acquisition of EnergySouth, Inc. in October 2008, we adopted the Plan to utilize the shares remaining available for future awards under the 2008 Incentive Plan of EnergySouth, Inc. (the Prior Plan). All awards outstanding under the Prior Plan at the time of the acquisition were canceled, and the holders were paid the merger consideration in accordance with the terms of the merger agreement. The Plan provides for the grant of substantially the same types of share-based awards (other than incentive stock options) that are available under the Sempra Energy 2008 Long Term Incentive Plan.

SHARE-BASED AWARDS AND COMPENSATION EXPENSE

We measure and recognize compensation expense for all share-based payment awards made to our employees and directors based on estimated fair values on the date of grant. We recognize compensation costs net of an estimated forfeiture rate (based on historical experience) and recognize the compensation costs for non-qualified stock options and restricted stock and stock units on a straight-line basis over the requisite service period of the award, which is generally four years. However, in the year that an employee becomes eligible for retirement, the remaining expense related to the employee’s awards is recognized immediately. Substantially all awards outstanding are classified as equity instruments, therefore we recognize additional paid in capital as we recognize the compensation expense associated with the awards.

As of December 31, 2011, 2,555,427 shares were authorized and available for future grants of share-based awards. Our practice is to satisfy share-based awards by issuing new shares rather than by open-market purchases.

Total share-based compensation expense for all of Sempra Energy’s share-based awards was comprised as follows:

SHARE-BASED COMPENSATION EXPENSE ― SEMPRA ENERGY CONSOLIDATED
(Dollars in millions, except per share amounts)
	Years ended December 31,
	2011		2010		2009
Share-based compensation expense, before income taxes	$	44	$	34	$	34
Income tax benefit		(18)		(13)		(13)
Share-based compensation expense, net of income taxes	$	26	$	21	$	21

Net share-based compensation expense, per common share
Basic	$	0.11	$	0.09	$	0.09
Diluted	$	0.11	$	0.08	$	0.08

Sempra Energy Consolidated’s capitalized compensation cost was $4 million in 2011, $3 million in 2010 and $5 million in 2009.

We classify the tax benefits resulting from tax deductions in excess of the tax benefit related to compensation cost recognized for stock option exercises as financing cash flows.

Sempra Energy subsidiaries record an expense for the plans to the extent that subsidiary employees participate in the plans and/or the subsidiaries are allocated a portion of the Sempra Energy plans’ corporate staff costs. Expenses and capitalized compensation costs recorded by SDG&E and SoCalGas were as follows:

SHARE-BASED COMPENSATION EXPENSE ― SDG&E AND SOCALGAS
(Dollars in millions)
	Years ended December 31,
	2011		2010		2009
SDG&E:
Compensation expense	$	8	$	9	$	6
Capitalized compensation cost		3		2		3
SoCalGas:
Compensation expense	$	9	$	8	$	7
Capitalized compensation cost		1		1		2

SEMPRA ENERGY NON-QUALIFIED STOCK OPTIONS

We use a Black-Scholes option-pricing model (Black-Scholes model) to estimate the fair value of each non-qualified stock option grant. The use of a valuation model requires us to make certain assumptions about selected model inputs. Expected volatility is calculated based on the historical volatility of Sempra Energy’s stock price. We base the average expected life for options on the contractual term of the option and expected employee exercise and post-termination behavior.

The risk-free interest rate is based on U.S. Treasury zero-coupon issues with a remaining term equal to the expected life assumed at the date of the grant. No new options were granted in 2011, and the weighted-average per-share fair values for options granted in 2010 and 2009 were $7.92 and $5.29, respectively. To calculate these fair values, we used the Black-Scholes model with the following weighted-average assumptions:

	2010	2009
Stock price volatility	19%	18%
Risk-free rate of return	2.6%	1.9%
Annual dividend yield	2.8%	3.2%
Expected life	5.5 years	5.6 years

The following table shows a summary of the non-qualified stock options as of December 31, 2011 and activity for the year then ended:

NON-QUALIFIED STOCK OPTIONS

					Weighted-
			Weighted-		Average
	Shares		Average		Remaining		Aggregate
	Under		Exercise		Contractual Term		Intrinsic Value
	Option		Price		(in years)		(in millions)
Outstanding at December 31, 2010		5,630,472	$	44.79
Exercised		(958,126)	$	29.41
Forfeited/canceled		(41,375)	$	57.75
Outstanding at December 31, 2011		4,630,971	$	47.85		4.9	$	40

Vested or expected to vest, at December 31, 2011		4,615,468	$	47.83		4.8	$	40
Exercisable at December 31, 2011		3,542,346	$	46.56		4.2	$	35

The aggregate intrinsic value at December 31, 2011 is the total of the difference between Sempra Energy’s closing stock price and the exercise price for all in-the-money options. The aggregate intrinsic value for non-qualified stock options exercised in the last three years was

§	$23 million in 2011

§	$22 million in 2010

§	$45 million in 2009

The total fair value of shares vested in the last three years was

§	$7 million in 2011

§	$8 million in 2010

§	$9 million in 2009

The $1 million of total compensation cost related to nonvested stock options not yet recognized as of December 31, 2011 is expected to be recognized over a weighted-average period of 1.7 years.

We received cash from option exercises during 2011 totaling $28 million. There were no realized tax benefits for the share-based payment award deductions in 2011 over and above the $18 million income tax benefit shown above.

SEMPRA ENERGY RESTRICTED STOCK AWARDS AND UNITS

We use a Monte-Carlo simulation model to estimate the fair value of the restricted stock awards and units. Our determination of fair value is affected by the volatility of the stock price and the dividend yields for Sempra Energy and its peer group companies. The valuation also is affected by the risk-free rates of return, and a number of other variables. Below are key assumptions for Sempra Energy:

	2011	2010	2009
Risk-free rate of return	1.5%	2.1%	1.4%
Annual dividend yield	3.0%	2.8%	3.2%
Stock price volatility	27%	26%	25%

Restricted Stock Awards

We provide a summary of Sempra Energy’s restricted stock awards as of December 31, 2011 and the activity during the year below.

RESTRICTED STOCK AWARDS

			Weighted-
			Average
			Grant-Date
	Shares		Fair Value
Nonvested at December 31, 2010		787,973	$	36.73
Granted		11,876	$	52.96
Vested		(775,573)	$	36.67
Nonvested at December 31, 2011		24,276	$	46.51
Vested or expected to vest, at December 31, 2011		24,276	$	46.51

The $1 million of total compensation cost related to nonvested restricted stock awards not yet recognized as of December 31, 2011 is expected to be recognized in 2012. The weighted-average per-share fair value for restricted stock awards granted in 2009 was $40.34.

The total fair value of shares vested in the last three years was

§	$28 million in 2011

§	$4 million in 2010

§	$27 million in 2009

Restricted Stock Units

We provide a summary of Sempra Energy’s restricted stock units as of December 31, 2011 and the activity during the year below.

RESTRICTED STOCK UNITS

				Weighted-
				Average
				Grant-Date
		Units		Fair Value
Nonvested at December 31, 2010			2,231,325	$	43.46
Granted			1,089,223	$	42.35
Vested			(10,336)	$	50.40
Forfeited			(17,700)	$	42.34
Nonvested at December 31, 2011(1)			3,292,512	$	43.08
Vested or expected to vest, at December 31, 2011			3,231,843	$	43.10
(1)	Each unit represents the right to receive one share of our common stock if applicable performance conditions are satisfied. Up to an additional 50% of the shares represented by the units may be issued if Sempra Energy exceeds target performance conditions.

The $24 million of total compensation cost related to nonvested restricted stock units not yet recognized as of December 31, 2011 is expected to be recognized over a weighted-average period of 2.3 years. The weighted-average per-share fair values for restricted stock units granted were $44.44 in 2010 and $35.96 in 2009.

NOTE 10. 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 and benchmark interest rate risk. We may also manage foreign exchange rate exposures using derivatives. 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 presented below.

We record all derivatives at fair value on the 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 other comprehensive income (cash flow hedge), on the balance sheet (fair value hedges and regulatory offsets), or recognized in earnings. We classify cash flows from the settlements of derivative instruments as operating activities on the Consolidated Statements of Cash Flows.

In certain cases, we apply the normal purchase or sale exception to derivative accounting 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.

HEDGE ACCOUNTING

We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accounting for derivative commodity 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 a given future revenue or expense item may vary, and other criteria.

We may designate an interest rate derivative as a fair value hedging instrument if it effectively converts our own debt from a fixed interest rate to a variable rate. The combination of the derivative and debt instruments results in fixing that portion of the fair value of the debt that is related to benchmark interest rates. Designating fair value hedges is dependent on the instrument being used, the effectiveness of the instrument in offsetting changes in the fair value of our debt instruments, 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.

The California Utilities use natural gas energy derivatives, on their customers’ behalf, with the objective of managing price risk and basis risks, and lowering natural gas costs. These derivatives include fixed price natural gas positions, options, and basis risk instruments, which are either exchange-traded or over-the-counter financial instruments. This activity is governed by risk management and transacting activity plans that have been filed with and approved by the CPUC. Natural gas 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 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 congestion revenue rights (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 are recorded in Cost of Electric Fuel and Purchased Power, which is recoverable in rates, on the Consolidated Statements of Operations.

Sempra Mexico uses natural gas derivatives and Sempra Natural Gas uses natural gas and electricity derivatives to market energy commodities and optimize the earnings of their natural gas power plants. Gains and losses associated with these undesignated derivatives are recognized in Energy-Related Businesses Revenues or in Cost of Natural Gas, Electric Fuel and Purchased Power on the Consolidated Statements of Operations.

Sempra Mexico and Sempra Natural Gas use natural gas derivatives to market energy commodities and optimize the earnings of our LNG business and Sempra Natural Gas’ natural gas storage and transportation assets and LNG assets. These derivatives are undesignated, and their impact on earnings is recorded in Energy-Related Businesses Revenues on the Consolidated Statements of Operations. Sempra Mexico also uses natural gas energy derivatives with the objective of managing price risk and lowering natural gas prices at its Mexican 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 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.

We summarize net energy derivative volumes as of December 31, 2011 and 2010 as follows:


		December 31,
Business Unit and Commodity		2011	2010
California Utilities:
SDG&E:
	Natural gas	35 million MMBtu	51 million MMBtu	(1)
	Congestion revenue rights	19 million MWh	21 million MWh	(2)

Energy-Related Businesses:
Sempra Natural Gas:
Electric power		5 million MWh	1 million MWh
Natural gas		20 million MMBtu	15 million MMBtu
Sempra Mexico - natural gas		1 million MMBtu	-
(1)	Million British thermal units
(2)	Megawatt hours

In addition to the amounts noted above, we frequently use commodity derivatives to manage risks associated with the physical locations of our customers, assets and other contractual obligations, 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. We periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. We utilize interest rate swaps typically designated as fair value hedges, as a means to achieve our targeted level of variable rate debt as a percent of total debt. In addition, we may utilize interest rate swaps, which are typically designated as cash flow hedges, to lock in interest rates on outstanding debt or in anticipation of future financings.

Interest rate derivatives are utilized by the California Utilities as well as by other Sempra Energy subsidiaries. Although the California Utilities generally recover borrowing costs in rates over time, the use of interest rate derivatives is subject to certain regulatory constraints, and the impact of interest rate derivatives may not be recovered from customers as timely as described above with regard to natural gas derivatives. Accordingly, interest rate derivatives are generally accounted for as hedges at the California Utilities, as well as at the rest of Sempra Energy’s subsidiaries. Separately, Otay Mesa VIE has entered into interest rate swap agreements to moderate its exposure to interest rate changes. This activity was designated as a cash flow hedge as of April 1, 2011.

The net notional amounts of our interest rate derivatives as of December 31, 2011 and 2010 were:

		December 31, 2011			December 31, 2010
(Dollars in millions)		Notional Debt		Maturities	Notional Debt		Maturities
Sempra Energy Consolidated(1)		$	15-305	2013-2019	$	215-355	2011-2019
SDG&E(1)			285-355	2019		285-365	2019
SoCalGas			-	-		150	2011
(1)	Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE.

FOREIGN CURRENCY DERIVATIVES

We are exposed to exchange rate movements primarily as a result of our Mexican subsidiaries, which have U.S. dollar denominated receivables and payables (monetary assets and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. These subsidiaries also have deferred income tax assets and liabilities that are denominated in the Mexican peso, which must be translated into U.S. dollars for financial reporting purposes. From time to time, we may utilize short-term foreign currency derivatives at our subsidiaries and at the consolidated level as a means to manage the risk of exposure to significant fluctuations in our income tax expense from these impacts.

FINANCIAL STATEMENT PRESENTATION

The following tables provide the fair values of derivative instruments, without consideration of margin deposits held or posted, on the Consolidated Balance Sheets as of December 31, 2011 and 2010:

DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
		December 31, 2011
									Deferred
									credits
			Current				Current		and other
			assets:				liabilities:		liabilities:
			Fixed-price		Investments		Fixed-price		Fixed-price
			contracts		and other		contracts		contracts
			and other		assets:		and other		and other
Derivatives designated as hedging instruments			derivatives(1)		Sundry		derivatives(2)		derivatives
Sempra Energy Consolidated:
	Interest rate instruments(3)	$	5	$	11	$	(17)	$	(65)
SDG&E:
	Interest rate instruments(3)	$	―	$	―	$	(16)	$	(65)

Derivatives not designated as hedging instruments
Sempra Energy Consolidated:
	Interest rate instruments	$	8	$	41	$	(7)	$	(36)
	Commodity contracts not subject to rate recovery		156		72		(148)		(94)
	Associated offsetting commodity contracts		(120)		(68)		120		68
	Commodity contracts subject to rate recovery		28		8		(62)		(24)
	Associated offsetting commodity contracts		(10)		(2)		10		2
	Total	$	62	$	51	$	(87)	$	(84)
SDG&E:
	Commodity contracts subject to rate recovery	$	22	$	8	$	(55)	$	(24)
	Associated offsetting commodity contracts		(5)		(2)		5		2
	Total	$	17	$	6	$	(50)	$	(22)
SoCalGas:
	Commodity contracts subject to rate recovery	$	6	$	―	$	(7)	$	―
	Associated offsetting commodity contracts		(5)		―		5		―
	Total	$	1	$	―	$	(2)	$	―
(1)	Included in Current Assets: Other for SoCalGas.
(2)	Included in Current Liabilities: Other for SoCalGas.
(3)	Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE.

DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Continued)
(Dollars in millions)
		December 31, 2010
									Deferred
									credits
			Current				Current		and other
			assets:				liabilities:		liabilities:
			Fixed-price		Investments		Fixed-price		Fixed-price
			contracts		and other		contracts		contracts
			and other		assets:		and other		and other
Derivatives designated as hedging instruments			derivatives(1)		Sundry		derivatives(2)		derivatives
Sempra Energy Consolidated:
	Interest rate instrument	$	3	$	―	$	―	$	―
SoCalGas:
	Interest rate instrument	$	3	$	―	$	―	$	―

Derivatives not designated as hedging instruments
Sempra Energy Consolidated:
	Interest rate instruments(3)	$	9	$	22	$	(25)	$	(57)
	Commodity contracts not subject to rate recovery		59		20		(44)		(34)
	Associated offsetting commodity contracts		(2)		(8)		2		8
	Commodity contracts subject to rate recovery		5		―		(43)		(27)
	Associated offsetting commodity contracts		(37)		(26)		37		26
	Total	$	34	$	8	$	(73)	$	(84)
SDG&E:
	Interest rate instruments(3)	$	―	$	―	$	(17)	$	(41)
	Commodity contracts not subject to rate recovery		1		―		―		―
	Commodity contracts subject to rate recovery		2		―		(35)		(27)
	Associated offsetting commodity contracts		(34)		(26)		34		26
	Total	$	(31)	$	(26)	$	(18)	$	(42)
SoCalGas:
	Commodity contracts not subject to rate recovery	$	1	$	―	$	―	$	―
	Commodity contracts subject to rate recovery		3		―		(3)		―
	Associated offsetting commodity contracts		(3)		―		3		―
	Total	$	1	$	―	$	―	$	―
(1)	Included in Current Assets: Other for SoCalGas.
(2)	Included in Current Liabilities: Other for SoCalGas.
(3)	Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE.

The effects of derivative instruments designated as hedges on the Consolidated Statements of Operations and on Other Comprehensive Income (OCI) and Accumulated Other Comprehensive Income (AOCI) for the years ended December 31 were:

FAIR VALUE HEDGE IMPACT ON THE CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
			Gain (loss) on derivatives recognized in earnings
			Years ended December 31,
		Location	2011		2010		2009
Sempra Energy Consolidated:
	Interest rate instruments	Interest Expense	$	9	$	10	$	19
	Interest rate instruments	Other Income, Net		13		(11)		(11)
	Total(1)		$	22	$	(1)	$	8
SoCalGas:
	Interest rate instrument	Interest Expense	$	1	$	6	$	6
	Interest rate instrument	Other Income, Net		(3)		(4)		(2)
	Total(1)		$	(2)	$	2	$	4
(1)	There has been no hedge ineffectiveness on these swaps. Changes in the fair values of the interest rate swap agreements are exactly offset by changes in the fair value of the underlying long-term debt.

CASH FLOW HEDGE IMPACT ON THE CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
		Pretax gain (loss) recognized in OCI							Gain (loss) reclassified from AOCI into earnings
		(effective portion)							(effective portion)
		Years ended December 31,							Years ended December 31,
			2011		2010		2009	Location		2011		2010		2009
Sempra Energy Consolidated:
	Interest rate instruments(1)	$	(42)	$	―	$	―	Interest Expense	$	(8)	$	(12)	$	(2)
	Interest rate instruments		―		―		13	Other Income, Net(2)		―		10		3
								Equity Earnings, Net of Income
	Interest rate instruments		(32)		2		―	Tax		(5)		(1)		―
	Commodity contracts not subject							Revenues: Energy-Related
	to rate recovery		―		―		17	Businesses		―		―		22
	Commodity contracts not subject							Cost of Natural Gas, Electric
	to rate recovery		―		―		―	Fuel and Purchased Power		―		―		(16)
	Commodity contracts not subject
	to rate recovery		―		―		1	Other Operation and Maintenance		―		―		2
	Commodity contracts not subject							Equity Earnings (Losses): RBS
	to rate recovery		―		1		37	Sempra Commodities LLP		―		21		7
	Total	$	(74)	$	3	$	68		$	(13)	$	18	$	16
SDG&E:
	Interest rate instruments(1)	$	(40)	$	―	$	―	Interest Expense	$	(5)	$	(7)	$	3
	Commodity contracts not subject
	to rate recovery		―		―		―	Operation and Maintenance		―		―		1
	Total	$	(40)	$	―	$	―		$	(5)	$	(7)	$	4
SoCalGas:
	Interest rate instrument	$	―	$	―	$	―	Interest Expense	$	(3)	$	(5)	$	(4)
	Commodity contracts not subject
	to rate recovery		―		―		1	Operation and Maintenance		―		―		1
	Total	$	―	$	―	$	1		$	(3)	$	(5)	$	(3)
(1)	Amounts include Otay Mesa VIE. All of SDG&E’s 2010 and 2011 interest rate derivative activity relates to Otay Mesa VIE. There has been a negligible amount of ineffectiveness related to these swaps.
(2)	Gains reclassified into earnings due to changes in cash requirements and associated impacts on forecasted interest payments, primarily related to proceeds received from RBS Sempra Commodities. See Note 4.

Sempra Energy expects that losses of $8 million, which are net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next twelve months as the hedged items affect earnings. Actual amounts ultimately reclassified into earnings depend on the interest rates in effect when derivative contracts that are currently outstanding mature.

SDG&E and SoCalGas expect that losses of $3 million and $1 million, respectively, which are net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next twelve months as the hedged items affect earnings.

For all forecasted transactions, the maximum term over which we are hedging exposure to the variability of cash flows at December 31, 2011 is 88 months for Sempra Energy and SDG&E. The maximum term of exposure related to contracts at Sempra Renewables’ equity method investees is 18 years.

We recorded negligible hedge ineffectiveness in 2011, 2010 and 2009.

The effects of derivative instruments not designated as hedging instruments on the Consolidated Statements of Operations for the years ended December 31 were:

UNDESIGNATED DERIVATIVE IMPACT ON THE CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
			Gain (loss) on derivatives recognized in earnings
			Years ended December 31,
		Location	2011		2010		2009
Sempra Energy Consolidated:
	Interest rate and foreign
	exchange instruments(1)	Other Income, Net	$	(14)	$	(34)	$	30
	Commodity contracts not subject	Revenues: Energy-Related
	to rate recovery	Businesses		30		47		47
	Commodity contracts not subject	Cost of Natural Gas, Electric
	to rate recovery	Fuel and Purchased Power		1		(29)		(39)
	Commodity contracts not subject
	to rate recovery	Other Operation and Maintenance		1		2		―
	Commodity contracts subject	Cost of Electric Fuel
	to rate recovery	and Purchased Power		(14)		(102)		(54)
	Commodity contracts subject
	to rate recovery	Cost of Natural Gas		(2)		(9)		(10)
	Total		$	2	$	(125)	$	(26)
SDG&E:
	Interest rate instruments(1)	Other Income, Net	$	(1)	$	(34)	$	27
	Commodity contracts not subject
	to rate recovery	Operation and Maintenance		―		1		―
	Commodity contracts subject	Cost of Electric Fuel
	to rate recovery	and Purchased Power		(14)		(102)		(54)
	Total		$	(15)	$	(135)	$	(27)
SoCalGas:
	Commodity contracts not subject
	to rate recovery	Operation and Maintenance	$	1	$	1	$	―
	Commodity contracts subject
	to rate recovery	Cost of Natural Gas		(2)		(5)		(5)
	Total		$	(1)	$	(4)	$	(5)
(1)	Amounts are related to Otay Mesa VIE. Sempra Energy Consolidated also includes additional instruments.

CONTINGENT FEATURES

For Sempra Energy and SDG&E, certain of our derivative instruments contain credit limits which vary depending upon 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, the total fair value of this group of derivative instruments in a net liability position at December 31, 2011 is $24 million. As of December 31, 2011, if the credit ratings of Sempra Energy were reduced below investment grade, $24 million of additional assets could be required to be posted as collateral for these derivative contracts.

For SDG&E, the total fair value of this group of derivative instruments in a net liability position at December 31, 2011 is $11 million. As of December 31, 2011, if the credit ratings of SDG&E were reduced below investment grade, $11 million of additional assets could be required to be posted as collateral for these derivative contracts.

For Sempra Energy, 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 11. FAIR VALUE MEASUREMENTS

FAIR VALUE OF FINANCIAL INSTRUMENTS

The fair values of certain of our financial instruments (cash, temporary investments, accounts and notes receivable, dividends and accounts payable, short-term debt and customer deposits) approximate their carrying amounts. The following table provides the carrying amounts and fair values of certain other financial instruments at December 31:

FAIR VALUE OF FINANCIAL INSTRUMENTS
(Dollars in millions)
		December 31, 2011				December 31, 2010
		Carrying		Fair		Carrying		Fair
		Amount		Value		Amount		Value
Sempra Energy Consolidated:
Investments in affordable housing partnerships(1)		$	21	$	48	$	28	$	58
Total long-term debt(2)			9,826		11,047		8,330		8,883
Due to unconsolidated affiliate(3)			―		―		2		2
Preferred stock of subsidiaries			99		106		179		166
SDG&E:
Total long-term debt(4)		$	3,895	$	4,288	$	3,305	$	3,300
Contingently redeemable preferred stock			79		86		79		78
SoCalGas:
Total long-term debt(5)		$	1,313	$	1,506	$	1,566	$	1,638
Preferred stock			22		23		22		21
(1)	We discuss our investments in affordable housing partnerships in Note 4.
(2)	Before reductions for unamortized discount (net of premium) of $16 million at December 31, 2011 and $22 million at December 31, 2010, and excluding capital leases of $204 million at December 31, 2011 and $221 million at December 31, 2010, and commercial paper classified as long-term debt of $400 million at December 31, 2011 and $800 million at December 31, 2010. We discuss our long-term debt in Note 5.
(3)	Note payable was extinguished due to the increase in our ownership of Chilquinta Energía to 100% in 2011.
(4)	Before reductions for unamortized discount of $11 million at December 31, 2011 and $9 million at December 31, 2010, and excluding capital leases of $193 million at December 31, 2011 and $202 million at December 31, 2010.
(5)	Before reductions for unamortized discount of $3 million at both December 31, 2011 and 2010, and excluding capital leases of $11 million at December 31, 2011 and $19 million at December 31, 2010.

Sempra Energy based the fair values of investments in affordable housing partnerships on the present value of estimated future cash flows, discounted at rates available for similar investments. All entities based the fair values of long-term debt and preferred stock on their quoted market prices or quoted market prices for similar securities.

Derivative Positions Net of Cash Collateral

Each Consolidated Balance Sheet reflects the offsetting of net derivative positions with fair value amounts for cash collateral with the same counterparty when management believes a legal right of offset exists.

The following table provides the amount of fair value of cash collateral receivables that were not offset in the Consolidated Balance Sheets as of December 31, 2011 and 2010:

	December 31,
(Dollars in millions)	2011		2010
Sempra Energy Consolidated	$	20	$	32
SDG&E		10		25
SoCalGas		2		3

Fair Value Hierarchy

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 under “Fair Value Measurements.”

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 as of December 31, 2011 and 2010. We also discuss our financial assets and liabilities recorded at fair value on a non-recurring basis. 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 levels.

The fair value of commodity derivative assets and liabilities is determined in accordance with our netting policy, as discussed above under “Derivative Positions Net of Cash Collateral.”

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 as of December 31, 2011 and 2010 in the tables below include the following:

Nuclear decommissioning trusts reflect the assets of SDG&E’s nuclear decommissioning trusts, excluding cash balances, as we discuss in Note 6. The trust assets are valued by a third party trustee. The trustee obtains prices from pricing services that are derived from observable data. We monitor the prices supplied by pricing services by validating pricing with other sources of data.

§	Investments include marketable securities and are primarily priced based on observable interest rates for similar instruments actively trading in the marketplace.

Commodity and other derivative positions, which include other interest rate management instruments, are entered into primarily as a means to manage price exposures. We use market participant assumptions to price these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable.

RECURRING FAIR VALUE MEASURES ― SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
		At fair value as of December 31, 2011
									Collateral
			Level 1		Level 2		Level 3		Netted		Total
Assets:
Nuclear decommissioning trusts
Equity securities		$	468	$	―	$	―	$	―	$	468
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			92		78		―		―		170
Municipal bonds			―		77		―		―		77
Other securities			―		78		―		―		78
Total debt securities			92		233		―		―		325
Total nuclear decommissioning trusts(1)			560		233		―		―		793
Interest rate instruments			―		66		―		―		66
Commodity contracts subject to rate recovery			10		1		23		―		34
Commodity contracts not subject to rate recovery			15		35		―		(2)		48
Investments			5		―		―		―		5
Total		$	590	$	335	$	23	$	(2)	$	946
Liabilities:
Interest rate instruments		$	1	$	124	$	―	$	―	$	125
Commodity contracts subject to rate recovery			61		13		―		(61)		13
Commodity contracts not subject to rate recovery			1		52		―		(4)		49
Total		$	63	$	189	$	―	$	(65)	$	187

		At fair value as of December 31, 2010
									Collateral
			Level 1		Level 2		Level 3		netted		Total
Assets:
Nuclear decommissioning trusts
Equity securities		$	460	$	―	$	―	$	―	$	460
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			144		30		―		―		174
Municipal bonds			―		100		―		―		100
Other securities			―		25		―		―		25
Total debt securities			144		155		―		―		299
Total nuclear decommissioning trusts(1)			604		155		―		―		759
Interest rate instruments			―		34		―		―		34
Commodity contracts subject to rate recovery			25		1		2		―		28
Commodity contracts not subject to rate recovery			9		66		―		(22)		53
Investments			1		―		―		―		1
Total		$	639	$	256	$	2	$	(22)	$	875
Liabilities:
Interest rate instruments		$	―	$	82	$	―	$	―	$	82
Commodity contracts subject to rate recovery			60		8		―		(60)		8
Commodity contracts not subject to rate recovery			―		67		―		―		67
Total		$	60	$	157	$	―	$	(60)	$	157
(1)	Excludes cash balances and cash equivalents.

RECURRING FAIR VALUE MEASURES ― SDG&E
(Dollars in millions)
		At fair value as of December 31, 2011
									Collateral
			Level 1		Level 2		Level 3		netted		Total
Assets:
Nuclear decommissioning trusts
Equity securities		$	468	$	―	$	―	$	―	$	468
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			92		78		―		―		170
Municipal bonds			―		77		―		―		77
Other securities			―		78		―		―		78
Total debt securities			92		233		―		―		325
Total nuclear decommissioning trusts(1)			560		233		―		―		793
Commodity contracts subject to rate recovery			9		―		23		―		32
Commodity contracts not subject to rate recovery			1		―		―		―		1
Total		$	570	$	233	$	23	$	―	$	826

Liabilities:
Interest rate instruments		$	―	$	81	$	―	$	―	$	81
Commodity contracts subject to rate recovery			61		12		―		(61)		12
Total		$	61	$	93	$	―	$	(61)	$	93

		At fair value as of December 31, 2010
									Collateral
			Level 1		Level 2		Level 3		netted		Total
Assets:
Nuclear decommissioning trusts
Equity securities		$	460	$	―	$	―	$	―	$	460
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			144		30		―		―		174
Municipal bonds			―		100		―		―		100
Other securities			―		25		―		―		25
Total debt securities			144		155		―		―		299
Total nuclear decommissioning trusts(1)			604		155		―		―		759
Commodity contracts subject to rate recovery			24		―		2		―		26
Commodity contracts not subject to rate recovery			2		―		―		―		2
Total		$	630	$	155	$	2	$	―	$	787

Liabilities:
Interest rate instruments		$	―	$	58	$	―	$	―	$	58
Commodity contracts subject to rate recovery			60		2		―		(60)		2
Total		$	60	$	60	$	―	$	(60)	$	60
(1)	Excludes cash balances and cash equivalents.

RECURRING FAIR VALUE MEASURES ― SOCALGAS
(Dollars in millions)
	At fair value as of December 31, 2011
								Collateral
		Level 1		Level 2		Level 3		netted		Total
Assets:
Commodity contracts subject to rate recovery	$	1	$	1	$	―	$	―	$	2
Commodity contracts not subject to rate recovery		2		―		―		―		2
Total	$	3	$	1	$	―	$	―	$	4

Liabilities:
Commodity contracts subject to rate recovery	$	―	$	1	$	―	$	―	$	1
Total	$	―	$	1	$	―	$	―	$	1

	At fair value as of December 31, 2010
								Collateral
		Level 1		Level 2		Level 3		netted		Total
Assets:
Interest rate instruments	$	―	$	3	$	―	$	―	$	3
Commodity contracts subject to rate recovery		1		1		―		―		2
Commodity contracts not subject to rate recovery		3		―		―		―		3
Total	$	4	$	4	$	―	$	―	$	8

There were no transfers into or out of Level 1 or Level 2 for Sempra Energy Consolidated, SDG&E or SoCalGas during the periods presented.

Level 3 Information

The following table sets forth reconciliations of changes in the fair value of net trading and other derivatives classified as Level 3 in the fair value hierarchy for Sempra Energy Consolidated and SDG&E:

LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Years ended December 31,
	2011		2010		2009
Balance as of January 1	$	2	$	10	$	27
Realized and unrealized gains (losses)		32		(16)		(31)
Allocated transmission instruments		7		8		15
Settlements		(18)		―		(1)
Balance as of December 31	$	23	$	2	$	10
Change in unrealized gains or losses relating to
instruments still held at December 31	$	17	$	(9)	$	(16)

There were no transfers into or out of Level 3 during the periods presented.

Level 3 recurring items are related to CRRs at SDG&E. These instruments are recorded at fair value based on the most current auction prices published by the California Independent System Operator (ISO). The earnings impacts of CRRs are deferred and recorded in regulatory accounts to the extent they are recoverable or refundable through rates. Upon settlement, CRRs are included in Cost of Electric Fuel and Purchased Power on the Consolidated Statements of Operations for each of the three years in the period ended December 31, 2011.

Non-Recurring Fair Value Measures – Sempra Energy Consolidated

We discuss non-recurring fair value measures and the associated accounting impact on our investments in RBS Sempra Commodities and Argentina in Note 4.

NOTE 12. PREFERRED STOCK

The table below shows the details of preferred stock for SDG&E, SoCalGas and Pacific Enterprises (PE). All series of PE preferred stock were redeemed during 2011 as we discuss below.

PREFERRED STOCK

			Call/
			Redemption	December 31,
			Price	2011		2010
				(in millions)
Contingently redeemable:
	SDG&E:
	$20 par value, authorized 1,375,000 shares:
	5% Series, 375,000 shares outstanding	$	24.00	$	8	$	8
	4.5% Series, 300,000 shares outstanding	$	21.20		6		6
	4.4% Series, 325,000 shares outstanding	$	21.00		7		7
	4.6% Series, 373,770 shares outstanding	$	20.25		7		7
	Without par value:
	$1.70 Series, 1,400,000 shares outstanding	$	25.17		35		35
	$1.82 Series, 640,000 shares outstanding	$	26.00		16		16
	SDG&E - Total contingently redeemable preferred stock				79		79
	Sempra Energy - Total preferred stock of subsidiary,
	contingently redeemable			$	79	$	79

SoCalGas:
$25 par value, authorized 1,000,000 shares:
6% Series, 79,011 shares outstanding				$	3	$	3
6% Series A, 783,032 shares outstanding					19		19
Total preferred stock of SoCalGas					22		22
Less: 50,970 shares of the 6% Series outstanding owned by PE					(2)		(2)
					20		20
Pacific Enterprises:
Without par value, authorized 15,000,000 shares; outstanding
	as of December 31, 2010:
$4.75 Dividend, 200,000 shares		$	100.00		―		20
$4.50 Dividend, 300,000 shares		$	100.00		―		30
$4.40 Dividend, 100,000 shares		$	101.50		―		10
$4.36 Dividend, 200,000 shares		$	101.00		―		20
$4.75 Dividend, 253 shares		$	101.00		―		―
Total preferred stock of Pacific Enterprises					―		80

	Sempra Energy - Total preferred stock of subsidiaries			$	20	$	100

Following are the attributes of each company’s preferred stock. No amounts currently outstanding are subject to mandatory redemption.

SDG&E

§	All outstanding series are callable.

§	The $20 par value preferred stock has two votes per share on matters being voted upon by shareholders of SDG&E and a liquidation preference at par plus any unpaid dividends.

§	All outstanding series of SDG&E’s preferred stock have cumulative preferences as to dividends.

§	The no-par-value preferred stock is nonvoting and has a liquidation preference of $25 per share plus any unpaid dividends.

§	SDG&E is authorized to issue 10 million shares of no-par-value preferred stock (both subject to and not subject to mandatory redemption).

SDG&E is currently authorized to issue up to 25 million shares of an additional class of preference shares designated as “Series Preference Stock.” The Series Preference Stock is in addition to the Cumulative Preferred Stock, Preference Stock (Cumulative) and Common Stock that SDG&E was otherwise authorized to issue, and when issued would rank junior to the Cumulative Preferred Stock and Preference Stock (Cumulative). The stock’s rights, preferences and privileges would be established by the board of directors at the time of issuance.

SDG&E’s outstanding preferred securities are classified as contingently redeemable because they contain a contingent redemption feature that allows the holder to elect a majority of SDG&E’s board of directors if dividends are not paid for eight consecutive quarters, and such a redemption triggering event is not solely within the control of SDG&E. They are therefore presented separate from and outside of equity in a manner consistent with temporary equity.

SOCALGAS

§	None of SoCalGas’ outstanding preferred stock is callable.

§	All outstanding series have one vote per share, cumulative preferences as to dividends and liquidation preferences of $25 per share plus any unpaid dividends.

SoCalGas currently is authorized to issue 5 million shares of series preferred stock and 5 million shares of preference stock, both without par value and with cumulative preferences as to dividends and liquidation value. The preference stock would rank junior to all series of preferred stock. Other rights and privileges of the stock would be established by the board of directors at the time of issuance.

PACIFIC ENTERPRISES

On June 30, 2011, PE redeemed all five series of its outstanding preferred stock for $81 million. Each series was redeemed for cash at redemption prices ranging from $100 to $101.50 per share, plus accrued dividends up to the redemption date of an aggregate of $1 million. The redeemed shares are no longer outstanding and represent only the right to receive the applicable redemption price, to the extent that shares have not yet been presented for payment.

PE currently is authorized to issue 10 million shares of series preferred stock and 5 million shares of Class A series preferred stock, both without par value and with cumulative preferences as to dividends and liquidation value. No shares of preferred stock or Class A series preferred stock are outstanding. Class A series preferred stock, when issued, would rank junior to all other series of preferred stock with respect to dividends and liquidation value. Other rights and privileges of each series of the preferred stock and Class A series preferred stock would be established by the board of directors at the time of issuance.

NOTE 13. SEMPRA ENERGY – SHAREHOLDERS’ EQUITY AND EARNINGS PER SHARE

The following table provides the per share computations for our earnings for years ended December 31. Basic earnings per common share (EPS) is calculated by dividing earnings attributable to common stock by the weighted-average number of common shares outstanding for the year. 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 SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
	Years ended December 31,
	2011		2010		2009
Numerator:
Earnings/Income attributable to common shareholders	$	1,331	$	709	$	1,119

Denominator:
Weighted-average common shares outstanding for basic EPS		239,720		244,736		243,339
Dilutive effect of stock options, restricted stock awards and
restricted stock units		1,803		3,206		4,045
Weighted-average common shares outstanding for diluted EPS		241,523		247,942		247,384

Earnings per share:
Basic	$	5.55	$	2.90	$	4.60
Diluted	$	5.51	$	2.86	$	4.52

The dilution from common stock options is based on the treasury stock method. Under this method, proceeds based on the exercise price plus unearned compensation and windfall tax benefits and minus tax shortfalls are assumed to be used to repurchase shares on the open market at the average market price for the period. The windfall tax benefits are tax deductions we would receive upon the assumed exercise of stock options in excess of the deferred income taxes we recorded related to the compensation expense on the stock options. Tax shortfalls occur when the assumed tax deductions are less than recorded deferred income taxes. The calculation excludes options for which the exercise price on common stock was greater than the average market price during the period (out-of-the-money options). We had 2,083,275; 2,138,800 and 1,504,250 of such antidilutive stock options outstanding during 2011, 2010 and 2009, respectively.

During 2011 and 2010, respectively, we had 900 and 9,900 stock options outstanding that were antidilutive because of the unearned compensation and windfall tax benefits included in the assumed proceeds under the treasury stock method. There were no such antidilutive stock options outstanding during 2009.

The dilution from unvested restricted stock awards (RSAs) and restricted stock units (RSUs) is also based on the treasury stock method. Assumed proceeds equal to the unearned compensation and windfall tax benefits and minus tax shortfalls related to the awards and units are assumed to be used to repurchase shares on the open market at the average market price for the period. The windfall tax benefits or tax shortfalls are the difference between tax deductions we would receive upon the assumed vesting of RSAs or RSUs and the deferred income taxes we recorded related to the compensation expense on such awards and units. There were no antidilutive restricted stock awards or units from the application of unearned compensation in the treasury stock method in 2011, 2010 or 2009.

Each performance based RSU represents the right to receive between zero and 1.5 shares of Sempra Energy common stock based on Sempra Energy’s four-year cumulative total shareholder return compared to the S&P 500 Utilities Index, as follows:

Four-Year Cumulative Total Shareholder Return Ranking versus S&P 500 Utilities Index(1)		Number of Sempra Energy Common Shares Received for Each Restricted Stock Unit(2)
75th Percentile or Above		1.5
50th Percentile		1
35th Percentile or Below		―
(1)	If Sempra Energy ranks at or above the 50th percentile compared to the S&P 500 Index, participants will receive a minimum of 1.0 share for each restricted stock unit.
(2)	Participants may also receive additional shares for dividend equivalents on shares subject to restricted stock units, which are reinvested to purchase additional shares that become subject to the same vesting conditions as the restricted stock units to which the dividends relate.

RSAs have a maximum potential of 100 percent vesting. We include our performance based RSAs and RSUs in potential dilutive shares at zero to 100 percent and zero to 150 percent, respectively, to the extent that they currently meet the performance requirements for vesting, subject to the application of the treasury stock method. Due to market fluctuations of both Sempra Energy stock and the comparative index, dilutive RSA and RSU shares may vary widely from period-to-period. We include our service-based RSAs in potential dilutive shares at 100 percent.

RSUs and RSAs may be excluded from potential dilutive shares by the application of unearned compensation in the treasury stock method or because performance goals are currently not met. The maximum excluded RSUs and RSAs, assuming performance goals were met at maximum levels, were 4,109,717; 2,008,413, and 1,058,521 for the years ended December 31 2011, 2010 and 2009, respectively.

We are authorized to issue 750,000,000 shares of no-par-value common stock. In addition, we are authorized to issue 50,000,000 shares of preferred stock having rights, preferences and privileges that would be established by the Sempra Energy board of directors at the time of issuance.

Shares of common stock held by the ESOP were 153,625; 504,440 and 868,173 at December 31, 2011, 2010 and 2009, respectively. These shares are unallocated and therefore excluded from the computation of EPS.

Excluding shares held by the ESOP, common stock activity consisted of the following:

COMMON STOCK ACTIVITY

		2011	2010	2009
Common shares outstanding, January 1		240,447,416	246,507,865	243,324,281
Savings plan issuance		―	560,600	1,021,023
Shares released from ESOP		350,815	363,733	309,023
Stock options exercised		958,126	912,725	1,835,184
Restricted stock issuances		11,876	―	37,233
Restricted stock units vesting(1)		2,625	―	―
Shares repurchased		(1,836,177)	(8,108,579)	(396,046)
Common stock investment plan(2)		―	217,772	381,167
Shares forfeited and other		―	(6,700)	(4,000)
Common shares outstanding, December 31		239,934,681	240,447,416	246,507,865
(1)	Includes dividend equivalents.
(2)	Participants in the Direct Stock Purchase Plan may reinvest dividends to purchase newly issued shares.

Our board of directors has the discretion to determine the payment and amount of future dividends.

COMMON STOCK REPURCHASE PROGRAMS

On September 11, 2007, our board of directors authorized the repurchase of additional shares of our common stock provided that the amounts expended for such purposes did not exceed the greater of $2 billion or amounts expended to purchase no more than 40 million shares. Purchases may include open-market and negotiated transactions, structured purchase arrangements, and tender offers.

In April 2008, we entered into a share repurchase program under which we prepaid $1 billion to repurchase shares of our common stock to be delivered later in 2008 in a share forward transaction. The $1 billion purchase price was recorded as a reduction in shareholders’ equity, and we received 18,416,241 shares under the program during 2008 based on a final weighted average price of $54.30 per share.

In September 2010, we entered into a share repurchase program under which we prepaid $500 million to repurchase shares of our common stock in a share forward transaction. The program was completed in March 2011 with a total of 9,574,435 shares repurchased at an average price of $52.22 per share. Our outstanding shares used to calculate earnings per share were reduced by the number of shares repurchased when they were delivered to us, and the $500 million purchase price was recorded as a reduction in shareholders’ equity upon its prepayment. We received 5,670,006 shares during the quarter ended September 30, 2010; 2,407,994 shares on October 4, 2010 and 1,496,435 shares on March 22, 2011.

These share repurchase programs are unrelated to share based compensation as described in Note 9.

NOTE 14. CALIFORNIA UTILITIES’ REGULATORY MATTERS

SDG&E POWER PROCUREMENT AND RESOURCE PLANNING

Background—Electric Industry Regulation

California’s legislative response to the 2000 – 2001 energy crisis resulted in the DWR purchasing a substantial portion of power for California’s electricity users. In 2001, the DWR entered into long-term contracts with suppliers, including Sempra Natural Gas, to provide power for the utility procurement customers of each of the California investor-owned utilities (IOUs), including SDG&E. The CPUC allocates the power and its administrative responsibility, including collection of power contract costs from utility customers, among the IOUs.

Effective in 2003, the IOUs resumed responsibility for electric commodity procurement above their allocated share of the DWR’s long-term contracts, and the CPUC:

§	directed the IOUs, including SDG&E, to resume electric commodity procurement to cover their net short energy requirements, which are the total customer energy requirements minus supply from resources owned, operated or contracted;

§	implemented legislation regarding procurement and renewable energy portfolio standards; and

§	established a process for review and approval of the utilities’ long-term resource and procurement plans.

This process is intended to identify anticipated needs for generation and transmission resources in order to support transmission grid reliability and to better serve customers.

Renewable Energy

In 2010, the State of California required certain California electric retail sellers, including SDG&E, to deliver 20 percent of their retail energy sales from renewable energy sources. The rules governing this requirement, administered by both the CPUC and the California Energy Commission (CEC), are known as the Renewables Portfolio Standard (RPS) Program. In December 2011, California Senate Bill 2(1X) (33% RPS Program) went into effect, superseding the previous RPS Program. It requires each California utility to procure 33 percent of its annual electric energy requirements from renewable energy sources by 2020, with an average of 20 percent required from January 1, 2011 to December 31, 2013; 25 percent by December 31, 2016; and 33 percent by December 31, 2020. The CPUC began a rulemaking in May 2011 to address the implementation of the 33% RPS Program.

The 33% RPS Program contains new flexible compliance mechanisms, more restrictive than the prior mechanisms, that can be used to comply with or meet the 33% RPS Program mandates in 2011 and beyond. The new mechanisms provide for a CPUC waiver under certain conditions, including: 1) a finding of inadequate transmission, 2) delays in the start-up of commercial operations of renewable energy projects due to permitting or interconnection or 3) unexpected curtailment by an electric system balancing authority, such as the California Independent System Operator (ISO).

SDG&E continues to procure renewable energy supplies to achieve the 33% RPS Program requirements. A substantial number of these supply contracts, however, are contingent upon many factors, including:

§	access to electric transmission infrastructure;

§	timely regulatory approval of contracted renewable energy projects;

§	the renewable energy project developers’ ability to obtain project financing and permitting; and

§	successful development and implementation of the renewable energy technologies.

For 2010, SDG&E satisfied its RPS procurement requirements through a combination of contracted deliveries and application of the flexible compliance mechanism, including the application of certain mechanisms that are no longer available under the 33% RPS Program. For 2011 and beyond, SDG&E believes it will be able to comply with the 33% RPS Program requirements based on its contracting activity and, if necessary, application of the new flexible compliance mechanisms. SDG&E’s failure to comply with the RPS Program requirements could subject it to a CPUC-imposed penalty of 5 cents per kilowatt hour of renewable energy under-delivery.

SDG&E Purchase of El Dorado

SDG&E purchased Sempra Natural Gas’ El Dorado natural gas generation plant on October 1, 2011, pursuant to an option to acquire the plant that was exercised in 2007. In accordance with the CPUC’s approval, SDG&E acquired El Dorado (now named Desert Star Energy Center) at a price equal to the closing book value of the plant upon transfer. SDG&E made a compliance filing with the CPUC in September 2011 stating the book value purchase price as $215 million. The final purchase price was $214 million based on the completion of an independent audit of Sempra Natural Gas’ net book value of the plant as of the close of business on September 30, 2011.

East County Substation

In response to a CPUC application filed by SDG&E for authorization to proceed with the East County Substation project, the CPUC and Bureau of Land Management jointly issued a favorable final environmental impact report and environmental impact statement in October 2011. The project, which will include construction of a new 500/230/138- kilovolt (kV) substation, rebuilding of the existing Boulevard Substation and construction of a new 138-kV transmission line connecting the two substations, is estimated to cost approximately $435 million. It would allow interconnections from new renewable-generation sources and enhance the reliability of electric service to a number of communities. We expect a CPUC decision on this project in the first half of 2012.

San Onofre Nuclear Generating Station (SONGS)

Edison (78.21%), SDG&E (20%) and the city of Riverside (1.79%) jointly own SONGS. Edison completed the replacement of the steam generators at San Onofre Units 2 and 3 in April 2010 and February 2011, respectively. The final phase of the project, disposal of the old steam generators, is planned to be completed in 2012. SDG&E’s share of the capital investment in this project is $180 million, including $160 million incurred through December 31, 2011. The CPUC approved SDG&E’s participation in the replacement project. SDG&E has requested continuation of full recovery of current operating and maintenance costs via balancing account treatment in its 2012 General Rate Case application, discussed below.

GENERAL RATE CASE (GRC)

The CPUC uses a general rate case proceeding to prospectively set rates sufficient to allow the California Utilities to recover their reasonable cost of operations and maintenance and to provide the opportunity to realize their authorized rates of return on their investment. In December 2010, the California Utilities filed their 2012 General Rate Case (GRC) applications to establish their authorized 2012 revenue requirements and the ratemaking mechanisms by which those requirements will change on an annual basis over the subsequent three-year (2013-2015) period. Both SDG&E and SoCalGas filed revised applications with the CPUC in July 2011. Evidentiary hearings were completed in January 2012 and final briefs reflecting the results from these hearings are scheduled to be filed with the CPUC by May 1, 2012. The final decision for the 2012 GRC will be made effective retroactive to January 1, 2012.

In February 2012, the California Utilities filed amendments to update their July 2011 revised applications. With these amendments, SDG&E is requesting a revenue requirement in 2012 of $1.849 billion, an increase of $235 million (or 14.6%) over 2011. SoCalGas is requesting a revenue requirement in 2012 of $2.112 billion, an increase of $268 million (14.5%) over 2011. The Division of Ratepayer Advocates and other intervening parties are recommending that the CPUC reduce the utilities’ revenue requirements in 2012 by approximately 5 percent compared to 2011.

UTILITY INCENTIVE MECHANISMS

The CPUC applies performance-based measures and incentive mechanisms to all California IOUs. Under these, the California Utilities have earnings potential above authorized base margins if they achieve or exceed specific performance and operating goals. Generally, for performance-based awards, if performance is above or below specific benchmarks, the utility is eligible for financial awards or subject to financial penalties. Both SDG&E and SoCalGas have incentive mechanisms associated with:

§	operational incentives

§	energy efficiency/demand side management

SoCalGas has additional incentive mechanisms associated with:

§	natural gas procurement

§	unbundled natural gas storage and system operator hub services

Incentive awards are included in our earnings when we receive any required CPUC approval of the award. We would record penalties for results below the specified benchmarks in earnings when we believe it is more likely than not that the CPUC would assess a penalty.

We provide a summary of the incentive awards recognized below.

UTILITY INCENTIVE AWARDS 2009-2011
(Dollars in millions)
	Years ended December 31,
	2011		2010		2009
Sempra Energy Consolidated
Energy efficiency and demand side management	$	16	$	15	$	2
Unbundled natural gas storage and hub services		4		15		19
Natural gas procurement		6		12		7
Operational incentives		3		1		1
Total awards	$	29	$	43	$	29
SDG&E
Energy efficiency and demand side management	$	14	$	5	$	―
Operational incentives		1		1		1
Total awards	$	15	$	6	$	1
SoCalGas
Energy efficiency and demand side management	$	2	$	10	$	2
Unbundled natural gas storage and hub services		4		15		19
Natural gas procurement		6		12		7
Operational incentives		2		―		―
Total awards	$	14	$	37	$	28

Energy Efficiency and Demand Side Management

The CPUC established incentive mechanisms that are based on the effectiveness of energy efficiency and demand side management programs. In December 2009, the CPUC awarded $0.3 million and $2.1 million to SDG&E and SoCalGas, respectively, for their performance during the 2006 – 2008 program period. In February 2010, the California Utilities filed a petition with the CPUC to correct errors in the computation of these awards. In December 2010, the CPUC additionally awarded $5.1 million and $9.9 million to SDG&E and SoCalGas, respectively, as the final true-up incentive awards for the 2006 – 2008 program period, which amounts incorporate the California Utilities’ petition to correct computational errors.

In December 2011, the CPUC awarded $13.7 million to SDG&E and $2.0 million to SoCalGas for their 2009 program year results.

The CPUC has not yet established a schedule for reviewing and approving incentive awards for the 2010 – 2012 program period. The CPUC is also considering modifications to the incentive mechanism that would apply to future program periods (2013 and beyond), but has not established a schedule for a decision.

Natural Gas Procurement

The California Utilities procure natural gas on behalf of their core natural gas customers. The CPUC has established incentive mechanisms to allow the California Utilities the opportunity to share in the savings and/or costs from buying natural gas for their core customers at prices below or above monthly market-based benchmarks. In 2008, the SDG&E and SoCalGas core natural gas supply portfolios were combined, and SoCalGas now procures natural gas for SDG&E’s core natural gas customers’ requirements. All SDG&E assets associated with its core natural gas supply portfolio were transferred or assigned to SoCalGas. Accordingly, SDG&E’s incentive mechanism for natural gas procurement awards or penalties ended as of the effective date of the combination of the core natural gas supply portfolios, and SoCalGas’ gas cost incentive mechanism (GCIM) is applied on the combined portfolio basis going forward.

In September 2011, the CPUC approved SoCalGas’ application for its GCIM award of $6 million for natural gas procured for its core customers during the 12-month period ending March 31, 2010.

In June 2011, SoCalGas applied to the CPUC for approval of a GCIM award of $6.2 million for natural gas procured for its core customers during the 12-month period ending March 31, 2011. SoCalGas expects a CPUC decision in the first half of 2012.

In January 2010, the CPUC approved a GCIM award of $12 million for SoCalGas’ procurement activities during the 12-month period ending March 31, 2009.

Unbundled Natural Gas Storage and System Operator Hub Services

The CPUC has established a revenue sharing mechanism which provides for the sharing between ratepayers and SoCalGas (shareholders) of the net revenues generated by SoCalGas’ unbundled natural gas storage and system operator hub services. Annual net revenues (revenues less allocated service costs) are shared on a graduated basis, as follows:

§	the first $15 million of net revenue to be shared 90 percent ratepayers/10 percent shareholders;

§	the next $15 million of net revenue to be shared 75 percent ratepayers/25 percent shareholders;

§	all additional net revenues to be shared evenly between ratepayers and shareholders; and

§	the maximum total annual shareholder-allocated portion of the net revenues cannot exceed $20 million.

Operational Incentives

The CPUC may establish operational incentives and associated performance benchmarks as part of a general rate case or cost of service proceeding. Through the end of 2011, the California Utilities had operational incentives that applied to their performance in the area of employee safety.

COST OF CAPITAL

A cost of capital proceeding determines a utility’s authorized capital structure and authorized rate of return on rate base (ROR), which is a weighted average of the authorized returns on debt, preferred stock, and common equity (return on equity or ROE). The authorized rate of return is the rate that the California Utilities may earn on their electric and natural gas distribution, natural gas transmission and electric generation assets. In addition, a cost of capital proceeding also addresses market-based benchmarks to be monitored to determine whether an adjustment to the established authorized rate of return is required during the interim years between proceedings through the approved adjustment mechanism.

SDG&E’s authorized ROE is 11.10 percent and its authorized ROR is 8.40 percent. SDG&E’s current authorized capital structure is

§	49.0 percent common equity

§	5.75 percent preferred equity

§	45.25 percent long-term debt

Unless the benchmark interest rates, as described below, change from current levels, the authorized ROE and ROR will remain in effect until SDG&E’s next cost of capital proceeding is completed. SDG&E’s next cost of capital application is scheduled to be filed in April 2012 for a 2013 test year, consistent with the schedule for cost of capital applications for each of Edison and Pacific Gas and Electric Company (PG&E).

SoCalGas’ authorized ROE is 10.82 percent and its authorized ROR is 8.68 percent. These rates continue to be effective until market interest rate changes are large enough to trigger an automatic adjustment or until either the CPUC orders a periodic review or SoCalGas files a cost of capital application. In its 2012 GRC application, SoCalGas advised the CPUC that it plans to file a cost of capital application in April 2012 for a 2013 test year, at the same time as the other California IOUs. SoCalGas’ current authorized capital structure is

§	48.0 percent common equity

§	6.39 percent preferred equity

§	45.61 percent long-term debt

In addition to establishing the authorized ROR, a cost of capital proceeding also addresses market-based benchmarks to be monitored to determine whether an adjustment to the established authorized rate of return is required during the interim years between cost of capital proceedings. SDG&E’s cost of capital benchmark is based on the 12-month average monthly A-rated utility bond yield as published by Moody’s for the 12-month period October through September of each fiscal year. If this 12-month average falls outside of the range of 5.02 percent to 7.02 percent, SDG&E’s authorized rate of return would be adjusted, upward or downward, by one-half of the difference between the 12-month average and 6.02 percent (SDG&E’s benchmark interest rate), effective January 1 following the year in which the benchmark range was exceeded. In the event of such an event occurring, the benchmark interest rate would be reset to the interest rate in effect at the time it was determined that the benchmark range had been exceeded.

SoCalGas’ cost of capital trigger mechanism (the Market Indexed Capital Adjustment Mechanism or MICAM) identifies two conditions for determining whether a change in the authorized rate of return is required. Both conditions are based on the 30-year Treasury bond yields – one being the most recent trailing 12-month rolling average yield and the second being the corresponding 12-month forward forecast yield as published by Global Insight. If both conditions fall outside a range of 3.88 percent (MICAM floor) to 6.88 percent (MICAM ceiling) in a given month, SoCalGas’ authorized ROE would be adjusted, upward or downward, by one-half of the difference between the trailing 12-month rolling average yield and 5.38 percent (SoCalGas’ MICAM benchmark interest rate), effective January 1 following the year in which both conditions were exceeded. Also, SoCalGas’ authorized recovery rate for the cost of debt and preferred stock would be adjusted to their actual weighted average cost. Therefore, SoCalGas’ authorized ROR would adjust, upward or downward, as a result of all three cost adjustments. In the event of such an event occurring, the benchmark interest rate would be reset to the interest rate in effect at the time it was determined that the benchmark range had been exceeded.

At December 31, 2011, neither SDG&E’s nor SoCalGas’ benchmark range has been exceeded. As of January 31, 2012, the historical rolling average yield for the 30-year Treasury bonds of 3.79 percent fell below the MICAM floor of 3.88 percent. In addition, the Global Insight 12-month forward forecasted yield of 3.48 percent published in early February 2012 is also below the MICAM floor. Therefore, SoCalGas’ MICAM mechanism calls for an adjustment of its ROE and authorized recovery for the cost of debt and preferred stock to their actual weighted average cost to be effective on January 1, 2013. However, as SoCalGas has advised the CPUC of its plan to file a cost of capital application in April 2012 along with the other California IOUs, SoCalGas expects that the decision from this cost of capital application will supersede the rates that would result from the MICAM trigger. As there haven’t been any objections raised to SoCalGas’ proposal to file a cost of capital application, management believes that the CPUC will accept SoCalGas’ application. Absent a SoCalGas cost of capital application and proceeding, SoCalGas’ ROE would be reduced to 10.02 percent effective January 1, 2013, a reduction of 80 basis points from its current authorized ROE, and its authorized ROR would be reduced to 8.05 percent, a reduction of 63 basis points from its current authorized ROR.

ADVANCED METERING INFRASTRUCTURE

SDG&E

SDG&E’s project to install advanced meters with integrated two-way communications functionality, including electric remote disconnect and home area network capability, was substantially completed by the end of 2011.

SoCalGas

In April 2010, the CPUC issued a decision approving SoCalGas’ application to upgrade approximately six million natural gas meters with an advanced metering infrastructure (AMI), subject to certain safeguards to better ensure its cost effectiveness for ratepayers. The approved cost of the project is $1.05 billion (including approximately $900 million in capital investment), with SoCalGas being subject to risk/reward sharing for costs above or below this amount. Installation of the meters is expected to begin in early 2013 and continue through mid 2017.

In November 2011, the Division of Ratepayer Advocates (DRA) and The Utility Reform Network (TURN) filed a joint petition requesting that the CPUC reconsider its prior approval of SoCalGas’ AMI project and stay AMI deployment while the CPUC considers the request. The CPUC has taken no action in response to the DRA/TURN request, and SoCalGas is continuing its deployment of AMI pursuant to the April 2010 CPUC decision.

SDG&E REQUEST FOR AUTHORITY TO INVEST IN WIND FARM

In July 2011, the CPUC approved a settlement agreement regarding SDG&E’s request to make a tax equity investment in the holding company of a wind farm project. In December 2011, the Federal Energy Regulatory Commission (FERC) approved SDG&E’s involvement in the project and the associated power purchase agreement. These approvals allow SDG&E to make an investment after the wind farm project has met all of the conditions precedent set forth in the definitive documents and upon the initiation of commercial operation of the project. The approved investment, which would be included in the utility’s rate base, is the lesser of $250 million or 64.99 percent of the project’s costs. SDG&E would also make an incremental investment, to be excluded from the utility’s rate base, of no less than 10 percent of the project’s costs. SDG&E expects the project to be in commercial operation in late 2012.

2007 WILDFIRES COST RECOVERY FOR RESTORATION OF COMPANY FACILITIES

In October 2010, the CPUC issued a decision approving a settlement agreement between SDG&E and the DRA, authorizing SDG&E to recover $43 million of capital costs incurred to replace and repair company facilities under CPUC jurisdiction damaged by the October 2007 wildfires. This decision was in response to an application that SDG&E filed with the CPUC in March 2009 seeking to recover $49.8 million of incremental costs ($43 million of capital costs and $6.8 million of operation and maintenance costs).

SDG&E also incurred $30.1 million of incremental costs for the replacement and repair of company facilities under FERC jurisdiction, which are currently being recovered in SDG&E’s electric transmission rates.

We discuss recovery of 2007 wildfire litigation costs in Note 15.

INCREMENTAL INSURANCE PREMIUM COST RECOVERY

In December 2010, the CPUC approved SDG&E’s request for a $29 million revenue requirement for the recovery of the incremental increase in its general liability and wildfire liability insurance premium costs for the 2009/2010 policy period. In its decision approving this cost recovery, the CPUC also authorized SDG&E to request recovery of any incremental insurance premiums for future policy periods through December 31, 2011, with a $5 million deductible applied to each policy renewal period. This approval was in response to a request filed by SDG&E with the CPUC in August 2009 seeking authorization to recover higher liability insurance premiums (amounts in excess of those authorized to be recovered in the 2008 GRC), which SDG&E began incurring commencing July 1, 2009, and any losses realized due to higher deductibles associated with the new policies. SDG&E made the filing under the CPUC’s rules allowing utilities to seek recovery of significant cost increases incurred between GRC filings resulting from unforeseen circumstances. The CPUC’s rules allow a utility to seek recovery of incurred costs that meet certain criteria, subject to a $5 million deductible per event.

In December 2011, the CPUC approved SDG&E’s request for an incremental revenue requirement of $63 million for the 2010/2011 policy period. SDG&E recorded the revenue resulting from this decision in the fourth quarter of 2011. In addition, SDG&E’s fourth quarter 2011 earnings include revenue to recover $28 million of incremental insurance premiums incurred in the six month period of July through December 2011 for which a final decision from the CPUC is pending. We expect a CPUC decision on this request in the second quarter of 2012.

EXCESS WILDFIRE CLAIMS COST RECOVERY

SDG&E and SoCalGas filed an application, along with other related filings, with the CPUC in August 2009 proposing a new mechanism for the future recovery of all wildfire-related expenses for claims, litigation expenses and insurance premiums that are in excess of amounts authorized by the CPUC for recovery in rates. This application was made jointly with Edison and PG&E. In July 2010, the CPUC approved SDG&E’s and SoCalGas’ requests for separate regulatory memorandum accounts to record the subject expenses while the application is pending before the CPUC. Several parties protested the original application and, in response, the four utilities jointly submitted an amended application in August 2010. A February 2011 ruling directing the utilities to show cause why the application should not be dismissed was stayed to permit continued settlement discussions between the four utilities and the CPUC and with the other parties to the proceeding. In June 2011, the CPUC issued a ruling scheduling evidentiary hearings in October with a decision in 2012. In September 2011, the CPUC delayed hearings to January 2012. In November 2011, Edison and PG&E requested to withdraw from the joint utility application due, in part, to the delays in the proceeding. In January 2012, the CPUC granted their requests to withdraw and held evidentiary hearings for SDG&E and SoCalGas, both of which are still moving forward with the application. We expect a CPUC decision in the second half of 2012.

SDG&E intends to request recovery for costs incurred associated with the 2007 wildfires that are in excess of amounts recovered from its insurance coverage and other responsible third parties in a future application. If a cost recovery mechanism covering the 2007 wildfire costs is approved by the CPUC as a result of these proceedings, SDG&E intends to utilize the methodology authorized. Otherwise, SDG&E will file an application for cost recovery utilizing other cost recovery application processes available through the CPUC.

We provide additional information about 2007 wildfire litigation costs and their recovery in Note 15.

NATURAL GAS PIPELINE OPERATIONS SAFETY ASSESSMENTS

As a result of recent natural gas pipeline explosions in the U.S., including the September 2010 rupture in San Bruno, California of a natural gas pipeline owned and operated by PG&E (the San Bruno incident), various regulatory agencies, including the CPUC, are evaluating natural gas pipeline safety regulations, practices and procedures.

In February 2011, the CPUC opened a forward-looking rulemaking proceeding to examine what changes should be made to existing pipeline safety regulations for California natural gas pipelines. The California Utilities are parties to this proceeding. The CPUC also appointed an independent review panel to make recommendations for possible actions by the CPUC in light of the San Bruno incident.

The panel issued its report in June 2011 providing a number of conclusions regarding the San Bruno incident specifically, as well as general recommendations for pipeline operations and their oversight by regulatory agencies going forward.

In June 2011, the CPUC directed SoCalGas, SDG&E, PG&E and Southwest Gas to file comprehensive implementation plans to test or replace all natural gas transmission pipelines that have not been pressure tested. The California Utilities filed their Pipeline Safety Enhancement Plan (PSEP) with the CPUC in August 2011. The proposed safety measures, investments and estimated costs are not included in the California Utilities’ 2012 GRC requests discussed above. The comprehensive plan covers all of the utilities’ approximately 4,000 miles of transmission lines (3,750 miles for SoCalGas and 250 miles for SDG&E) and would be implemented in two phases:

§	Phase 1 focuses on populated areas of SoCalGas’ and SDG&E’s service territories and would be implemented over a 10-year period, from 2012 to 2022.

§	Phase 2 covers unpopulated areas of SoCalGas’ and SDG&E’s service territories and will be filed with the CPUC at a later date.

The total cost estimate for Phase 1, over the 10-year period of 2012 to 2022, is $3.1 billion ($2.5 billion for SoCalGas and $600 million for SDG&E). In their August 2011 filing, the utilities requested the CPUC to authorize funding for the recovery of costs through 2015 of approximately $1.5 billion for SoCalGas, of which $1.2 billion would be capital investment, and $240 million for SDG&E, of which $230 million would be capital investment. After 2015, the utilities proposed to include the costs of the PSEP in their next General Rate Case (for their authorized revenue requirements in 2016). The utilities also proposed that the cost of the program be recovered through a surcharge, rather than by incorporating it into rates. The surcharge would increase over time, as more project work is completed.

In December 2011, the assigned Commissioner to the rulemaking proceeding for the pipeline safety regulations ruled that SDG&E’s and SoCalGas’ Triennial Cost Allocation Proceeding (TCAP) would be the most logical proceeding to conduct the reasonableness and ratemaking review of the companies’ PSEP. In the TCAP, SDG&E and SoCalGas will, among other things, seek to: (1) establish and revise gas rates to reflect updated customer class allocations of each company’s respective base margin costs authorized in the most recent GRC; (2) update demand forecasts; and (3) support continuation of balancing account treatment for noncore transportation revenue requirements. In February 2012, the assigned Commissioner to the TCAP issued a scoping memo for the companies’ TCAP, including their PSEP. This scoping memo sets evidentiary hearings for the first phase of the TCAP, which addresses the scope and reasonableness of the PSEP, in the third quarter of 2012, with briefs scheduled to be filed early in the fourth quarter of 2012.

On January 17, 2012, the CPUC Consumer Protection and Safety Division (CPSD) issued a Technical Report of the California Utilities’ PSEP. The report, along with testimony and evidentiary hearings, will be used to evaluate the PSEP in the regulatory process (once a schedule is established). Generally, the report found that the PSEP approach to pipeline replacement and pressure testing and other proposed enhancements is reasonable.

In January 2011, the National Transportation Safety Board (NTSB) issued seven safety recommendations in connection with its investigation into the cause of the San Bruno incident. According to the NTSB, these safety recommendations “were issued to address record-keeping problems that could create conditions in which a pipeline is operated at a higher pressure than the pipe was built to withstand.” In response to a request from the CPUC, each of the California Utilities reviewed its pipeline facilities located or operating in populated or high consequence areas, as defined by the NTSB, to identify those segments that have not had the maximum allowable operating pressure (MAOP) established through prior hydrostatic testing. Federal and state regulations allow natural gas pipelines installed prior to July 1, 1970 to establish MAOPs through prior operating history rather than through a strength test, but strength tests are required on natural gas pipelines installed subsequent to June 30, 1970 as an element in establishing MAOPs.

In response to the CPUC’s request, the California Utilities conducted a detailed review of 1,622 miles of pipelines (1,416 miles for SoCalGas and 206 miles for SDG&E) installed in the subject class locations, and on April 15, 2011, the California Utilities submitted a report to the CPUC on the results of their review and the actions they are taking in response to the NTSB recommendations.

The California Utilities’ records review process did not reveal any significant concerns with the currently established MAOP for their pipelines, and the California Utilities intend to continue to operate their pipelines in a safe and prudent manner.

NATURAL GAS PIPELINE SAFETY LEGISLATION

In October 2011, the California legislature enacted five separate legislative bills (SB44, SB216, SB705, SB879 and AB56) that address natural gas pipeline safety. Each bill addresses a different aspect of natural gas pipeline safety and imposes requirements on the CPUC and the natural gas pipeline operator. These include such things as the development of a safety plan; installation of automatic shut-off and remote controlled gas valves; emergency response; reporting; ratemaking; and increasing the maximum penalty for gas pipeline safety violations. Much of the legislation is addressed by the utility safety plans being reviewed by the CPUC, and the California Utilities do not expect that the legislation will have a material impact on their results of operations, financial condition or cash flows.

AIR QUALITY AND GREENHOUSE GAS REGULATION

The California Legislature enacted Assembly Bill 32 (AB 32) and California Senate Bill 1368 in 2006. These laws mandate, among other things, reductions in greenhouse gas (GHG) emissions and the payment of GHG administration fees annually. The California Air Resources Board (CARB), the agency responsible for establishing the compliance rules and regulations for the regulation of GHG under AB 32, has adopted a number of regulations pursuant to AB 32, including CARB’s GHG administration fees regulation and its GHG emissions trading regulation.

On October 20, 2011, the CARB finalized details of the cap and trade regulation authorized by AB 32. CARB intends to implement its cap and trade program in 2013. Certain legal challenges have been raised regarding the implementation of cap and trade (Associations of Irritated Residents, et al. v. California Air Resources Board). In September 2011, the California Supreme Court declined to immediately halt implementation of the CARB’s cap and trade program. The Supreme Court’s decision was limited only to a stay application before the California Court of Appeals, and was not a ruling on the merits of the legal challenges against cap and trade, which is still subject to appeal. No injunction has been issued by any court delaying adoption of the cap and trade program and it is currently proceeding.

These legislative and regulatory mandates could affect costs and growth at the California Utilities and at our natural gas-fired power plants in Arizona and Mexico. Any cost impact at the California Utilities is expected to be recoverable through rates. As discussed in Note 15 under “Environmental Issues,” compliance with this and similar legislation could adversely affect our Sempra Natural Gas and Sempra Mexico segments. However, such legislation could also have a positive impact on our natural gas and renewables businesses because of an increasing preference for natural gas and renewables for electric generation, as opposed to other sources.

NOTE 15. COMMITMENTS AND CONTINGENCIES

LEGAL PROCEEDINGS

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

At December 31, 2011, Sempra Energy’s accrued liabilities for material legal proceedings, on a consolidated basis, were $625 million. At December 31, 2011, accrued liabilities for material legal proceedings for SDG&E and SoCalGas were $596 million and $18 million, respectively. At December 31, 2011, liabilities of $596 million at Sempra Energy and SDG&E were related to wildfire litigation discussed below.

SDG&E

2007 Wildfire Litigation

In October 2007, San Diego County experienced several catastrophic wildfires. Reports issued by the California Department of Forestry and Fire Protection (Cal Fire) concluded that two of these fires (the Witch and Rice fires) were SDG&E “power line caused” and that a third fire (the Guejito fire) occurred when a wire securing a Cox Communications’ (Cox) fiber optic cable came into contact with an SDG&E power line “causing an arc and starting the fire.” Cal Fire reported that the Rice fire burned approximately 9,500 acres and damaged 206 homes and two commercial properties, and the Witch and Guejito fires merged and eventually burned approximately 198,000 acres, resulting in two fatalities, approximately 40 firefighters injured and approximately 1,141 homes destroyed.

A September 2008 staff report issued by the CPUC’s CPSD reached substantially the same conclusions as the Cal Fire reports, but also contended that the power lines involved in the Witch and Rice fires and the lashing wire involved in the Guejito fire were not properly designed, constructed and maintained. In April 2010, proceedings initiated by the CPUC to determine if any of its rules were violated were settled with SDG&E’s payment of $14.75 million.

Numerous parties have sued SDG&E and Sempra Energy in San Diego County Superior Court seeking recovery of unspecified amounts of damages, including punitive damages, from the three fires. These include owners and insurers of properties that were destroyed or damaged in the fires and public entities seeking recovery of firefighting, emergency response, and environmental costs. They assert various bases for recovery, including inverse condemnation based upon a California Court of Appeal decision finding that another California investor-owned utility was subject to strict liability, without regard to foreseeability or negligence, for property damages resulting from a wildfire ignited by power lines.

In October 2010, the Court of Appeal affirmed the trial court’s ruling that these claims must be pursued in individual lawsuits, rather than as class actions on behalf of all persons who incurred wildfire damages. In February 2011, the California Supreme Court denied a petition for review of the affirmance. The trial court has scheduled a Witch fire and Guejito fire trial to begin in March 2013.

SDG&E filed cross-complaints against Cox seeking indemnification for any liability that SDG&E might incur in connection with the Guejito fire, two SDG&E contractors seeking indemnification in connection with the Witch fire, and one SDG&E contractor seeking indemnification in connection with the Rice fire.

In December 2010, SDG&E and Cox reached an agreement settling SDG&E’s claims against Cox and Cox’s insurers in the wildfire litigation (Cox Settlement). Among other things, the settlement agreement provided that SDG&E receive approximately $444 million for wildfire related expenditures, and SDG&E will defend and indemnify Cox against all compensatory damage claims and related costs arising out of the wildfires.

At December 31, 2010, the $300 million Settlement Receivable Related to Wildfire Litigation on the Consolidated Balance Sheets of Sempra Energy and SDG&E represented cash to be received in accordance with the terms of the Cox Settlement in several payments through March 2011 and which was received. As of December 31, 2011, there was no wildfire-related restricted cash on the Consolidated Balance Sheets of Sempra Energy and SDG&E as all amounts received from Cox had been applied to wildfire related expenditures.

SDG&E has settled all of the approximately 19,000 claims brought by homeowner insurers for damage to insured property relating to the three fires. Under the settlement agreements, SDG&E has paid or will pay 57.5 percent of the approximately $1.6 billion paid or reserved for payment by the insurers to their policyholders and received an assignment of the insurers’ claims against other parties potentially responsible for the fires.

The wildfire litigation also includes claims of non-insurer plaintiffs for damage to uninsured and underinsured structures, business interruption, evacuation expenses, agricultural damage, emotional harm, personal injuries and other losses. SDG&E has settled the claims of approximately 2,750 of these plaintiffs. Approximately 650 of the approximately 1,650 remaining individual and business plaintiffs have submitted settlement demands and damage estimates totaling approximately $750 million and government entity claims totaling approximately $80 million. SDG&E expects to receive additional settlement demands and damage estimates as settlement negotiations continue. SDG&E has established reserves for the wildfire litigation as we discuss below.

SDG&E’s settled claims and defense costs have exceeded its $1.1 billion of liability insurance coverage and the $444 million it received from Cox. It expects that its wildfire reserves and amounts paid to resolve wildfire claims will continue to increase as it obtains additional information; it is presently unable to reasonably estimate the amount or timing of recoveries from other potentially responsible parties.

SDG&E has concluded, however, that it is probable that it will be permitted to recover from its utility customers substantially all reasonably incurred costs of resolving wildfire claims in excess of its liability insurance coverage and any amounts recovered from other potentially responsible parties. Accordingly, although such recovery will require future regulatory actions, at December 31, 2011 and December 31, 2010, SDG&E recorded a regulatory asset of $594 million and $364 million, respectively, which represents the amount substantially equal to the aggregate amount it has paid or reserved for payment for the resolution of wildfire claims and related costs in excess of its liability insurance coverage and amounts received from Cox. SDG&E will increase the regulatory asset as additional amounts are paid or reserves are recorded and reduce it by any amounts recovered from other potentially responsible parties.

As a consequence of the expected recovery of wildfire costs from utility customers, Sempra Energy and SDG&E expect no significant earnings impact from the resolution of the remaining wildfire claims. However, SDG&E’s cash flow may be materially adversely affected due to the timing differences between the resolution of claims and the recoveries from other potentially responsible parties and utility customers, which may extend over a number of years. Also, recovery from customers will require future regulatory actions, and a failure to obtain substantial or full recovery, or any negative assessment of the likelihood of recovery, would likely have a material adverse effect on Sempra Energy’s and SDG&E’s financial position, cash flows and results of operations.

SDG&E will continue to gather information to evaluate and assess the remaining wildfire claims and the likelihood, amount and timing of related recoveries from other potentially responsible parties and utility customers and will make appropriate adjustments to wildfire reserves and the related regulatory asset as additional information becomes available.

In 2010 and 2011, as liabilities for wildfire litigation have become reasonably estimable in the form of settlement demands, damage estimates, and other damage information, SDG&E has recorded related reserves as a liability. The impact of this liability at December 31, 2011 is offset by the recognition of a regulatory asset, as discussed above, for reserves in excess of the insurance coverage and the Cox Settlement. The impact of the reserves on SDG&E’s and Sempra Energy’s after-tax earnings was $13 million and $20 million for the years ended December 31, 2011 and 2010, respectively. There was no effect on SDG&E’s or Sempra Energy’s 2009 earnings from the recording of the reserves. At December 31, 2011, wildfire litigation reserves were $596 million ($586 million in current and $10 million in long-term).

Sunrise Powerlink Electric Transmission Line

SDG&E commenced construction on the Sunrise Powerlink in the fall of 2010. The Sunrise Powerlink is a new 117-mile, 500-kV electric transmission line that is being built between the Imperial Valley and the San Diego region, along a route that generally runs south of the Anza-Borrego Desert State Park. The current project plan provides for the transmission line to be completed and in-service in the second half of 2012.

The Sunrise Powerlink project was originally approved by the CPUC in December 2008, including approval of the environmental impact review conducted jointly with the Bureau of Land Management (BLM). The CPUC has subsequently denied or dismissed all requests for rehearing of its approval of the project.

In February 2011, the California Supreme Court denied a petition filed jointly by the Utility Consumers’ Action Network (UCAN) and the Center for Biological Diversity/Sierra Club (CBD). The petition challenged the CPUC’s decision with regard to implementation of the California Environmental Quality Act (CEQA). In addition, in August 2010, the California Court of Appeal denied a petition previously filed by UCAN with the Court of Appeal challenging the CPUC decision on other legal grounds.

In January 2009, the BLM issued its decision approving the portions of the project, route and environmental review within its jurisdiction. The Interior Board of Land Appeals (IBLA) subsequently denied or dismissed all administrative appeals that were filed challenging the BLM’s approval of the project.

The CPUC and BLM jointly approved the final Project Modification Report for Sunrise Powerlink in September 2010, accepting all of the proposed modifications to the approved route and finding that no additional environmental review was required. In December 2010, the IBLA dismissed an appeal challenging the BLM’s approval of the Project Modification Report. In March 2011, opponents of the Sunrise Powerlink filed a petition for writ of review or mandamus with the California Supreme Court challenging the CPUC’s acceptance of the Project Modification Report. The California Supreme Court denied the petition in April 2011.

In February 2010, parties opposed to the project filed a lawsuit in Federal District Court in San Diego seeking declaratory and injunctive relief and alleging that the BLM failed to properly address the environmental impacts of the approved Sunrise Powerlink route and the related potential development of renewable resources in east San Diego County and Imperial County. In June 2011, the court granted the defendants’ motion for summary judgment on the grounds that the plaintiffs were not challenging final government agency actions. The plaintiffs have appealed to the U.S. Court of Appeals for the Ninth Circuit.

In July 2010, the United States Forest Service (USFS) issued its decision approving the portions of the project, route and environmental review within its jurisdiction. The USFS has subsequently denied all administrative appeals challenging its approval of the project.

In January 2011, project opponents filed a lawsuit in Federal District Court in San Diego alleging that the federal approvals for construction of the project on USFS land and BLM land violated the National Environmental Policy Act and other federal environmental laws. The lawsuit asks the court for injunctive relief preventing the USFS and the BLM from approving any ongoing or future construction activities. In October 2011, the opponents appealed the court’s denial of their motion for a preliminary injunction.

In February 2011, opponents of the Sunrise Powerlink filed a lawsuit in Sacramento County Superior Court against the State Water Resources Control Board and SDG&E alleging that the water quality certification issued by the Board under the Federal Clean Water Act violated CEQA. The complaint seeks to have the certification set aside and requests an injunction be issued.

September 2011 Power Outage

In September 2011, a power outage lasting approximately 12 hours affected millions of people from Mexico to southern Orange County, California. Several agencies, including the FERC and North American Electric Reliability Corp., are participating in a joint investigation to determine the cause of the power failure. Within several days of the outage, several SDG&E customers filed a class action lawsuit in Federal District Court against Arizona Public Service Company, Pinnacle West, and SDG&E alleging that the companies failed to prevent the outage. The lawsuit seeks recovery of unspecified amounts of damages, including punitive damages. In addition, more than 6,500 customers’ claims, primarily related to food spoilage, have been submitted directly to SDG&E.

Smart Meters Patent Infringement Lawsuit

In October 2011, SDG&E was sued by a Texas design and manufacturing company in Federal District Court alleging that SDG&E’s recently installed smart meters infringed certain patents. The meters were purchased from a third party vendor that has agreed to defend and indemnify SDG&E. The lawsuit seeks injunctive relief and recovery of unspecified amounts of damages.

SoCalGas

SoCalGas, along with Monsanto Co., Solutia, Inc., Pharmacia Corp., and Pfizer, Inc., are defendants in two Los Angeles County Superior Court lawsuits served in May 2011 seeking recovery of unspecified amounts of damages, including punitive damages, as a result of plaintiffs’ exposure to PCBs (polychlorinated biphenyls). The lawsuits allege plaintiffs were exposed to PCBs not only through the food chain and other various sources but from PCB-contaminated natural gas pipelines owned and operated by SoCalGas. This contamination allegedly caused plaintiffs to develop cancer and other serious illnesses. Plaintiffs assert various bases for recovery, including negligence and products liability.

Sempra Natural Gas

Liberty Gas Storage, LLC (Liberty) received a demand for arbitration from Williams Midstream Natural Gas Liquids, Inc. (Williams) in February 2011 related to a sublease agreement. Williams alleges that Liberty was negligent in its attempt to convert certain salt caverns to natural gas storage and seeks damages of $56.7 million. Liberty filed a counterclaim alleging breach of contract in the inducement and seeks damages of more than $215 million.

Sempra Mexico

Sempra Mexico has been engaged in a long-running land dispute relating to property adjacent to its Energía Costa Azul liquefied natural gas (LNG) terminal near Ensenada, Mexico. The adjacent property is not required by environmental or other regulatory permits for the operation of the terminal. A claimant to the adjacent property has nonetheless asserted that his health and safety are endangered by the operation of the facility. In June 2010, a Mexican federal appeals court revoked a district court order, issued at the behest of the claimant, directing Mexican regulatory authorities to provisionally suspend authorizations for the operation of the LNG terminal. In February 2011, based on a complaint by the claimant, the new Ensenada Mayor attempted to temporarily close the terminal based on claims of irregularities in municipal permits issued six years earlier. This attempt was promptly countermanded by Mexican federal and Baja California state authorities. No terminal permits or operations were affected as a result of these proceedings or events and the terminal has continued to operate normally.

Sempra Mexico expects additional Mexican court proceedings and governmental actions regarding the claimant’s assertions as to whether the terminal’s permits should be modified or revoked in any manner.

The property claimant also filed a lawsuit in July 2010 against Sempra Energy in Federal District Court in San Diego seeking compensatory and punitive damages as well as the earnings from the Energía Costa Azul LNG terminal based on his allegations that he was wrongfully evicted from the adjacent property and that he has been harmed by other allegedly improper actions.

Other Litigation

In August 2007, the U.S. Court of Appeals for the Ninth Circuit issued a decision reversing and remanding certain FERC orders declining to provide refunds regarding short-term bilateral sales up to one month in the Pacific Northwest for the December 2000 to June 2001 time period. In December 2010, the FERC approved a comprehensive settlement previously reached by Sempra Energy and RBS Sempra Commodities with the State of California. The settlement resolves all issues with regard to sales between the California Department of Water Resources (DWR) and Sempra Commodities in the Pacific Northwest, but potential claims may exist regarding sales between Sempra Commodities and other buyers in the Pacific Northwest. The FERC is in the process of addressing these potential claims on remand. Pursuant to the agreements related to the formation of RBS Sempra Commodities, we have indemnified RBS should the liability from the final resolution of these matters be greater than the reserves related to Sempra Commodities. Pursuant to our agreement with the Noble Group, we have also indemnified Noble Americas Gas & Power Corp. and its affiliates for all losses incurred by such parties resulting from these proceedings as related to Sempra Commodities.

Sempra Energy and several subsidiaries, along with three oil and natural gas companies, the City of Beverly Hills, and the Beverly Hills Unified School District, are defendants in toxic tort lawsuits filed beginning in 2003 in Los Angeles County Superior Court by approximately 1,000 plaintiffs. These lawsuits claim that various emissions resulted in cancer or fear of cancer. In November 2006, the court granted the defendants’ summary judgment motions based on lack of medical causation for the 12 initial plaintiffs scheduled to go to trial first. The court also granted summary judgment excluding punitive damages. The court has stayed the lawsuits as to the remaining plaintiffs pending the appeal of the rulings. A mediation occurred in June 2010, after which the plaintiffs’ counsel agreed to recommend a settlement of the lawsuits as to Sempra Energy and its subsidiaries for an amount that is not significant and has been recorded. Any such settlement will require approval by each of the plaintiffs. If approval is obtained, finalization of the settlement is expected to occur within six months.

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

Resolved Matters

We discuss certain commitments remaining from an energy crisis matter resolved prior to 2010 below under “Other Commitments.”

The following is a description of the 2010 litigation settlements relating to California energy crisis matters.

Energy Crisis Litigation Settlement

In 2010, Sempra Energy, RBS Sempra Commodities and Sempra Natural Gas reached a comprehensive settlement with the State of California to resolve substantially all of their remaining litigation arising out of the 2000 – 2001 California energy crisis for a total payment of $410 million. The matters resolved include the settlement of multiple actions brought by the DWR and other parties with respect to the validity, pricing and operation of Sempra Natural Gas’ contract with the DWR and the settlement of the FERC refund and manipulation proceedings against RBS Sempra Commodities. The FERC approved both settlements in December 2010.

The payment of $410 million was funded largely from previously recorded reserves and receivables at RBS Sempra Commodities. Sempra Energy also recorded an additional pretax charge of $159 million in the first quarter of 2010 to provide for the remainder of the settlement, including $139 million at Sempra Natural Gas and $20 million at Sempra Commodities. The amount at Sempra Commodities was reduced by $11 million pretax in the fourth quarter of 2010 to reflect a receipt in January 2011 from an unrelated party that had a joint liability for the claim. In January 2011, Sempra Natural Gas paid $130 million to the DWR under the terms of the settlement agreement.

CONTRACTUAL COMMITMENTS

Natural Gas Contracts

Natural Gas

SoCalGas has the responsibility for procuring natural gas for both SDG&E’s and SoCalGas’ core customers in a combined portfolio. SoCalGas buys natural gas under short-term and long-term contracts for this portfolio. Purchases are from various producing regions in the southwestern U.S., U.S. Rockies, and Canada and are primarily based on published monthly bid-week indices.

SoCalGas transports natural gas primarily under long-term firm interstate pipeline capacity agreements that provide for annual reservation charges, which are recovered in rates. SoCalGas has commitments with interstate pipeline companies for firm pipeline capacity under contracts that expire at various dates through 2027.

Sempra Natural Gas’ and Sempra Mexico’s businesses have various natural gas purchase agreements to fuel natural gas-fired power plants and capacity agreements for natural gas storage and transportation.

At December 31, 2011, the future minimum payments under existing natural gas contracts and natural gas storage and transportation contracts were:

Sempra Energy Consolidated
		Storage and
(Dollars in millions)		Transportation		Natural Gas(1)		Total(1)
2012		$	143	$	415	$	558
2013			106		148		254
2014			74		103		177
2015			60		3		63
2016			55		3		58
Thereafter			252		5		257
Total minimum payments		$	690	$	677	$	1,367
(1)	Excludes amounts related to LNG purchase agreements at discussed below.

SoCalGas
(Dollars in millions)	Transportation		Natural Gas		Total
2012	$	110	$	290	$	400
2013		81		19		100
2014		55		2		57
2015		41		2		43
2016		36		2		38
Thereafter		145		―		145
Total minimum payments	$	468	$	315	$	783

Total payments under natural gas contracts were:

	Years ended December 31,
(Dollars in millions)	2011		2010		2009
Sempra Energy Consolidated	$	1,991	$	2,097	$	1,754
SoCalGas		1,810		1,936		1,452

LNG

Sempra Natural Gas has various purchase agreements with major international companies for the supply of LNG to the Energía Costa Azul and Cameron terminals. The agreements range from short-term to multi-year periods and are priced using a predetermined formula based on natural gas market indices.

Although these contracts specify a number of cargoes to be delivered, under their terms, customers may divert certain cargoes, which would reduce amounts paid under the contracts by Sempra Natural Gas. As of December 31, 2011, if all cargoes under the contracts were to be delivered, future payments under these contracts would be

§	$517 million in 2012

§	$625 million in 2013

§	$689 million in 2014

§	$733 million in 2015

§	$774 million in 2016

§	$12.1 billion in 2017 – 2029

The amounts above are based on forward prices of the index applicable to each contract from 2012 to 2021 and an estimated one percent escalation per year beyond 2021. The LNG commitment amounts above are based on Sempra Natural Gas’ commitment to accept the maximum possible delivery of cargoes under the agreements. Actual LNG purchases in 2011 have been significantly lower than the maximum amount possible.

Purchased-Power Contracts

For 2012, SDG&E expects to receive 9 percent of its customer power requirements from DWR allocations. The remaining requirements are expected to be met as follows:

§	SONGS: 18 percent

§	Long-term contracts: 20 percent (of which 9 percent is provided by renewable energy contracts expiring on various dates through 2037)

§	Other SDG&E-owned generation (including Palomar, Miramar I and II, Desert Star Energy Center and Cuyamaca Peak Energy Plant) and tolling contracts (including OMEC): 40 percent

§	Spot market purchases: 13 percent

The long-term contracts expire on various dates through 2037.

Chilquinta Energía and Luz del Sur also have purchased-power contracts, with various dates extending through 2025, which cover most of the consumption needs of the companies’ customers. These commitments are included under Sempra Energy Consolidated in the table below.

At December 31, 2011, the estimated future minimum payments under long-term purchased-power contracts (not including the DWR allocations for SDG&E) were:

		Sempra
		Energy
(Dollars in millions)		Consolidated		SDG&E
2012		$	1,049	$	319
2013			1,120		321
2014			1,110		260
2015			1,164		229
2016			1,199		231
Thereafter			9,555		1,948
Total minimum payments(1)		$	15,197	$	3,308
(1)	Excludes purchase agreements accounted for as capital leases and amounts related to Otay Mesa VIE, as it is consolidated by Sempra Energy and SDG&E.

Payments on these contracts represent capacity charges and minimum energy purchases. SDG&E is required to pay additional amounts for actual purchases of energy that exceed the minimum energy commitments. Excluding DWR-allocated contracts, total payments under purchased-power contracts were:

	Years ended December 31,
(Dollars in millions)	2011		2010		2009
Sempra Energy Consolidated	$	918	$	314	$	413
Sempra South American Utilities		572		-		-
SDG&E		346		314		413

Operating Leases

Sempra Energy, SDG&E and SoCalGas have operating leases on real and personal property expiring at various dates from 2012 through 2054. Certain leases on office facilities contain escalation clauses requiring annual increases in rent ranging from two percent to six percent at both Sempra Energy and SDG&E and three percent to five percent at SoCalGas. The rentals payable under these leases may increase by a fixed amount each year or by a percentage of a base year, and most leases contain extension options that we could exercise.

The California Utilities have an operating lease agreement for future acquisitions of fleet vehicles with RBS Asset Finance, Inc. with an aggregate maximum lease limit of $125 million, $66 million of which has been utilized.

Rent expense for all operating leases totaled:

	Years ended December 31,
(Dollars in millions)	2011		2010		2009
Sempra Energy Consolidated	$	77	$	85	$	101
SDG&E		18		20		24
SoCalGas		35		40		52

At December 31, 2011, the minimum rental commitments payable in future years under all noncancelable operating leases were as follows:

	Sempra
	Energy
(Dollars in millions)	Consolidated		SDG&E		SoCalGas
2012	$	73	$	19	$	28
2013		72		18		28
2014		68		18		28
2015		65		17		28
2016		60		17		26
Thereafter		538		46		240
Total future rental commitments	$	876	$	135	$	378

Capital Leases

Utility Fleet Vehicles

The California Utilities entered into agreements with U.S. Bancorp Equipment Finance in 2009 and with RBS Asset Finance, Inc. in 2010 to refinance existing fleet vehicles. These are capital leases, and as of December 31, 2011, the related capital lease obligations were $24 million at Sempra Energy, including $13 million at SDG&E and $11 million at SoCalGas. As of December 31, 2010, the related capital lease obligations were $39 million at Sempra Energy, including $20 million at SDG&E and $19 million at SoCalGas.

At December 31, 2011, the future minimum lease payments and present value of the net minimum lease payments under these capital leases are as follows:

	Sempra
	Energy
(Dollars in millions)	Consolidated		SDG&E		SoCalGas
2012	$	13	$	7	$	6
2013		7		4		3
2014		4		2		2
Total minimum lease payments		24		13		11
Less: interest		―		―		―
Present value of net minimum lease payments	$	24	$	13	$	11

The 2011 annual amortization charge for the utility fleet vehicles was $15 million at Sempra Energy, including $7 million at SDG&E and $8 million at SoCalGas. The 2010 annual amortization charge for the utility fleet vehicles was $17 million at Sempra Energy, including $6 million at SDG&E and $11 million at SoCalGas. The 2009 annual amortization charge for the utility fleet vehicles was $3 million at Sempra Energy, including $1 million at SDG&E and $2 million at SoCalGas.

Power Purchase Agreements

SDG&E has two power purchase agreements with peaker plant facilities that went into commercial operation in June 2010 and are accounted for as capital leases. As of December 31, 2011, capital lease obligations for these leases, each with a 25-year term, were valued at $180 million.

At December 31, 2011, the future minimum lease payments and present value of the net minimum lease payments under these capital leases for both Sempra Energy Consolidated and SDG&E were as follows:

(Dollars in millions)
	2012	$	24
	2013		24
	2014		24
	2015		24
	2016		24
	Thereafter		442
	Total minimum lease payments(1)		562
	Less: estimated executory costs		(93)
	Less: interest(2)		(289)
	Present value of net minimum lease payments(3)	$	180
(1)	This amount will be recorded over the lives of the leases as Cost of Electric Fuel and Purchased Power on Sempra Energy’s and SDG&E’s Consolidated Statements of Operations. This expense will receive ratemaking treatment consistent with purchased-power costs.
(2)	Amount necessary to reduce net minimum lease payments to present value at the inception of the leases.
(3)	Includes $2 million in Current Portion of Long-Term Debt and $178 million in Long-Term Debt on Sempra Energy’s and SDG&E’s Consolidated Balance Sheets at December 31, 2011.

The annual amortization charge for the power purchase agreements was $2 million for 2011 and $1 million for 2010.

Construction and Development Projects

Sempra Energy has various capital projects in progress in the United States, Mexico and South America. The following is a summary of contractual commitments and contingencies related to the construction projects.

SDG&E

At December 31, 2011, SDG&E has commitments to make future payments of $408 million for construction projects that include

§	$147 million for the engineering, material procurement and construction costs associated with the Sunrise Powerlink project; and

§	$205 million related to nuclear fuel fabrication and other construction projects at SONGS.

SDG&E expects future payments under these contractual commitments to be $229 million in 2012, $39 million in 2013, $16 million in 2014, $14 million in 2015, $27 million in 2016 and $83 million thereafter.

SoCalGas

At December 31, 2011, SoCalGas has commitments to make future payments of $378 million for construction and infrastructure improvements for natural gas transmission and distribution operations, pipeline integrity and the Advanced Metering Infrastructure Program. The future payments under these contractual commitments are expected to be $60 million in 2012, $72 million in 2013, $65 million in 2014, $65 million in 2015, $6 million in 2016 and $110 million thereafter.

Sempra South American Utilities

At December 31, 2011, Sempra South American Utilities has commitments to make future payments of $134 million for construction projects that include $129 million for the construction of the Santa Teresa hydroelectric power plant at Luz del Sur. The future payments under these contractual commitments are expected to be $64 million in 2012, $62 million in 2013 and $8 million in 2014.

Sempra Renewables

At December 31, 2011, Sempra Renewables has commitments to make future payments of $836 million for the construction of Mesquite Solar 1 and Copper Mountain 2 Solar facilities. The future payments under these contractual commitments are expected to be $610 million in 2012 and $226 million in 2013.

Sempra Natural Gas

At December 31, 2011, Sempra Natural Gas has commitments to make future payments of $43 million for construction projects that include $34 million for the construction of natural gas storage facilities at Bay Gas and Mississippi Hub. The future payments under these contractual commitments are expected to be $32 million in 2012 and $11 million in 2013.

GUARANTEES

Sempra Energy’s guarantees related to RBS Sempra Commodities, Fowler Ridge 2 and Cedar Creek 2 are discussed in Note 5.

As of December 31, 2011, SDG&E and SoCalGas did not have any outstanding guarantees.

DEPARTMENT OF ENERGY NUCLEAR FUEL DISPOSAL

The Nuclear Waste Policy Act of 1982 made the DOE responsible for the disposal 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. This cost will be recovered through SONGS revenue unless SDG&E is able to recover the increased cost from the federal government.

OTHER COMMITMENTS

Additional consideration for the settlement discussed above in “Legal Proceedings – Resolved Matters – Energy Crisis Litigation Settlement” included an agreement that, for a period of 18 years beginning in 2011, Sempra Natural Gas would sell to the California Utilities, subject to annual CPUC approval, up to 500 million cubic feet (MMcf) per day of regasified LNG from Sempra Mexico’s Energía Costa Azul facility that is not delivered or sold in Mexico at the California border index minus $0.02 per MMBtu.

We discuss reserves at Sempra Energy and SDG&E for wildfire litigation above in “Legal Proceedings – SDG&E – 2007 Wildfire Litigation.”

ENVIRONMENTAL ISSUES

Our operations are subject to federal, state and local environmental laws. We also are subject to regulations related to hazardous wastes, air and water quality, land use, solid waste disposal and the protection of wildlife. These laws and regulations require that we investigate and correct the effects of the release or disposal of materials at sites associated with our past and our present operations. These sites include those at which we have been identified as a Potentially Responsible Party (PRP) under the federal Superfund laws and similar state laws.

In addition, we are required to obtain numerous governmental permits, licenses and other approvals to construct facilities and operate our businesses. The related costs of environmental monitoring, pollution control equipment, cleanup costs, and emissions fees are significant. Increasing national and international concerns regarding global warming and mercury, carbon dioxide, nitrogen oxide and sulfur dioxide emissions could result in requirements for additional pollution control equipment or significant emissions fees or taxes that could adversely affect Sempra Natural Gas and Sempra Mexico. The California Utilities’ costs to operate their facilities in compliance with these laws and regulations generally have been recovered in customer rates.

We generally capitalize the significant costs we incur to mitigate or prevent future environmental contamination or extend the life, increase the capacity, or improve the safety or efficiency of property used in current operations. The following table shows (in millions) our capital expenditures in order to comply with environmental laws and regulations:

		Years ended December 31,
		2011		2010		2009
Sempra Energy Consolidated(1)		$	21	$	21	$	43
SDG&E			7		10		24
SoCalGas			13		10		17
(1)	In cases of non-wholly owned affiliates, includes only our share.

Decreases in 2010 compared to 2009 were primarily due to a decrease in environmental-related spending on SoCalGas’ natural gas transmission projects, completion of SDG&E’s Miramar II facility and the deconsolidation of a VIE at SDG&E. We have not identified any significant environmental issues outside the United States. From 2009 through 2013, SDG&E expects to incur costs of approximately $286 million for environmental mitigation measures associated with the Sunrise Powerlink construction project.

At the California Utilities, costs that relate to current operations or an existing condition caused by past operations are generally recorded as a regulatory asset due to the probability that these costs will be recovered in rates.

The environmental issues currently facing us or resolved during the last three years include (1) investigation and remediation of the California Utilities’ manufactured-gas sites, (2) cleanup of third-party waste-disposal sites used by the California Utilities at sites for which we have been identified as a PRP and (3) mitigation of damage to the marine environment caused by the cooling-water discharge from SONGS. The requirements for enhanced fish protection and restoration of 150 acres of coastal wetlands for the SONGS mitigation are in process and a 150-acre artificial reef was completed in 2008. The table below shows the status at December 31, 2011, of the California Utilities’ manufactured-gas sites and the third-party waste-disposal sites for which we have been identified as a PRP:

	# Sites		# Sites
	Completed		In Process
SDG&E
Manufactured-gas sites		3		―
Third-party waste-disposal sites		1		1
SoCalGas
Manufactured-gas sites		38		4
Third-party waste-disposal sites		1		2

We record environmental liabilities at undiscounted amounts when our liability is probable and the costs can be reasonably estimated. In many cases, however, investigations are not yet at a stage where we can determine whether we are liable or, if the liability is probable, to reasonably estimate the amount or range of amounts of the costs. Estimates of our liability are further subject to uncertainties such as the nature and extent of site contamination, evolving cleanup standards and imprecise engineering evaluations. We review our accruals periodically and, as investigations and cleanup proceed, we make adjustments as necessary. The following table shows (in millions) our accrued liabilities for environmental matters at December 31, 2011:

				Waste		Former Fossil-		Other
		Manufactured-		Disposal		Fueled Power		Hazardous
		Gas Sites		Sites (PRP)(1)		Plants		Waste Sites		Total
SDG&E(2)		$	0.1	$	―	$	1.0	$	0.5	$	1.6
SoCalGas			21.3		0.5		―		1.6		23.4
Other			2.7		1.2		―		0.1		4.0
Total Sempra Energy		$	24.1	$	1.7	$	1.0	$	2.2	$	29.0
(1)	Sites for which we have been identified as a Potentially Responsible Party.
(2)	Does not include SDG&E’s liability for SONGS marine mitigation.

We expect to pay the majority of these accruals over the next three years. In connection with the issuance of operating permits, SDG&E and the other owners of SONGS previously reached an agreement with the California Coastal Commission to mitigate the damage to the marine environment caused by the cooling-water discharge from SONGS. At December 31, 2011, SDG&E’s share of the estimated mitigation costs remaining to be spent through 2050 is $17 million, which is recoverable in rates.

We discuss renewable energy requirements and greenhouse gas regulation in Note 14.

NUCLEAR INSURANCE

SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. This insurance provides $375 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides for up to $12.2 billion of secondary financial protection (SFP). If a nuclear liability loss occurring at any U.S. licensed/commercial reactor exceeds the $375 million insurance limit, all nuclear reactor owners could be required to contribute to the SFP. SDG&E’s contribution would be up to $47 million. This amount is subject to an annual maximum of $7 million, unless a default occurs by any other SONGS owner. If the SFP is insufficient to cover the liability loss, SDG&E could be subject to an additional assessment.

The SONGS owners, including SDG&E, also have $2.75 billion of nuclear property, decontamination, and debris removal insurance. In addition, the SONGS owners have up to $490 million insurance coverage for outage expenses and replacement power costs due to accidental property damage. This coverage is limited to $3.5 million per week for the first 52 weeks, then $2.8 million per week for up to 110 additional weeks. There is a 12-week waiting period deductible. These insurance coverages are provided through a mutual insurance company. Insured members are subject to retrospective premium assessments. SDG&E could be assessed up to $9.6 million.

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). The industry aggregate loss limit for property claims arising from non-certified acts of terrorism is $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.

CONCENTRATION OF CREDIT RISK

We maintain credit policies and systems 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. We also grant credit to utility customers and counterparties of our other companies providing natural gas or electric services in Mexico, Chile, Peru and southwest Alabama.

When they become operational, projects owned or partially owned by Sempra Natural Gas, Sempra Renewables, Sempra South American Utilities and Sempra Mexico place significant reliance on the ability of their suppliers and customers 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.

At December 31, 2011, RBS Sempra Commodities no longer requires significant working capital support, although RBS is obligated to provide RBS Sempra Commodities with all credit support. However, we have provided back-up guarantees for a portion of RBS Sempra Commodities’ remaining trading obligations. A few of these back-up guarantees may continue for a prolonged period of time. We provide additional information regarding these back-up guarantees and other guarantees in Note 5.

NOTE 16. SEGMENT INFORMATION

We have six separately managed reportable segments, as follows:

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

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

3.	Sempra South American Utilities operates electric transmission and distribution utilities in Chile and Peru, and owns interests in utilities in Argentina. We are currently pursuing the sale of our interests in the Argentine utilities, which we discuss further in Note 4 above.

4.	Sempra Mexico owns and operates, or holds interests in, natural gas transmission pipelines and propane systems, a natural gas distribution utility, electric generation facilities and a terminal for the import of LNG and sale of natural gas in Mexico.

5.	Sempra Renewables develops, owns and operates, or holds interests in, wind and solar energy projects in Arizona, California, Colorado, Hawaii, Indiana, Kansas, Nevada and Pennsylvania to serve wholesale electricity markets in the United States.

Sempra Natural Gas develops, owns and operates, or holds interests in, a natural gas-fired electric generation plant, natural gas pipelines and storage facilities, a natural gas distribution utility and a terminal for the import and export of LNG and sale of natural gas, all within the United States.

Sempra South American Utilities and Sempra Mexico comprise our Sempra International operating unit. Sempra Renewables and Sempra Natural Gas comprise our Sempra U.S. Gas & Power operating unit.

We evaluate each segment’s performance based on its contribution to Sempra Energy’s reported earnings. 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.

Sempra Natural Gas’ sales to the DWR, under a 10-year contract that expired September 30, 2011, comprised 6 percent of our revenues in 2011, 8 percent in 2010 and 9 percent in 2009.

Prior to 2011, our Sempra Commodities segment contained our investment in RBS Sempra Commodities LLP (RBS Sempra Commodities), which held commodities-marketing businesses previously owned by us. Our investment in the partnership is reported on the equity method. We and RBS, our partner in the joint venture, sold substantially all of the partnership’s businesses and assets in four separate transactions completed in July, November and December of 2010 and February of 2011. We discuss these transactions and other matters concerning the partnership in Note 4.

The activity in the partnership no longer meets the quantitative thresholds that require Sempra Commodities to be reported as a reportable segment under applicable GAAP, and we do not consider the remaining wind-down activities of the partnership to be of continuing significance. As a result, effective January 1, 2011, we are reporting the former Sempra Commodities segment in “All other” in the following tables and have restated prior year information to be consistent with this treatment.

The following tables show selected information by segment from our Consolidated Statements of Operations and Consolidated Balance Sheets. We provide information about our equity method investments by segment in Note 4. Amounts labeled as “All other” in the following tables consist primarily of parent organizations and the former commodities-marketing businesses.

SEGMENT INFORMATION
(Dollars in millions)
	Years ended December 31,
	2011				2010				2009
REVENUES
SDG&E	$	3,373	34	%	$	3,049	34	%	$	2,916	36	%
SoCalGas		3,816	38			3,822	43			3,355	41
Sempra South American Utilities		1,080	11			1	―			1	―
Sempra Mexico		734	7			825	9			752	9
Sempra Renewables		22	―			9	―			4	―
Sempra Natural Gas		1,632	16			2,009	22			1,594	20
Adjustments and eliminations		―	―			(3)	―			(2)	―
Intersegment revenues(1)		(621)	(6)			(709)	(8)			(514)	(6)
Total	$	10,036	100	%	$	9,003	100	%	$	8,106	100	%
INTEREST EXPENSE
SDG&E	$	142			$	136			$	104
SoCalGas		69				66				68
Sempra South American Utilities		34				8				17
Sempra Mexico		20				21				19
Sempra Renewables		13				7				2
Sempra Natural Gas		80				92				60
All other		234				242				235
Intercompany eliminations(2)		(127)				(136)				(138)
Total	$	465			$	436			$	367
INTEREST INCOME
SDG&E	$	―			$	―			$	1
SoCalGas		1				1				3
Sempra South American Utilities		22				7				9
Sempra Mexico		9				5				―
Sempra Natural Gas		34				36				27
All other		1				4				7
Intercompany eliminations(2)		(41)				(37)				(26)
Total	$	26			$	16			$	21
DEPRECIATION AND AMORTIZATION
SDG&E	$	422	43	%	$	381	44	%	$	329	42	%
SoCalGas		331	34			309	36			293	38
Sempra South American Utilities		40	4			―	―			―	―
Sempra Mexico		62	6			61	7			53	7
Sempra Renewables		6	1			2	―			1	―
Sempra Natural Gas		103	11			96	11			82	11
All other		12	1			17	2			17	2
Total	$	976	100	%	$	866	100	%	$	775	100	%
INCOME TAX EXPENSE (BENEFIT)
SDG&E	$	237			$	173			$	177
SoCalGas		143				176				144
Sempra South American Utilities		42				―				(13)
Sempra Mexico		48				52				69
Sempra Renewables		(28)				(24)				(6)
Sempra Natural Gas		72				44				28
All other		(120)				(288)				23
Total	$	394			$	133			$	422

SEGMENT INFORMATION (Continued)
(Dollars in millions)
		At December 31 or for the years ended December 31,
		2011				2010				2009
EARNINGS (LOSSES)
SDG&E(3)		$	431	32	%	$	369	52	%	$	344	31	%
SoCalGas(3)			287	22			286	40			273	24
Sempra South American Utilities			425	32			69	10			69	6
Sempra Mexico			205	15			138	20			164	15
Sempra Renewables			7	―			9	1			(8)	(1)
Sempra Natural Gas			115	9			71	10			39	4
All other			(139)	(10)			(233)	(33)			238	21
Total		$	1,331	100	%	$	709	100	%	$	1,119	100	%
ASSETS
SDG&E		$	13,555	41	%	$	12,077	40	%	$	10,229	36	%
SoCalGas			8,475	25			7,986	26			7,287	26
Sempra South American Utilities			2,981	9			796	3			695	2
Sempra Mexico			2,914	9			2,846	10			2,309	8
Sempra Renewables			1,210	4			599	2			350	1
Sempra Natural Gas			5,738	17			6,132	20			5,533	19
All other			538	2			1,898	6			3,008	11
Intersegment receivables			(2,162)	(7)			(2,103)	(7)			(910)	(3)
Total		$	33,249	100	%	$	30,231	100	%	$	28,501	100	%
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E		$	1,831	64	%	$	1,210	59	%	$	955	50	%
SoCalGas			683	24			503	24			480	25
Sempra South American Utilities			110	4			―	―			―	―
Sempra Mexico			16	―			15	1			77	4
Sempra Renewables			248	9			123	6			10	1
Sempra Natural Gas			157	6			207	10			386	20
All other			4	―			4	―			4	―
Intercompany eliminations(4)			(205)	(7)			―	―			―	―
Total		$	2,844	100	%	$	2,062	100	%	$	1,912	100	%
GEOGRAPHIC INFORMATION
Long-lived assets:
United States		$	21,398	85	%	$	19,843	87	%	$	19,859	88	%
Mexico			2,196	9			2,217	10			1,954	9
South America			1,542	6			705	3			780	3
Total		$	25,136	100	%	$	22,765	100	%	$	22,593	100	%

Revenues:
United States		$	8,135	81	%	$	8,118	90	%	$	7,476	92	%
South America			1,080	11			1	―			1	―
Mexico			821	8			884	10			629	8
Total		$	10,036	100	%	$	9,003	100	%	$	8,106	100	%
(1)	Revenues for reportable segments include intersegment revenues of:
	$6 million, $53 million, $300 million and $262 million for 2011, $6 million, $44 million, $327 million and $332 million for 2010, and $7 million, $43 million, $354 million and $110 million for 2009 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively.
(2)	Prior year amounts have been revised to present amounts after eliminations between Parent and corporate entities.
(3)	After preferred dividends.
(4)	Amount represents elimination of intercompany sale of El Dorado power plant in 2011, as discussed in Note 14.

NOTE 17. QUARTERLY FINANCIAL DATA (UNAUDITED)

SEMPRA ENERGY
(In millions, except for per share amounts)
		Quarters ended
		March 31		June 30		September 30		December 31
2011
Revenues		$	2,434	$	2,422	$	2,576	$	2,604
Expenses and other income		$	2,091	$	1,836	$	2,188	$	2,198

Net income		$	260	$	494	$	319	$	308
Earnings attributable to Sempra Energy		$	254	$	503	$	289	$	285

Basic per-share amounts(1):
Net income		$	1.08	$	2.06	$	1.33	$	1.28
Earnings attributable to Sempra Energy		$	1.06	$	2.10	$	1.21	$	1.19
Weighted average common shares outstanding			240.1		239.4		239.5		239.8

Diluted per-share amounts(1):
Net income		$	1.08	$	2.05	$	1.32	$	1.27
Earnings attributable to Sempra Energy		$	1.05	$	2.09	$	1.20	$	1.18
Weighted average common shares outstanding			241.9		240.8		241.9		241.8
2010
Revenues		$	2,534	$	2,008	$	2,116	$	2,345
Expenses and other income		$	2,395	$	1,771	$	2,017	$	2,033

Net income		$	103	$	187	$	119	$	294
Earnings attributable to Sempra Energy		$	109	$	204	$	123	$	273

Basic per-share amounts(1):
Net income		$	0.42	$	0.75	$	0.49	$	1.23
Earnings attributable to Sempra Energy		$	0.44	$	0.82	$	0.50	$	1.14
Weighted average common shares outstanding			246.1		246.8		246.7		239.5

Diluted per-share amounts(1):
Net income		$	0.41	$	0.74	$	0.48	$	1.21
Earnings attributable to Sempra Energy		$	0.44	$	0.81	$	0.50	$	1.12
Weighted average common shares outstanding			250.4		249.7		249.8		242.5
(1)	Earnings per share are computed independently for each of the quarters and therefore may not sum to the total for the year.

In the second quarter of 2011, Expenses and Other Income, Net Income and Earnings Attributable to Sempra Energy were impacted by a $277 million gain (both before and after tax) resulting from the remeasurement of our equity method investments related to Sempra South American Utilities’ acquisition of additional interests in Chilquinta Energía and Luz del Sur on April 6, 2011, as we discuss in Note 3. Earnings Attributable to Sempra Energy were impacted by $11 million in the third quarter of 2011 and $24 million in the fourth quarter of 2011 from higher earnings from the acquisition of the additional interests in Chilquinta Energía and Luz del Sur.

Revenues increased $324 million, $335 million and $350 million in the second, third and fourth quarters of 2011 compared to 2010, respectively, due to the consolidation of Chilquinta Energía and Luz del Sur beginning April 6, 2011.

In the first quarter of 2010, Expenses and Other Income included $159 million in litigation expense related to the agreement in principle to settle certain energy crisis litigation. The litigation expense negatively impacted Net Income and Earnings Attributable to Sempra Energy by $96 million. Also in the first quarter of 2010, Earnings Attributable to Sempra Energy were negatively impacted by a $16 million write-down of deferred tax assets as a result of the change to U.S. tax law regarding the Medicare Part D subsidy.

In the third quarter of 2010, Expenses and Other Income included a $305 million write-down of our investment in RBS Sempra Commodities. This write-down and a write-down of our investment in Argentina negatively impacted Net Income and Earnings Attributable to Sempra Energy by $139 million and $24 million, respectively.

We discuss quarterly fluctuations related to SDG&E and SoCalGas below.

SDG&E
(Dollars in millions)
	Quarters ended
	March 31		June 30		September 30		December 31
2011
Operating revenues	$	840	$	697	$	868	$	968
Operating expenses		677		584		658		699
Operating income	$	163	$	113	$	210	$	269

Net income	$	94	$	53	$	136	$	172
(Earnings) losses attributable to noncontrolling interests		(4)		19		(21)		(13)
Earnings		90		72		115		159
Dividends on preferred stock		(1)		(1)		(2)		(1)
Earnings attributable to common shares	$	89	$	71	$	113	$	158
2010
Operating revenues	$	742	$	692	$	811	$	804
Operating expenses		604		546		613		629
Operating income	$	138	$	146	$	198	$	175

Net income	$	76	$	55	$	103	$	124
(Earnings) losses attributable to noncontrolling interests		8		21		5		(18)
Earnings		84		76		108		106
Dividends on preferred stock		(1)		(1)		(2)		(1)
Earnings attributable to common shares	$	83	$	75	$	106	$	105

In the fourth quarter of 2011 compared to the same quarter in 2010, Operating Revenues, Net Income and Earnings for SDG&E were favorably impacted by $57 million, $34 million and $34 million, respectively, related to higher revenues associated with incremental wildfire insurance premiums.

Net Income and Earnings for the second, third and fourth quarters of 2011 were favorably impacted by $7 million, $10 million and $13 million, respectively, related to higher allowance for equity funds used during construction, net of changes in interest expense.

SOCALGAS
(Dollars in millions)
	Quarters ended
	March 31		June 30		September 30		December 31
2011
Operating revenues	$	1,056	$	876	$	844	$	1,040
Operating expenses		937		773		709		911
Operating income	$	119	$	103	$	135	$	129

Net income	$	68	$	60	$	81	$	79
Dividends on preferred stock		―		(1)		―		―
Earnings attributable to common shares	$	68	$	59	$	81	$	79
2010
Operating revenues	$	1,182	$	834	$	776	$	1,030
Operating expenses		1,048		716		642		900
Operating income	$	134	$	118	$	134	$	130

Net income	$	65	$	70	$	78	$	74
Dividends on preferred stock		―		(1)		―		―
Earnings attributable to common shares	$	65	$	69	$	78	$	74

In the first quarter of 2011, SoCalGas’ Operating Revenues decreased by $176 million due to lower natural gas prices compared to the first quarter of 2010.

Compared to the first quarter of 2010, Operating Revenues and Operating Expenses were lower in the remaining quarters of 2010 due to lower natural gas prices and volumes.

NOTE 18. SUBSEQUENT EVENT

Effective January 1, 2012, in connection with several key executive appointments made in September 2011, management realigned some of the company’s major operating units to better fit its strategic direction and to enhance the management and integration of our assets. This realignment resulted in a change in reportable segments in 2012, primarily to regroup the Sempra Global business units under two operating units, Sempra International and Sempra U.S. Gas & Power, as we discuss in Note 1.

GLOSSARY


2010 Tax Act	Tax Relief, Unemployment Insurance Reauthorization, and Job Creation Act of 2010	Ecogas	Ecogas Mexico, S de RL de CV
AB 32	California Assembly Bill 32	Edison	Southern California Edison Company
AFUDC	Allowance for funds used during construction	Elk Hills	Elk Hills Power
AMI	Advanced Metering Infrastructure	EPA	Environmental Protection Agency
AOCI	Accumulated other comprehensive income (loss)	EPS	Earnings per common share
AROs	Asset retirement obligations	ERRP	Early Retiree Reinsurance Program
ASC	Accounting Standards Codification	ESOP	Employee stock ownership plan
ASU	Accounting Standards Update	FERC	Federal Energy Regulatory Commission
Bay Gas	Bay Gas Storage, LLC	Fowler Ridge 2	Fowler Ridge 2 Wind Farm
Bcf	Billion cubic feet	GAAP	Accounting Principles Generally Accepted in the United States of America
Black-Scholes Model	Black-Scholes option-pricing model	Gazprom	Gazprom Marketing & Trading Mexico
BLM	Bureau of Land Management	GCIM	Gas Cost Incentive Mechanism
Cal Fire	California Department of Forestry and Fire Protection	GHG	Greenhouse Gas
California Utilities	San Diego Gas & Electric Company and Southern California Gas Company	GRC	General Rate Case
CARB	California Air Resources Board	IBLA	Interior Board of Land Appeals
CBD	Center for Biological Diversity/Sierra Club	ICSID	International Center for the Settlement of Investment Disputes
CEC	California Energy Commission	IFRS	International Financial Reporting Standards
Cedar Creek 2	Cedar Creek 2 Wind Farm	IOUs	Investor-owned Utilities
CEQA	California Environmental Quality Act	ISFSI	Independent spent fuel storage installation
CFE	Comisión Federal de Electricidad (Federal Electricity Commission)	ISO	Independent System Operator
CFTC	U.S. Commodity Futures Trading Commission	JP Morgan	J.P. Morgan Chase & Co.
Chilquinta Energía	Chilquinta Energía S.A.	J.P. Morgan Ventures	J.P. Morgan Ventures Energy Corporation
CMS 2	Copper Mountain Solar 2	KMP	Kinder Morgan Energy Partners, L.P.
CNE	Comisión Nacional de Energía (National Energy Commission)	kV	Kilovolt
Conoco	ConocoPhillips	Liberty	Liberty Gas Storage, LLC
Cox	Cox Communications	LIBOR	London interbank offered rate
CPSD	Consumer Protection and Safety Division	LIFO	Last-in first-out inventory
CPUC	California Public Utilities Commission	LNG	Liquefied natural gas
CRE	Comisión Reguladora de Energía (Energy Regulatory Commission)	Luz del Sur	Luz del Sur S.A.A.
CRRs	Congestion revenue rights	MAOP	Maximum allowable operating pressure
DOE	U.S. Department of Energy	MBFC	Mississippi Business Finance Corporation
DRA	Division of Ratepayer Advocates	Mcf	Thousand cubic feet
DWR	California Department of Water Resources	MHI	Mitsubishi Heavy Industries
EBITDA	Earnings before interest, taxes, depreciation and amortization	MICAM	Market Indexed Capital Adjustment Mechanism

GLOSSARY (CONTINUED)


Midstream Services	Sempra Midstream Services	RDS	Retiree Drug Subsidy
Mississippi Hub	Mississippi Hub, LLC	REX	Rockies Express Pipeline
MMBtu	Million British Thermal Units (of natural gas)	Rockies Express	Rockies Express Pipeline LLC
MMcf	Million cubic feet	ROE	Return on equity
Mobile Gas	Mobile Gas Service Corporation	ROR	Rate of return
MSCI	Morgan Stanley Capital International	RPS	Renewables Portfolio Standard
MSCI EAFE Index	MSCI Index for equity market performance in Europe, Australasia and Far East	RSAs	Restricted stock awards
MW	Megawatt	RSUs	Restricted stock units
MWh	Megawatt hour	SDG&E	San Diego Gas & Electric Company
Noble Group	Noble Group Ltd.	SFP	Secondary Financial Protection
NOLs	Net operating losses	Shell	Shell México Gas Natural
NRC	Nuclear Regulatory Commission	SoCalGas	Southern California Gas Company
NTSB	National Transportation Safety Board	SONGS	San Onofre Nuclear Generating Station
OCI	Other comprehensive income	SPPR Group	Southwest Public Power Resources Group
OMEC	Otay Mesa Energy Center	S&P	Standard & Poor’s
OMEC LLC	Otay Mesa Energy Center LLC	Tangguh PSC	Tangguh PSC Contractors
OSINERGMIN	Organismo Supervisor de la Inversión en Energía y Minería (Energy and Mining Investment Supervisory Body)	Tecnored	Tecnored S.A.
Otay Mesa VIE	Otay Mesa Energy Center LLC	Tecsur	Tecsur S.A.
OTC	Over-the-counter	The Committee	Pension and Benefits Investment Committee
PBOP	Other postretirement benefit plans	The Plan	Sempra Energy 2008 Long Term Incentive Plan for EnergySouth, Inc. Employees and Other Eligible Individuals
PBOP plan trusts	Postretirement benefit plan trusts	The Prior Plan	2008 Incentive Plan of EnergySouth, Inc.
PCBs	Polychlorinated biphenyls	Trust	ESOP trust
PE	Pacific Enterprises	TURN	The Utility Reform Network
PEMEX	Petroleos Mexicanos (Mexican state-owned oil company)	UCAN	Utility Consumers’ Action Network
PG&E	Pacific Gas and Electric Company	USFS	United States Forest Service
PPACA	Patient Protection and Affordable Care Act	VaR	Value at Risk
PRP	Potentially Responsible Party	VEBA	Voluntary Employee Beneficiary Association
PSEP	Pipeline Safety Enhancement Plan	VIE	Variable Interest Entity
RBS	The Royal Bank of Scotland plc	VNR	Valor Nuevo de Reemplazo (New replacement value)
RBS Sempra Commodities	RBS Sempra Commodities LLP	Williams	Williams Midstream Natural Gas Liquids, Inc.

REVENUES FROM UNCONSOLIDATED AFFILIATES AT UTILITY BUSINESSES

(Dollars in millions)

Years ended December 31,