View Filing Data

3,336,000,000

3,273,000,000

Dedicated assets in support of certain benefit plans

1,082,000,000

1,063,000,000

Other investments

2,727,000,000

2,905,000,000

Goodwill

849,000,000

819,000,000

Other intangible assets

402,000,000

404,000,000

432,000,000

464,000,000

Property, plant and equipment

660,000,000

325,000,000

Sundry

825,000,000

761,000,000

Total other assets

10,519,000,000

10,220,000,000

Property, plant and equipment:

38,541,000,000

38,200,000,000

Less accumulated depreciation and amortization

(10,108,000,000)

(10,161,000,000)

Due to unconsolidated affiliates

28,433,000,000

28,039,000,000

Total assets

41,835,000,000

41,150,000,000

Current liabilities:

Short-term debt

1,177,000,000

622,000,000

Accounts payable - trade

1,028,000,000

1,133,000,000

Accounts payable - other

129,000,000

142,000,000

13,000,000

14,000,000

Dividends and interest payable

360,000,000

303,000,000

Accrued compensation and benefits

259,000,000

423,000,000

Regulatory balancing accounts, overcollected

45,000,000

34,000,000

Current portion of long-term debt

1,066,000,000

907,000,000

Fixed-price contracts and other derivatives, current liabilities

57,000,000

56,000,000

Customer deposits

147,000,000

153,000,000

Other current liabilities

302,000,000

274,000,000

549,000,000

551,000,000

Total current liabilities

5,132,000,000

4,612,000,000

Deferred Credits And Other Liabilities [Abstract]

12,975,000,000

13,134,000,000

Customer advances for construction

148,000,000

149,000,000

Pension and other postretirement benefit obligations, net of plan assets

1,165,000,000

1,152,000,000

Deferred income taxes, net noncurrent liabilities

3,222,000,000

3,157,000,000

Deferred investment tax credits

32,000,000

Regulatory liabilities arising from removal obligations

2,850,000,000

2,793,000,000

Asset retirement obligations

2,151,000,000

2,126,000,000

Fixed-price contracts and other derivatives, noncurrent liabilities

248,000,000

240,000,000

Deferred credits and other

1,188,000,000

1,176,000,000

Total deferred credits and other liabilities

11,004,000,000

10,825,000,000

Equity:

Preferred stock

Common stock

2,642,000,000

2,621,000,000

Retained earnings

10,125,000,000

9,994,000,000

Accumulated other comprehensive income (loss)

^[2]

(821,000,000)

(806,000,000)

Total shareholders' equity

11,946,000,000

11,809,000,000

Preferred stock of subsidiaries

20,000,000

Other noncontrolling interests

758,000,000

750,000,000

Total equity

12,724,000,000

12,579,000,000

Total liabilities and equity

41,835,000,000

41,150,000,000

Cash and cash equivalents

Current assets:

36,000,000

20,000,000

Restricted cash

21,000,000

23,000,000

Trade accounts receivable

300,000,000

331,000,000

Other accounts and notes receivable

18,000,000

17,000,000

Due from unconsolidated affiliates

1,000,000

Inventories

72,000,000

75,000,000

Regulatory balancing accounts, undercollected

256,000,000

307,000,000

Fixed-price contracts and other derivatives, current assets

119,000,000

107,000,000

50,000,000

53,000,000

Other current assets

64,000,000

70,000,000

Total current assets

937,000,000

1,004,000,000

Other assets:

Restricted cash, noncurrent

2,000,000

Deferred taxes recoverable in rates

921,000,000

914,000,000

968,000,000

977,000,000

Property, plant and equipment

1,082,000,000

1,063,000,000

Sundry

331,000,000

301,000,000

Total other assets

3,304,000,000

3,255,000,000

Property, plant and equipment:

16,668,000,000

16,458,000,000

Less accumulated depreciation and amortization

(4,284,000,000)

(4,202,000,000)

Due to unconsolidated affiliates

12,384,000,000

12,256,000,000

Total assets

16,625,000,000

16,515,000,000

Current liabilities:

Short-term debt

166,000,000

168,000,000

Accounts payable - trade

295,000,000

377,000,000

49,000,000

55,000,000

Income taxes payable

59,000,000

Accrued compensation and benefits

67,000,000

129,000,000

Accrued Franchise Fees

46,000,000

66,000,000

Current portion of long-term debt

191,000,000

50,000,000

Fixed-price contracts and other derivatives, current liabilities

53,000,000

51,000,000

Customer deposits

71,000,000

72,000,000

Interest payable

39,000,000

Asset Retirement Obligation Current

63,000,000

99,000,000

Other current liabilities

130,000,000

101,000,000

Total current liabilities

1,229,000,000

1,207,000,000

Deferred Credits And Other Liabilities [Abstract]

4,294,000,000

4,455,000,000

Customer advances for construction

44,000,000

46,000,000

Pension and other postretirement benefit obligations, net of plan assets

216,000,000

212,000,000

Deferred income taxes, net noncurrent liabilities

2,497,000,000

2,472,000,000

Deferred investment tax credits

20,000,000

19,000,000

Regulatory liabilities arising from removal obligations

1,692,000,000

1,629,000,000

Asset retirement obligations

745,000,000

729,000,000

Fixed-price contracts and other derivatives, noncurrent liabilities

107,000,000

106,000,000

Deferred credits and other

378,000,000

364,000,000

Total deferred credits and other liabilities

5,699,000,000

5,577,000,000

Equity:

Common stock

1,338,000,000

Retained earnings

4,022,000,000

3,893,000,000

Accumulated other comprehensive income (loss)

(8,000,000)

Total shareholders' equity

5,352,000,000

5,223,000,000

Other noncontrolling interests

51,000,000

53,000,000

Total equity

5,403,000,000

5,276,000,000

Total liabilities and equity

16,625,000,000

16,515,000,000

Cash and cash equivalents

Current assets:

14,000,000

58,000,000

Trade accounts receivable

445,000,000

635,000,000

Other accounts and notes receivable

99,000,000

Due from unconsolidated affiliates

8,000,000

48,000,000

Inventories

33,000,000

79,000,000

Regulatory assets arising from pension and other postretirement benefit obligations

8,000,000

7,000,000

Other current assets

44,000,000

40,000,000

Total current assets

651,000,000

966,000,000

Other assets:

715,000,000

699,000,000

686,000,000

636,000,000

Property, plant and equipment

660,000,000

325,000,000

Sundry

252,000,000

207,000,000

Total other assets

2,313,000,000

1,867,000,000

Property, plant and equipment:

14,359,000,000

14,171,000,000

Less accumulated depreciation and amortization

(4,896,000,000)

(4,900,000,000)

Due to unconsolidated affiliates

9,463,000,000

9,271,000,000

Total assets

12,427,000,000

12,104,000,000

Current liabilities:

Short-term debt

5,000,000

Accounts payable - trade

351,000,000

422,000,000

Accounts payable - other

77,000,000

76,000,000

34,000,000

Income taxes payable

27,000,000

3,000,000

Accrued compensation and benefits

110,000,000

160,000,000

Regulatory balancing accounts, overcollected

45,000,000

34,000,000

Current portion of long-term debt

9,000,000

Customer deposits

70,000,000

76,000,000

Other current liabilities

302,000,000

274,000,000

193,000,000

184,000,000

Total current liabilities

1,223,000,000

1,238,000,000

Deferred Credits And Other Liabilities [Abstract]

2,481,000,000

Customer advances for construction

104,000,000

103,000,000

Pension and other postretirement benefit obligations, net of plan assets

733,000,000

716,000,000

Deferred income taxes, net noncurrent liabilities

1,643,000,000

1,532,000,000

Deferred investment tax credits

13,000,000

14,000,000

Regulatory liabilities arising from removal obligations

1,139,000,000

1,145,000,000

Asset retirement obligations

1,367,000,000

1,354,000,000

Deferred credits and other

380,000,000

372,000,000

Total deferred credits and other liabilities

5,379,000,000

5,236,000,000

Equity:

Preferred stock

22,000,000

Common stock

866,000,000

Retained earnings

2,475,000,000

2,280,000,000

Accumulated other comprehensive income (loss)

(19,000,000)

Total shareholders' equity

3,344,000,000

3,149,000,000

Total equity

3,344,000,000

3,149,000,000

Total liabilities and equity

$ 12,427,000,000

$ 12,104,000,000

[1]	Derived from audited financial statements.
[2]	All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests.

CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - USD ($)
shares in Millions, $ in Millions

Mar. 31, 2016

Dec. 31, 2015

$ 28,433

$ 28,039

^[1]

Preferred stock, shares authorized

$ 12,975

$ 13,134

^[1]

Shareholders' equity:

Preferred stock, shares issued

Common stock, shares authorized

750

Common stock, shares outstanding

249

248

Otay Mesa VIE [Member]

$ 376

$ 383

300

303

12,384

12,256

^[1]

Common stock, shares authorized

$ 4,294

$ 4,455

^[1]

Shareholders' equity:

255

Common stock, shares outstanding

117

San Diego Gas and Electric Company [Member] | Otay Mesa VIE [Member]

$ 376

$ 383

300

303

9,463

9,271

^[1]

Common stock, shares authorized

$ 2,481

^[1]

Shareholders' equity:

100

Common stock, shares outstanding

[1]	Derived from audited financial statements.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($)
shares in Thousands, $ in Millions

3 Months Ended

Mar. 31, 2016

Mar. 31, 2015

REVENUES

Utilities

$ 2,442

$ 2,422

Energy-related businesses

180

260

Total revenues

2,622

2,682

Utilities [Abstract]

Cost of natural gas

(311)

(346)

Cost of electric fuel and purchased power

(515)

(481)

Cost of natural gas, electric fuel and purchased power

(56)

(98)

Other cost of sales

(35)

Operation and maintenance

(701)

(658)

Depreciation and amortization

(328)

(303)

Plant closure adjustment (loss)

Franchise fees and other taxes

(111)

(107)

Equity Earnings Losses Before Income Tax [Abstract]

Equity (losses) earnings, before income tax

(22)

Other income (expense), net

Interest income

Income (loss) before income taxes and equity earnings of certain unconsolidated subsidiaries

(143)

(134)

455

606

Equity earnings, net of income tax

(142)

(163)

Net income (loss)

330

458

Losses (earnings) attributable to noncontrolling interests

(11)

(21)

Earnings (losses)

$ 319

$ 437

Basic earnings per common share:

Basic earnings per common share

$ 1.28

$ 1.76

Basic earnings per common share, weighted-average number of shares outstanding (thousands)

^[1]

249,734

247,722

Diluted earnings per common share:

Diluted earnings per common share

$ 1.27

$ 1.74

Diluted earnings per common share, weighted-average number of shares outstanding (thousands)

251,412

251,206

Dividends declared per share of common stock

$ 0.76

$ 0.7

Total utility operating revenues

Utility operating revenues

Electric

$ 843

$ 805

Natural gas

148

161

991

966

Utility operating expenses

Utility cost of electric fuel and purchased power

248

228

Utility cost of natural gas

Utility operation and maintenance

246

217

Utility franchise fees and other taxes

159

145

Utility plant closure (adjustment) loss

(21)

Total utility operating expenses

755

684

Utility operating income (loss)

236

282

Equity Earnings Losses Before Income Tax [Abstract]

Other income (expense), net

Income (loss) before income taxes and equity earnings of certain unconsolidated subsidiaries

(48)

(52)

202

239

Losses (earnings) attributable to noncontrolling interests

(72)

(88)

Net income (loss)

130

151

(1)

(4)

Earnings (losses)

129

147

Total utility operating revenues

Utility operating revenues

1,033

1,048

Utility operating expenses

Utility cost of natural gas

253

267

Utility operation and maintenance

327

314

Utility franchise fees and other taxes

122

113

Total utility operating expenses

739

728

Utility operating income (loss)

294

320

Equity Earnings Losses Before Income Tax [Abstract]

Other income (expense), net

Income (loss) before income taxes and equity earnings of certain unconsolidated subsidiaries

(22)

(19)

282

309

CASH FLOWS FROM OPERATING ACTIVITIES

(87)

(95)

Net income (loss)

195

214

Earnings (losses)

$ 195

$ 214

[1]

Includes 555 and 452 average fully vested restricted stock units held in our Deferred Compensation Plan for the three months ended March 31, 2016 and 2015, respectively. These fully vested restricted stock units are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Net income	$ 330,000,000	$ 458,000,000
Before-Tax Amount [Member]
Net income	461,000,000	600,000,000
Comprehensive income, net of income tax
Foreign currency translation adjustments	68,000,000	(62,000,000)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	2,000,000	2,000,000
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	(159,000,000)	(89,000,000)
Other Comprehensive Income (Loss), Net of Tax, Total	(89,000,000)	(149,000,000)
Total Comprehensive Income	372,000,000	451,000,000
Income Tax (Expense) Benefit [Member]
Net income	(142,000,000)	(163,000,000)
Comprehensive income, net of income tax
Foreign currency translation adjustments	0	0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	(1,000,000)	(1,000,000)
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	75,000,000	34,000,000
Other Comprehensive Income (Loss), Net of Tax, Total	74,000,000	33,000,000
Total Comprehensive Income	(68,000,000)	(130,000,000)
Net-of-Tax Amount [Member]
Net income	319,000,000	437,000,000
Comprehensive income, net of income tax
Foreign currency translation adjustments	68,000,000	(62,000,000)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	1,000,000	1,000,000
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	(84,000,000)	(55,000,000)
Other Comprehensive Income (Loss), Net of Tax, Total	(15,000,000)	(116,000,000)
Total Comprehensive Income	304,000,000	321,000,000
Noncontrolling Interests [Member]
Net income	11,000,000	21,000,000
Comprehensive income, net of income tax
Foreign currency translation adjustments	5,000,000	(8,000,000)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	0	0
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	(5,000,000)	(5,000,000)
Other Comprehensive Income (Loss), Net of Tax, Total	0	(13,000,000)
Total Comprehensive Income	11,000,000	8,000,000
Total Equity [Member]
Net income	330,000,000	458,000,000
Comprehensive income, net of income tax
Foreign currency translation adjustments	73,000,000	(70,000,000)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	1,000,000	1,000,000
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	(89,000,000)	(60,000,000)
Other Comprehensive Income (Loss), Net of Tax, Total	(15,000,000)	(129,000,000)
Total Comprehensive Income	315,000,000	329,000,000
San Diego Gas and Electric Company [Member]
Net income	130,000,000	151,000,000
San Diego Gas and Electric Company [Member] \| Before-Tax Amount [Member]
Net income	201,000,000	235,000,000
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	0	0
Other Comprehensive Income (Loss), Net of Tax, Total	0	0
Total Comprehensive Income	201,000,000	235,000,000
San Diego Gas and Electric Company [Member] \| Income Tax (Expense) Benefit [Member]
Net income	(72,000,000)	(88,000,000)
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	0	0
Other Comprehensive Income (Loss), Net of Tax, Total	0	0
Total Comprehensive Income	(72,000,000)	(88,000,000)
San Diego Gas and Electric Company [Member] \| Net-of-Tax Amount [Member]
Net income	129,000,000	147,000,000
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	0	0
Other Comprehensive Income (Loss), Net of Tax, Total	0	0
Total Comprehensive Income	129,000,000	147,000,000
San Diego Gas and Electric Company [Member] \| Noncontrolling Interests [Member]
Net income	1,000,000	4,000,000
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	(2,000,000)	(2,000,000)
Other Comprehensive Income (Loss), Net of Tax, Total	(2,000,000)	(2,000,000)
Total Comprehensive Income	(1,000,000)	2,000,000
San Diego Gas and Electric Company [Member] \| Total Equity [Member]
Net income	130,000,000	151,000,000
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	(2,000,000)	(2,000,000)
Other Comprehensive Income (Loss), Net of Tax, Total	(2,000,000)	(2,000,000)
Total Comprehensive Income	128,000,000	149,000,000
Southern California Gas Company [Member]
Net income	195,000,000	214,000,000
Southern California Gas Company [Member] \| Before-Tax Amount [Member]
Net income	282,000,000	309,000,000
Comprehensive income, net of income tax
Total Comprehensive Income	282,000,000	309,000,000
Southern California Gas Company [Member] \| Income Tax (Expense) Benefit [Member]
Net income	(87,000,000)	(95,000,000)
Comprehensive income, net of income tax
Total Comprehensive Income	(87,000,000)	(95,000,000)
Southern California Gas Company [Member] \| Net-of-Tax Amount [Member]
Net income	195,000,000	214,000,000
Comprehensive income, net of income tax
Total Comprehensive Income	$ 195,000,000	$ 214,000,000

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($)
$ in Millions

3 Months Ended

Mar. 31, 2016

Mar. 31, 2015

Net income

$ 330

$ 458

Adjustments to reconcile net income to net cash provided by operating activities:

Depreciation and amortization

328

303

Deferred income taxes and investment tax credits

112

131

Plant closure (adjustment) loss

(21)

Equity earnings

(34)

Fixed-price contracts and other derivatives

Other

(27)

Net change in other working capital components

165

Insurance Receivable For Aliso Canyon Costs

(335)

Changes in other assets

(29)

(42)

Changes in other liabilities

Net cash provided by operating activities

592

811

CASH FLOWS FROM INVESTING ACTIVITIES

Expenditures for property, plant and equipment

(971)

(780)

Expenditures for investments

(30)

(34)

Distributions from investments

Purchases of nuclear decommissioning and other trust assets

(94)

(95)

Proceeds from sales by nuclear decommissioning and other trusts

Decrease in restricted cash

Increase in restricted cash

(16)

(18)

Advances to unconsolidated affiliates

(6)

(5)

Proceeds From Payments For Long Term Loans For Related Parties

Other cash flows from investing activities

(3)

Net cash used in investing activities

(989)

(770)

CASH FLOWS FROM FINANCING ACTIVITIES

Common dividends paid

(161)

(149)

Proceeds from issuances of common stock

Issuances of long-term debt

(54)

(65)

938

Payments on long-term debt

(54)

(654)

Increase (decrease) in short-term debt, net

531

(363)

Excess Tax Benefit From Share Based Compensation Financing Activities

Other cash flows from financing activities

(2)

(7)

Net cash provided by (used in) financing activities

364

(231)

Effect of exchange rate changes on cash and cash equivalents

(3)

Increase (decrease) in cash and cash equivalents

(27)

(193)

Cash and cash equivalents, beginning of period

403

^[1]

570

Cash and cash equivalents, end of period

376

377

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION

Interest payments, net of amounts capitalized

Income tax payments, net of refunds

SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES

Accrued capital expenditures

423

272

Financing of build-to-suit property

Common dividends issued in stock

Dividends declared but not paid

197

181

Acquisition Of Business [Abstract]

Assets acquired

Liabilities Assumed

(2)

Accrued purchase price

(6)

Cash paid

CASH FLOWS FROM OPERATING ACTIVITIES

Net income

130

151

Adjustments to reconcile net income to net cash provided by operating activities:

Deferred income taxes and investment tax credits

159

145

Utility plant closure (adjustment) loss

(21)

Fixed-price contracts and other derivatives

(1)

Other

(9)

(1)

Net change in other working capital components

103

Changes in other assets

(34)

(48)

Changes in other liabilities

Net cash provided by operating activities

369

299

CASH FLOWS FROM INVESTING ACTIVITIES

Expenditures for property, plant and equipment

(329)

(355)

Purchases of nuclear decommissioning trust assets

(93)

(94)

Proceeds from sales by nuclear decommissioning trusts

Decrease in restricted cash

Increase in restricted cash

(10)

Other cash flows from investing activities

(1)

Increase (Decrease) in loans to affiliates, net

(66)

Net cash used in investing activities

(330)

(421)

CASH FLOWS FROM FINANCING ACTIVITIES

Issuances of long-term debt

388

Payments on long-term debt

(20)

(3)

Increase (decrease) in short-term debt, net

(2)

(246)

Net cash provided by (used in) financing activities

(1)

(2)

(23)

137

Increase (decrease) in cash and cash equivalents

Cash and cash equivalents, beginning of period

^[1]

Cash and cash equivalents, end of period

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION

Interest payments, net of amounts capitalized

Income tax payments, net of refunds

(8)

SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES

Accrued capital expenditures

104

103

CASH FLOWS FROM OPERATING ACTIVITIES

Net income

195

214

Adjustments to reconcile net income to net cash provided by operating activities:

Deferred income taxes and investment tax credits

122

113

(9)

Other

(7)

(6)

Net change in other working capital components

243

Insurance Receivable For Aliso Canyon Costs

(335)

Changes in other assets

(37)

(19)

Changes in other liabilities

(3)

Net cash provided by operating activities

241

375

CASH FLOWS FROM INVESTING ACTIVITIES

Expenditures for property, plant and equipment

(340)

(315)

Increase (Decrease) in loans to affiliates, net

(74)

Net cash used in investing activities

(290)

(389)

CASH FLOWS FROM FINANCING ACTIVITIES

Increase (decrease) in short-term debt, net

(50)

Net cash provided by (used in) financing activities

(50)

Increase (decrease) in cash and cash equivalents

(44)

(64)

Cash and cash equivalents, beginning of period

^[1]

Cash and cash equivalents, end of period

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION

Interest payments, net of amounts capitalized

Income tax payments, net of refunds

(3)

SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES

Accrued capital expenditures

$ 148

$ 129

[1]	Derived from audited financial statements.

GENERAL

3 Months Ended

Mar. 31, 2016

Organization Consolidation And Presentation Of Financial Statements [Abstract]

General

SEMPRA ENERGY AND SUBSIDIARIES NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

NOTE 1. GENERAL

PRINCIPLES OF CONSOLIDATION

Sempra Energy

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

San Diego Gas & Electric Company (SDG&E) and Southern California Gas Company (SoCalGas), which are separate, reportable segments;
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 12.

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.

Our Sempra Mexico segment includes the operating companies of our subsidiary, Infraestructura Energética Nova, S.A.B. de C.V. (IEnova), as well as certain holding companies and risk management activity. We discuss IEnova further in Note 1 of the Notes to Consolidated Financial Statements in our Annual Report on Form 10-K for the year ended December 31, 2015 (the Annual Report), which includes the combined reports for Sempra Energy, SDG&E and SoCalGas.

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 entities in Notes 3 and 4 herein and in Notes 3, 4 and 10 of the Notes to Consolidated Financial Statements in the Annual Report.

SDG&E

SDG&E’s Condensed Consolidated Financial Statements include its accounts and the accounts of a VIE of which SDG&E is the primary beneficiary, as we discuss in Note 5 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’ Condensed Consolidated Financial Statements include its accounts and the de minimis accounts of inactive subsidiaries. SoCalGas’ common stock is wholly owned by Pacific Enterprises, 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 have prepared the Condensed Consolidated Financial Statements in conformity with accounting principles generally accepted in the United States of America (U.S. GAAP) and in accordance with the interim-period-reporting requirements of Form 10-Q. Results of operations for interim periods are not necessarily indicative of results for the entire year. We evaluated events and transactions that occurred after March 31, 2016 through the date the financial statements were issued and, in the opinion of management, the accompanying statements reflect all adjustments necessary for a fair presentation. These adjustments are only of a normal, recurring nature.

All December 31, 2015 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2015 Consolidated Financial Statements in the Annual Report. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the interim-period-reporting provisions of U.S. GAAP and the Securities and Exchange Commission.

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

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

Regulated Operations

Sempra South American Utilities has controlling interests in two electric distribution utilities in South America, Chilquinta Energía S.A. (Chilquinta Energía) in Chile and Luz del Sur S.A.A. (Luz del Sur) in Peru, and their subsidiaries. Sempra Natural Gas owns Mobile Gas Service Corporation (Mobile Gas) in southwest Alabama and Willmut Gas Company (Willmut Gas) in Mississippi, and Sempra Mexico owns Ecogas México, S. de R.L. de C.V. (Ecogas) in northern Mexico, all natural gas distribution utilities. The California Utilities, Mobile Gas, Willmut Gas, and Ecogas prepare their financial statements in accordance with U.S. GAAP provisions governing rate-regulated operations, as we discuss in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

Pipeline projects currently under construction by IEnova that are both regulated by the Comisión Reguladora de Energía (or CRE, the Energy Regulatory Commission) and meet the regulatory accounting requirements of U.S. GAAP record the impact of allowance for funds used during construction (AFUDC) related to equity. We discuss AFUDC in Note 5 below and in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

NEW ACCOUNTING STANDARDS	3 Months Ended
NEW ACCOUNTING STANDARDS	Mar. 31, 2016
Significant Accounting Policies
New Accounting Standards	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 Accounting Standards Update (ASU) 2014-09, “Revenue from Contracts with Customers,” ASU 2015-14, “Revenue from Contracts with Customers: Deferral of the Effective Date,” ASU 2016-08, “Revenue from Contracts with Customers: Principal versus Agent Considerations (Reporting Revenue Gross versus Net),” and ASU 2016-10, “Revenue from Contracts with Customers: Identifying Performance Obligations and Licensing”: ASU 2014-09 provides accounting guidance for revenue from contracts with customers and affects all entities that enter into contracts to provide goods or services to their customers. The guidance also provides a model for the measurement and recognition of gains and losses on the sale of certain nonfinancial assets, such as property and equipment, including real estate. This guidance must be adopted using either a full retrospective approach for all periods presented in the period of adoption or a modified retrospective approach. Amending ASU 2014-09, ASU 2016-08 clarifies the implementation guidance on principal versus agent considerations and ASU 2016-10 clarifies the determination of whether a good or service is separately identifiable from other promises and revenue recognition related to licenses of intellectual property. ASU 2015-14 defers the effective date of ASU 2014-09 by one year for all entities and permits early adoption on a limited basis. For public entities, ASU 2014-09 is effective for fiscal years beginning after December 15, 2017, with early adoption permitted for fiscal years beginning after December 15, 2016, and is effective for interim periods in the year of adoption. We are currently evaluating the effect of the standards on our ongoing financial reporting and have not yet selected the year in which we will adopt the standards or our transition method. ASU 2016-01, “Recognition and Measurement of Financial Assets and Financial Liabilities”: In addition to the presentation and disclosure requirements for financial instruments, ASU 2016-01 requires entities to measure equity investments not accounted for under the equity method at fair value and recognize changes in fair value in net income. Entities will no longer be able to use the cost method of accounting for equity securities. However, for equity investments without readily determinable fair values, entities may elect a measurement alternative that will allow those investments to be recorded at cost, less impairment, and adjusted for subsequent observable price changes. Upon adoption, entities must record a cumulative-effect adjustment to the balance sheet as of the beginning of the first reporting period in which the standard is adopted. The guidance on equity securities without readily determinable fair value will be applied prospectively to all equity investments that exist as of the date of adoption of the standard. For public entities, ASU 2016-01 is effective for fiscal years beginning after December 15, 2017. We will adopt ASU 2016-01 on January 1, 2018 as required and do not expect it to materially affect our financial condition, results of operations or cash flows. We will make the required changes to our disclosures upon adoption. ASU 2016-02, “Leases”: ASU 2016-02 requires entities to include substantially all leases on the balance sheet by requiring the recognition of right-of-use assets and lease liabilities for all leases. Entities may elect to exclude from the balance sheet those leases with a maximum possible term of less than 12 months. For lessees, a lease is classified as finance or operating and the asset and liability are initially measured at the present value of the lease payments. For lessors, accounting for leases is largely unchanged from previous U.S. GAAP, other than certain changes to align lessor accounting to specific changes made to lessee accounting and ASU 2014-09. ASU 2016-02 also requires qualitative disclosures along with specific quantitative disclosures for both lessees and lessors. For public entities, ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, with early adoption permitted, and is effective for interim periods in the year of adoption. The standard requires lessees and lessors to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The modified retrospective approach includes optional practical expedients that may be elected, which would allow entities to continue to account for leases that commence before the effective date of the standard in accordance with previous U.S. GAAP unless the lease is modified, except for the lessee requirement to recognize right-of-use assets and lease liabilities for all operating leases at the reporting date. We are currently evaluating the effect of the standard on our ongoing financial reporting, and have not yet selected the year in which we will adopt the standard. ASU 2016-05, “Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships”: ASU 2016-05 provides clarification that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge accounting criteria continue to be met. ASU 2016-05 may be adopted prospectively or using a modified retrospective approach. We prospectively adopted ASU 2016-05 on January 1, 2016 and it did not affect our financial condition, results of operations or cash flows. ASU 2016-09, “Improvements to Employee Share-Based Payment Accounting”: ASU 2016-09 is intended to simplify several aspects of the accounting for employee share-based payment transactions. Under ASU 2016-09, excess tax benefits and tax deficiencies are required to be recorded in earnings, and the requirement to reclassify excess tax benefits from operating to financing activities on the statement of cash flows has been eliminated. ASU 2016-09 also allows entities to withhold taxes up to the maximum individual statutory tax rate without resulting in liability classification of the award and clarifies that cash payments made to taxing authorities in connection with withheld shares should be classified as financing activities in the statement of cash flows. Additionally, the standard provides for an accounting policy election to either continue to estimate forfeitures or account for them as they occur. For public entities, ASU 2016-09 is effective for fiscal years beginning after December 15, 2016, with early adoption permitted, and is effective for interim periods in the year of adoption. We are currently evaluating the full effect of the standard on our ongoing financial reporting, and have not yet concluded as to whether we will elect an early adoption. If we early adopt in 2016, we will recognize a $34 million tax benefit in earnings, which is currently recorded in Shareholders’ Equity, related to the three months ended March 31, 2016, and a benefit to retained earnings as of January 1, 2016 of approximately $107 million, both associated with the provision in ASU 2016-09 to recognize all excess tax benefits related to share-based compensation.

Tabular disclosure of changes in accounting principles, including adoption of new accounting pronouncements, that describes the new methods, amount and effects on financial statement line items.

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Recent Investment Activity

RECENT INVESTMENT ACTIVITY

3 Months Ended

Mar. 31, 2016

Investments [Abstract]

NOTE 3. ACQUISITION AND DIVESTITURE ACTIVITY

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

Acquisition

Sempra Renewables

In March 2015, Sempra Renewables invested $8 million to acquire a 100-percent interest in the Black Oak Getty Wind project, a 78-megawatt (MW) wind farm under development in Stearns County, Minnesota. The wind farm has a 20-year power purchase agreement with Minnesota Municipal Power Agency that will commence upon commercial operation in late 2016.

POTENTIAL ACQUISITION

Sempra Mexico

IEnova and Petróleos Mexicanos (or PEMEX, the Mexican state-owned oil company) are 50-50 partners in the joint venture Gasoductos de Chihuahua (GdC). GdC develops and operates energy infrastructure in Mexico. On July 31, 2015, IEnova entered into an agreement to purchase PEMEX’s 50-percent interest for $1.325 billion (excluding the assumption of approximately $170 million of net debt), which upon closing would increase its interest from 50 percent to 100 percent. The assets involved in the acquisition included three natural gas pipelines, an ethane pipeline, and a liquid petroleum gas pipeline and associated storage terminal. The transaction excluded the Los Ramones Norte pipeline that is owned under a separate joint venture with GdC, PEMEX, BlackRock and First Reserve, keeping IEnova’s interest in the pipeline at the current 25 percent.

In December 2015, Mexico’s Comisión Federal de Competencia Económica (COFECE or Mexican Competition Commission) objected to the transaction based upon previous antitrust rulings on PEMEX’s indirect ownership of two of the assets, the TDF S. de R.L. de C.V. liquid petroleum gas pipeline and the San Fernando natural gas pipeline, included in the acquisition as proposed. COFECE specified that these assets must be offered by PEMEX in a competitive bidding process as a prerequisite for approval of any transaction involving these two assets. COFECE’s decision did not object to IEnova’s acquisition of the assets on a market concentration basis. The parties are in the process of restructuring the transaction so that PEMEX can proceed with a bidding process on these two assets in accordance with the COFECE ruling. IEnova will have the right to approve the winning bidder as a new partner. Any restructured transaction will require negotiation of satisfactory terms for the revised transaction, and will also be subject to IEnova and PEMEX board approvals and satisfactory completion of the Mexican antitrust review, and may require further approvals from Mexican authorities.

ASSETS HELD FOR SALE, POWER PLANT

Sempra Mexico

ASSETS HELD FOR SALE, POWER PLANT
(Dollars in millions)
		March 31, 2016
Cash and cash equivalents		$	1
Inventories			8
Other current assets			29
Other assets			15
Property, plant and equipment, net			250
Total assets held for sale		$	303

Accounts payable		$	1
Other current liabilities			7
Deferred income taxes			16
Asset retirement obligations			4
Other liabilities			15
Total liabilities held for sale(1)		$	43
(1)	Included in Other Current Liabilities on the Sempra Energy Condensed Consolidated Balance Sheet.

We considered the estimated fair value of the plant, less costs to sell, and determined that no adjustment to carrying value was required. In estimating fair value, we used both a market approach and discounted cash flow valuation techniques. In the event that the estimated sales price, less transaction costs, is less than the carrying value, or updated market information indicates fair value may be less than carrying value, we would recognize a loss in our results of operations at that time. We expect to complete the sale in the second half of 2016.

PENDING DIVESTITURE

Sempra Natural Gas

On March 29, 2016, Sempra Natural Gas entered into an agreement to sell its 25-percent interest in Rockies Express Pipeline LLC (Rockies Express) to a subsidiary of Tallgrass Development, LP for cash consideration of approximately $440 million, subject to adjustment at closing. The transaction is subject to customary closing conditions. Sempra Natural Gas expects the transaction to close in the second quarter of 2016.

At the date of the agreement, the carrying value of Sempra Natural Gas’ investment in Rockies Express was $484 million. Sempra Natural Gas measured the fair value of its equity method investment at $440 million, and recognized a $44 million ($27 million after-tax) impairment in Equity (Losses) Earnings, Before Income Tax, on the Sempra Energy Condensed Consolidated Statement of Operations for the three months ended March 31, 2016. We discuss non-recurring fair value measures and the associated accounting impact on our investment in Rockies Express in Note 8.

INVESTMENTS IN UNCONSOLIDATED ENTITIES	3 Months Ended
INVESTMENTS IN UNCONSOLIDATED ENTITIES	Mar. 31, 2016
Investments [Abstract]
Investments in Unconsolidated Entities	NOTE 4. INVESTMENTS IN UNCONSOLIDATED ENTITIES We provide additional information concerning our equity method investments above in Note 3 above and in Notes 3 and 4 of the Notes to Consolidated Financial Statements in the Annual Report. SEMPRA RENEWABLES Sempra Renewables invested cash of $15 million and $17 million in its joint ventures during the three months ended March 31, 2016 and 2015, respectively. SEMPRA NATURAL GAS Sempra Natural Gas capitalized $12 million of interest during both the three months ended March 31, 2016 and 2015 and invested cash of $3 million during the three months ended March 31, 2015 at Cameron LNG Holdings, LLC (Cameron LNG JV). In March 2016, Sempra Natural Gas entered into an agreement to sell its 25-percent interest in Rockies Express, which we discuss in Note 3. GUARANTEES We discuss guarantees that we have provided, which have a maximum aggregate amount of $4.5 billion, in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report. These guarantees have an aggregate carrying value of $67 million at March 31, 2016.

OTHER FINANCIAL DATA

3 Months Ended

Mar. 31, 2016

Disclosure Text Block [Abstract]

Other Financial Data

INVENTORIES

The components of inventories by segment are as follows:

INVENTORY BALANCES
(Dollars in millions)
		Natural gas				Liquefied natural gas				Materials and supplies				Total
		March 31, 2016		December 31, 2015		March 31, 2016		December 31, 2015		March 31, 2016		December 31, 2015		March 31, 2016		December 31, 2015
SDG&E		$	3	$	6	$	―	$	―	$	69	$	69	$	72	$	75
SoCalGas(1)			―		49		―		―		33		30		33		79
Sempra South American
Utilities			―		―		―		―		37		30		37		30
Sempra Mexico			―		―		6		3		2		10		8		13
Sempra Renewables			―		―		―		―		3		3		3		3
Sempra Natural Gas			74		94		3		3		1		1		78		98
Sempra Energy
Consolidated		$	77	$	149	$	9	$	6	$	145	$	143	$	231	$	298
(1)	At both March 31, 2016 and December 31, 2015, SoCalGas' natural gas inventory for core customers is net of the estimated inventory loss related to the Aliso Canyon natural gas leak, which we discuss in Note 11.

GOODWILL

We discuss goodwill in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. The increase in goodwill from $819 million at December 31, 2015 to $849 million at March 31, 2016 is due to foreign currency translation at Sempra South American Utilities. We record the offset of this fluctuation in Other Comprehensive Income (Loss).

VARIABLE INTEREST ENTITIES

We consolidate a VIE if we are the primary beneficiary of the VIE. Our determination of whether we are the primary beneficiary is based 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

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.

Tolling Agreements

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

Otay Mesa VIE

SDG&E has an agreement to purchase power generated at the Otay Mesa Energy Center (OMEC), a 605-MW generating facility. In addition to tolling, the agreement provides SDG&E with the option to purchase OMEC 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, which we refer to as the put option.

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, holds no equity in OMEC LLC and does not operate OMEC. In addition to the risks absorbed under the tolling agreement, SDG&E absorbs separately through the put option a significant portion of the risk that the value of Otay Mesa VIE could decline. Accordingly, SDG&E and Sempra Energy have consolidated Otay Mesa VIE. Otay Mesa VIE’s equity of $51 million at March 31, 2016 and $53 million at December 31, 2015 is included on the Condensed Consolidated Balance Sheets in Other Noncontrolling Interests for Sempra Energy and in Noncontrolling Interest for SDG&E.

OMEC LLC has a loan outstanding of $312 million at March 31, 2016, 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 7.

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

AMOUNTS ASSOCIATED WITH OTAY MESA VIE
(Dollars in millions)
	Three months ended March 31,
	2016		2015
Operating expenses
Cost of electric fuel and purchased power	$	(17)	$	(18)
Operation and maintenance		4		4
Depreciation and amortization		7		6
Total operating expenses		(6)		(8)
Operating income		6		8
Interest expense		(5)		(4)
Income before income taxes/Net income		1		4
Earnings attributable to noncontrolling interest		(1)		(4)
Earnings attributable to common shares	$	―	$	―

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 at March 31, 2016. 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. In addition, SDG&E is not exposed to losses or gains as a result of these other VIEs, because all such variability would be recovered in rates. We provide additional information about power purchase agreements with peaker plant facilities that are VIEs of which SDG&E is not the primary beneficiary in Note 15 of the Notes to Consolidated Financial Statements in the Annual Report.

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

Sempra Natural Gas

Sempra Energy’s equity method investment in Cameron LNG JV is considered to be a VIE generally due to contractual provisions that transfer certain risks to customers. Sempra Energy is not the primary beneficiary because we do not have the power to direct the most significant activities of Cameron LNG JV. We will continue to evaluate Cameron LNG JV for any changes that may impact our determination of the primary beneficiary. The carrying value of our investment in Cameron LNG JV, including amounts recognized in Accumulated Other Comprehensive Income (Loss) (AOCI), was $872 million at March 31, 2016 and $983 million at December 31, 2015. Our maximum exposure to loss includes the carrying value of our investment and the guarantees discussed above in Note 4 and in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report.

Other Variable Interest Entities

Sempra Energy’s other operating 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; however, their financial statements are not material to the financial statements of Sempra Energy. In all other cases, we have determined that these contracts are not variable interests in a VIE and therefore are not subject to the U.S. GAAP requirements concerning the consolidation of VIEs.

PENSION AND OTHER POSTRETIREMENT BENEFITS

Net Periodic Benefit Cost

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

NET PERIODIC BENEFIT COST – SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended March 31,
	2016		2015		2016		2015
Service cost	$	28	$	30	$	5	$	7
Interest cost		40		39		11		12
Expected return on assets		(42)		(44)		(17)		(17)
Amortization of:
Prior service cost (credit)		3		3		―		(1)
Actuarial loss		6		8		―		―
Regulatory adjustment		(28)		(29)		2		―
Total net periodic benefit cost	$	7	$	7	$	1	$	1

NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended March 31,
	2016		2015		2016		2015
Service cost	$	7	$	8	$	1	$	2
Interest cost		10		10		2		2
Expected return on assets		(12)		(14)		(3)		(3)
Amortization of:
Prior service cost		―		―		1		1
Actuarial loss		3		2		―		―
Regulatory adjustment		(7)		(5)		(1)		(2)
Total net periodic benefit cost	$	1	$	1	$	―	$	―

NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended March 31,
	2016		2015		2016		2015
Service cost	$	17	$	19	$	4	$	5
Interest cost		25		25		8		9
Expected return on assets		(25)		(27)		(14)		(14)
Amortization of:
Prior service cost (credit)		2		2		(1)		(2)
Actuarial loss		3		5		―		―
Regulatory adjustment		(21)		(24)		3		2
Total net periodic benefit cost	$	1	$	―	$	―	$	―

Benefit Plan Contributions

The following table shows our year-to-date contributions to pension and other postretirement benefit plans and the amounts we expect to contribute in 2016:

BENEFIT PLAN CONTRIBUTIONS
(Dollars in millions)
	Sempra Energy
	Consolidated		SDG&E		SoCalGas
Contributions through March 31, 2016:
Pension plans	$	15	$	2	$	―
Other postretirement benefit plans		1		―		―
Total expected contributions in 2016:
Pension plans	$	123	$	4	$	77
Other postretirement benefit plans		6		2		1

RABBI TRUST

In support of its Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans, Sempra Energy maintains dedicated assets, including a Rabbi Trust and investments in life insurance contracts, which totaled $432 million and $464 million at March 31, 2016 and December 31, 2015, respectively.

EARNINGS PER SHARE

The following table provides earnings per share (EPS) computations for the three months ended March 31, 2016 and 2015. Basic EPS is calculated by dividing earnings attributable to common stock by the weighted-average number of common shares outstanding for the period. Diluted EPS includes the potential dilution of common stock equivalent shares that could occur if securities or other contracts to issue common stock were exercised or converted into common stock.

EARNINGS PER SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
		Three months ended March 31,
		2016		2015
Numerator:
Earnings/Income attributable to common shares		$	319	$	437

Denominator:
Weighted-average common shares
	outstanding for basic EPS(1)		249,734		247,722
Dilutive effect of stock options, restricted
	stock awards and restricted stock units		1,678		3,484
Weighted-average common shares
	outstanding for diluted EPS		251,412		251,206

Earnings per share:
Basic		$	1.28	$	1.76
Diluted		$	1.27	$	1.74
(1)	Includes 555 and 452 average fully vested restricted stock units held in our Deferred Compensation Plan for the three months ended March 31, 2016 and 2015, respectively. These fully vested restricted stock units are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

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 recognized, minus tax shortfalls recognized, 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 of dilutive common stock equivalents 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). For the three months ended March 31, 2016 and 2015, we had no such antidilutive stock options outstanding. For the three months ended March 31, 2016 and 2015, we had no 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.

The dilution from unvested restricted stock awards (RSAs) and restricted stock units (RSUs) is also based on the treasury stock method. Proceeds equal to the unearned compensation and windfall tax benefits recognized, minus tax shortfalls recognized, 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 recognized 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 RSAs or antidilutive RSUs from the application of unearned compensation in the treasury stock method for the three months ended March 31, 2016. There were no such antidilutive RSAs and 614 antidilutive RSUs for the three months ended March 31, 2015.

Our performance-based RSUs include awards that vest at the end of three-year (for awards granted during or after 2015) or four-year performance periods based on Sempra Energy’s total return to shareholders relative to that of specified market indices (Total Shareholder Return or TSR RSUs) or based on the compound annual growth rate of Sempra Energy’s EPS (EPS RSUs). The comparative market indices for the TSR RSUs are the Standard & Poor’s (S&P) 500 Utilities Index and the S&P 500 Index. We primarily use long-term analyst consensus growth estimates for S&P 500 Utilities Index peer companies to develop our EPS RSU targets. TSR RSUs represent the right to receive from zero to 1.5 shares (2.0 shares for awards granted during or after 2014) of Sempra Energy common stock if performance targets are met. EPS RSUs represent the right to receive from zero to 2.0 shares of Sempra Energy common stock if performance targets are met. If performance falls between the targets specified for each performance metric, we calculate the payout using linear interpolation. Participants also receive additional shares for dividend equivalents on shares subject to RSUs, which are deemed reinvested to purchase additional units that become subject to the same vesting conditions as the RSUs to which the dividends relate. We discuss performance-based RSU awards further in Note 8 of the Notes to Consolidated Financial Statements in our Annual Report.

Our RSAs, which are solely service-based, and those RSUs that are service-based or issued in connection with certain other performance goals represent the right to receive up to 1.0 share if the service requirements or certain other vesting conditions are met. These RSAs and RSUs have the same dividend equivalent rights as the performance-based RSUs described above. We include RSAs and these RSUs in potential dilutive shares at 100 percent, subject to the application of the treasury stock method. We include our TSR RSUs and EPS RSUs in potential dilutive shares at zero to up to 200 percent 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 indices, dilutive TSR RSU shares may vary widely from period-to-period. If it were assumed that performance goals for all performance-based RSUs were met at maximum levels and if the treasury stock method were not applied to any of our RSAs or RSUs, the incremental potential dilutive shares would be 2,616,084 and 1,285,193 for the three months ended March 31, 2016 and 2015, respectively.

SHARE-BASED COMPENSATION

We discuss our share-based compensation plans in Note 8 of the Notes to Consolidated Financial Statements in the Annual Report. We recorded share-based compensation expense, net of income taxes, of $7 million and $8 million for the three months ended March 31, 2016 and 2015, respectively. Pursuant to our Sempra Energy share-based compensation plans, Sempra Energy’s compensation committee granted 372,270 TSR RSUs, 94,550 EPS RSUs and 93,256 service-based RSUs during the three months ended March 31, 2016, primarily in January.

During the three months ended March 31, 2016, IEnova issued 183,970 RSUs from the IEnova 2013 Long-Term Incentive Plan, under which awards are cash settled at vesting based on the price of IEnova common stock.

CAPITALIZED FINANCING COSTS

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

The following table shows capitalized financing costs for the three months ended March 31, 2016 and 2015.

CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Three months ended March 31,
	2016		2015
Sempra Energy Consolidated:
AFUDC related to debt	$	7	$	6
AFUDC related to equity		27		27
Other capitalized interest		18		17
Total Sempra Energy Consolidated	$	52	$	50
SDG&E:
AFUDC related to debt	$	4	$	3
AFUDC related to equity		11		8
Total SDG&E	$	15	$	11
SoCalGas:
AFUDC related to debt	$	3	$	3
AFUDC related to equity		10		9
Total SoCalGas	$	13	$	12

COMPREHENSIVE INCOME

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

CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1)
SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
		Three months ended March 31, 2016 and 2015
		Foreign						Total
		currency				Pension and other		accumulated other
		translation		Financial		postretirement		comprehensive
		adjustments		instruments		benefits		income (loss)
2016:
Balance as of December 31, 2015		$	(582)	$	(137)	$	(87)	$	(806)
Other comprehensive income (loss) before
reclassifications			68		(82)		―		(14)
Amounts reclassified from accumulated other
comprehensive income			―		(2)		1		(1)
Net other comprehensive income (loss)			68		(84)		1		(15)
Balance as of March 31, 2016		$	(514)	$	(221)	$	(86)	$	(821)
2015:
Balance as of December 31, 2014		$	(322)	$	(90)	$	(85)	$	(497)
Other comprehensive loss before
reclassifications			(62)		(54)		―		(116)
Amounts reclassified from accumulated other
comprehensive income			―		(1)		1		―
Net other comprehensive (loss) income			(62)		(55)		1		(116)
Balance as of March 31, 2015		$	(384)	$	(145)	$	(84)	$	(613)
(1)	All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests.

RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
		Amounts reclassified
Details about accumulated		from accumulated other				Affected line item on Condensed
other comprehensive income (loss) components		comprehensive income (loss)				Consolidated Statements of Operations
		Three months ended March 31,
		2016		2015
Sempra Energy Consolidated:
Financial instruments:
Interest rate and foreign exchange instruments		$	4	$	6	Interest Expense
Interest rate instruments			3		3	Equity (Losses) Earnings, Before Income Tax
Interest rate and foreign exchange instruments			1		―	Equity Earnings, Net of Income Tax
Commodity contracts not subject
	to rate recovery		(7)		(7)	Revenues: Energy-Related Businesses
Total before income tax			1		2
			―		1	Income Tax Expense
Net of income tax			1		3
			(3)		(4)	Earnings Attributable to Noncontrolling Interests
		$	(2)	$	(1)

Pension and other postretirement benefits:
Amortization of actuarial loss		$	2	$	2	See note (1) below
			(1)		(1)	Income Tax Expense
Net of income tax		$	1	$	1

Total reclassifications for the period, net of tax		$	(1)	$	―
SDG&E:
Financial instruments:
Interest rate instruments		$	3	$	3	Interest Expense
			(3)		(3)	Earnings Attributable to Noncontrolling Interest
Total reclassifications for the period		$	―	$	―
(1)	Amounts are included in the computation of net periodic benefit cost (see "Pension and Other Postretirement Benefits" above).

For the three months ended March 31, 2016 and 2015, Other Comprehensive Income (Loss) (OCI), excluding amounts attributable to noncontrolling interests, at SDG&E and SoCalGas was negligible, and reclassifications out of AOCI to Net Income were also negligible for SoCalGas.

SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS

The following tables provide reconciliations of changes in Sempra Energy’s and SDG&E’s shareholders’ equity and noncontrolling interests for the three months ended March 31, 2016 and 2015. The only change in SoCalGas’ equity for the three months ended March 31, 2016 and 2015 was comprehensive income and a negligible amount of preferred stock dividends declared.

SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS – SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
			Sempra Energy		Non-
			shareholders’		controlling		Total
			equity		interests(1)		equity
Balance at December 31, 2015		$	11,809	$	770	$	12,579
Comprehensive income			304		11		315
Share-based compensation expense			13		―		13
Common stock dividends declared			(188)		―		(188)
Issuances of common stock			28		―		28
Repurchases of common stock			(54)		―		(54)
Tax benefit related to share-based compensation			34		―		34
Distributions to noncontrolling interests			―		(3)		(3)
Balance at March 31, 2016		$	11,946	$	778	$	12,724
Balance at December 31, 2014		$	11,326	$	774	$	12,100
Comprehensive income			321		8		329
Share-based compensation expense			13		―		13
Common stock dividends declared			(173)		―		(173)
Issuances of common stock			30		―		30
Repurchases of common stock			(65)		―		(65)
Tax benefit related to share-based compensation			52		―		52
Distributions to noncontrolling interests			―		(5)		(5)
Balance at March 31, 2015		$	11,504	$	777	$	12,281
(1)	Noncontrolling interests include the preferred stock of SoCalGas and other noncontrolling interests as listed in the table below under "Other Noncontrolling Interests."

SHAREHOLDER'S EQUITY AND NONCONTROLLING INTEREST – SDG&E
(Dollars in millions)
		SDG&E		Non-
		shareholder’s		controlling		Total
		equity		interest		equity
Balance at December 31, 2015	$	5,223	$	53	$	5,276
Comprehensive income (loss)		129		(1)		128
Distributions to noncontrolling interest		―		(1)		(1)
Balance at March 31, 2016	$	5,352	$	51	$	5,403
Balance at December 31, 2014	$	4,932	$	60	$	4,992
Comprehensive income		147		2		149
Distributions to noncontrolling interest		―		(3)		(3)
Balance at March 31, 2015	$	5,079	$	59	$	5,138

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 Condensed Consolidated Balance Sheets. Earnings or losses attributable to noncontrolling interests are separately identified on the Condensed Consolidated Statements of Operations, and comprehensive income or loss attributable to noncontrolling interests is separately identified on the Condensed Consolidated Statements of Comprehensive Income (Loss).

Preferred Stock

At Sempra Energy, the preferred stock of SoCalGas is presented as a noncontrolling interest and preferred stock dividends are charges against income related to noncontrolling interests. We provide additional information concerning preferred stock in Note 11 of the Notes to Consolidated Financial Statements in the Annual Report.

Other Noncontrolling Interests

At March 31, 2016 and December 31, 2015, we reported the following noncontrolling ownership interests held by others (not including preferred shareholders) recorded in Other Noncontrolling Interests in Total Equity on Sempra Energy’s Condensed Consolidated Balance Sheets:

OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
		Percent ownership held by others
		March 31,		December 31,			March 31,		December 31,
		2016		2015			2016		2015
SDG&E:
Otay Mesa VIE		100	%	100	%	$	51	$	53
Sempra South American Utilities:
Chilquinta Energía subsidiaries(1)		23.5 – 43.4		23.5 – 43.4			22		21
Luz del Sur		16.4		16.4			171		164
Tecsur		9.8		9.8			4		4
Sempra Mexico:
IEnova		18.9		18.9			470		468
Sempra Natural Gas:
Bay Gas Storage Company, Ltd.		9.1		9.1			25		25
Liberty Gas Storage, LLC		23.2		23.2			14		14
Southern Gas Transmission Company		49.0		49.0			1		1
Total Sempra Energy						$	758	$	750
(1)	Chilquinta Energía has four subsidiaries with noncontrolling interests held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.

TRANSACTIONS WITH AFFILIATES

Amounts due from and to unconsolidated affiliates at Sempra Energy Consolidated, SDG&E and SoCalGas are as follows:

AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
		March 31, 2016		December 31, 2015
Sempra Energy Consolidated:
Total due from various unconsolidated affiliates - current		$	7	$	6

Sempra South American Utilities(1):
Eletrans S.A. and Eletrans II S.A.:
4% Note(2)		$	76	$	72
Other related party receivables			1		―
Sempra Mexico(1):
Affiliate of joint venture with PEMEX:
Note due November 13, 2017(3)			3		3
Note due November 14, 2018(3)			42		42
Note due November 14, 2018(3)			34		34
Note due November 14, 2018(3)			8		8
Energía Sierra Juárez:
Note due June 15, 2018(4)			17		24
Sempra Natural Gas:
Cameron LNG JV			5		3
Total due from unconsolidated affiliates - noncurrent		$	186	$	186

Total due to various unconsolidated affiliates - current		$	(13)	$	(14)
SDG&E:
Total due from various unconsolidated affiliates - current		$	1	$	1

Sempra Energy		$	(35)	$	(34)
SoCalGas			(8)		(13)
Affiliate			(6)		(8)
Total due to unconsolidated affiliates - current		$	(49)	$	(55)

Income taxes due (to) from Sempra Energy(5)		$	(32)	$	28
SoCalGas:
Sempra Energy(6)		$	―	$	35
SDG&E			8		13
Total due from unconsolidated affiliates - current		$	8	$	48

Sempra Energy		$	(34)	$	―
Total due to unconsolidated affiliate - current		$	(34)	$	―

Income taxes due (to) from Sempra Energy(5)		$	(23)	$	1
(1)	Amounts include principal balances plus accumulated interest outstanding.
(2)	U.S. dollar-denominated loan, at a fixed interest rate with no stated maturity date, to provide project financing for the construction of transmission lines at Eletrans S.A. and Eletrans II S.A., both of which are joint ventures at Chilquinta Energía.
(3)	U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 450 basis points (4.94 percent at March 31, 2016), to finance the Los Ramones Norte pipeline project.
(4)	U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 637.5 basis points (6.81 percent at March 31, 2016), to finance the first phase of the Energía Sierra Juárez wind project.
(5)	SDG&E and SoCalGas are included in the consolidated income tax return of Sempra Energy and are allocated income tax expense from Sempra Energy in an amount equal to that which would result from each company having always filed a separate return.
(6)	At December 31, 2015, net receivable included outstanding advances to Sempra Energy of $50 million at an interest rate of 0.11 percent.

Revenues and cost of sales from unconsolidated affiliates are as follows:

REVENUES AND COST OF SALES FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended March 31,
	2016		2015
REVENUES
Sempra Energy Consolidated	$	5	$	8
SDG&E		3		3
SoCalGas		17		19
COST OF SALES
Sempra Energy Consolidated	$	30	$	19
SDG&E		14		5

Guarantees

Sempra Energy has provided guarantees to certain of its solar and wind farm joint ventures and entered into completion guarantees related to the financing of the Cameron LNG JV project, as we discuss above in Note 4 and in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report.

OTHER INCOME, NET
(Dollars in millions)
		Three months ended March 31,
		2016		2015
Sempra Energy Consolidated:
Allowance for equity funds used during construction		$	27	$	27
Investment gains(1)			10		9
Electrical infrastructure relocation income(2)			1		―
Gains on interest rate and foreign exchange instruments, net			3		―
Sale of other investments			1		―
Foreign currency transaction losses			(2)		(1)
Regulatory interest, net(3)			2		1
Sundry, net			7		3
Total		$	49	$	39
SDG&E:
Allowance for equity funds used during construction		$	11	$	8
Regulatory interest, net(3)			2		1
Sundry, net			1		―
Total		$	14	$	9
SoCalGas:
Allowance for equity funds used during construction		$	10	$	9
Sundry, net			―		(1)
Total		$	10	$	8
(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)	Income at Luz del Sur associated with the relocation of electrical infrastructure.
(3)	Interest on regulatory balancing accounts.

INCOME TAXES

INCOME TAX EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
			Effective				Effective
		Income tax	income			Income tax	income
		expense	tax rate			expense	tax rate
		Three months ended March 31,
		2016				2015
Sempra Energy Consolidated	$	142	31	%	$	163	27	%
SDG&E		72	36			88	37
SoCalGas		87	31			95	31

Sempra Energy, SDG&E and SoCalGas record income taxes for interim periods utilizing a forecasted effective tax rate anticipated for the full year, as required by U.S. GAAP. The income tax effect of items that can be reliably forecasted is factored into the forecasted effective tax rate, and the impact is recognized proportionately over the year. Items that cannot be reliably forecasted (e.g., resolution of prior years’ income tax items, remeasurement of deferred tax asset valuation allowances, Mexican currency translation and inflation adjustments, and deferred income tax benefit associated with the impairment of a book investment) are recorded in the interim period in which they actually occur, which can result in variability in income tax expense.

Sempra Energy’s income tax expense in the three months ended March 31, 2016 includes deferred income tax expense related to Sempra Mexico’s power plant held for sale, as we discuss in Note 3.

For SDG&E and SoCalGas, the California Public Utilities Commission (CPUC) requires flow-through rate-making treatment for the current income tax benefit or expense arising from certain property-related and other temporary differences between the treatment for financial reporting and income tax, which will reverse over time. Under the regulatory accounting treatment required for these flow-through temporary differences, deferred income tax assets and liabilities are not recorded to deferred income tax expense, but rather to a regulatory asset or liability, which impacts the current effective income tax rate. 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:

repairs expenditures related to a certain portion of utility plant assets
the equity portion of AFUDC
a portion of the cost of removal of utility plant assets
utility self-developed software expenditures
depreciation on a certain portion of utility plant assets

state income taxes

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

We provide additional information about our accounting for income taxes in Notes 1 and 6 of the Notes to Consolidated Financial Statements in the Annual Report.

DEBT AND CREDIT FACILITIES	3 Months Ended
DEBT AND CREDIT FACILITIES	Mar. 31, 2016
Debt Disclosure [Abstract]
Debt and Credit Facilities	NOTE 6. DEBT AND CREDIT FACILITIES LINES OF CREDIT At March 31, 2016, Sempra Energy Consolidated had an aggregate of $4.2 billion in three primary committed lines of credit for Sempra Energy, Sempra Global and the California Utilities to provide liquidity and to support commercial paper, the major components of which we detail below. Available unused credit on these lines at March 31, 2016 was approximately $3.1 billion. Our foreign operations have additional general purpose credit facilities aggregating $1.1 billion at March 31, 2016. Available unused credit on these lines totaled $876 million at March 31, 2016. Sempra Energy Sempra Energy has a $1 billion, five-year syndicated revolving credit agreement expiring in October 2020. Citibank, N.A. serves as administrative agent for the syndicate of 20 lenders, and no single lender has greater than a 7-percent share. Borrowings bear interest at benchmark rates plus a margin that varies with 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 March 31, 2016, Sempra Energy was in compliance with this and all other financial covenants under the credit facility. 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 March 31, 2016, Sempra Energy had no outstanding borrowings or letters of credit supported by the facility. Sempra Global Sempra Global has a $2.21 billion, five-year syndicated revolving credit agreement expiring in October 2020. Citibank, N.A. serves as administrative agent for the syndicate of 20 lenders, and 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 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 March 31, 2016, Sempra Energy was in compliance with this and all other financial covenants under the credit facility. At March 31, 2016, Sempra Global had $879 million of commercial paper outstanding supported by the facility and $1.33 billion of available unused credit on the line. California Utilities SDG&E and SoCalGas have a combined $1 billion, five-year syndicated revolving credit agreement expiring in October 2020. JPMorgan Chase Bank, N.A. serves as administrative agent for the syndicate of 20 lenders, and no single lender has greater than a 7-percent share. The agreement permits each utility to individually borrow up to $750 million, subject to a combined limit of $1 billion 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 $250 million for both utilities. The amount of borrowings otherwise available under the facility is reduced by the amount of outstanding letters of credit. Borrowings bear interest at benchmark rates plus a margin that varies with the borrowing utility’s credit rating. 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. At March 31, 2016, the California Utilities were in compliance with this and all other financial covenants under the credit facility. 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 March 31, 2016, SDG&E and SoCalGas had $166 million and $5 million, respectively, of commercial paper outstanding, supported by the facility. Available unused credit on the line at March 31, 2016 was $584 million and $745 million at SDG&E and SoCalGas, respectively, subject to the $1 billion maximum combined credit limit. Sempra South American Utilities Sempra South American Utilities has Peruvian Sol- and Chilean Peso-denominated credit facilities aggregating $547 million U.S. dollar equivalent, expiring between 2016 and 2018. The credit facilities were entered into to finance working capital and for general corporate purposes. The Peruvian facilities require a debt to equity ratio of no more than 170 percent. At March 31, 2016, Sempra South American Utilities was in compliance with this financial covenant under the credit facilities. At March 31, 2016, Sempra South American Utilities had outstanding borrowings of $165 million and bank guarantees of $15 million against the Peruvian facilities, and $255 million of available unused credit. There were no outstanding borrowings at March 31, 2016 under the $112 million Chilean facility. Sempra Mexico IEnova has a $600 million, five-year revolving credit agreement expiring in August 2020. The lenders are Banco Santander (México), S.A., Institución de Banca Múltiple, Grupo Financiero Santander México, The Bank of Tokyo - Mitsubishi UFJ, LTD., The Bank of Nova Scotia and Sumitomo Mitsui Banking Corporation. At March 31, 2016, IEnova had $91 million of outstanding borrowings supported by the facility, and available unused credit on the line was $509 million. WEIGHTED AVERAGE INTEREST RATES The weighted average interest rates on the total short-term debt at Sempra Energy Consolidated were 1.12 percent and 1.09 percent at March 31, 2016 and December 31, 2015, respectively. At March 31, 2016, the weighted average interest rates on total short-term debt at SDG&E and SoCalGas were 1.02 percent and 0.40 percent, respectively. The weighted average interest rate on total short-term debt at SDG&E was 1.01 percent at December 31, 2015. LONG-TERM DEBT SDG&E In April 2016, SDG&E notified bondholders that it intends to redeem, prior to maturity, certain outstanding long-term debt instruments with a total principal amount of $105 million. At March 31, 2016, the debt remains classified as long-term on Sempra Energy’s and SDG&E’s Condensed Consolidated Balance Sheets. These instruments have a coupon rate of 5 percent and a maturity date of December 2027. SDG&E expects to repay the debt in the second quarter of 2016. INTEREST RATE SWAPS We discuss our fair value interest rate swaps and interest rate swaps to hedge cash flows in Note 7.

DERIVATIVE FINANCIAL INSTRUMENTS

3 Months Ended

Mar. 31, 2016

Derivative Instruments And Hedging Activities Disclosure [Abstract]

Derivative Financial Instruments

NOTE 7. DERIVATIVE FINANCIAL INSTRUMENTS

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

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

In all other cases, we record derivatives at fair value on the Condensed Consolidated Balance Sheets. We designate each derivative as (1) a cash flow hedge, (2) a fair value hedge, or (3) undesignated. Depending on the applicability of hedge accounting and, for the California Utilities and other operations subject to regulatory accounting, the requirement to pass impacts through to customers, the impact of derivative instruments may be offset in other comprehensive income (loss) (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 Condensed Consolidated Statements of Cash Flows.

HEDGE ACCOUNTING

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

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 instrument 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, as follows:

The California Utilities use energy derivatives, both natural gas and electricity, for the benefit of customers, with the objective of managing price risk and basis risks, and stabilizing and lowering natural gas and electricity costs. These derivatives include fixed price natural gas and electricity positions, options, and basis risk instruments, which are either exchange-traded or over-the-counter financial instruments, or bilateral physical transactions. This activity is governed by risk management and transacting activity plans that have been filed with and approved by the CPUC. Natural gas and electricity derivative activities are recorded as commodity costs that are offset by regulatory account balances and are recovered in rates. Net commodity cost impacts on the Condensed Consolidated Statements of Operations are reflected in Cost of Electric Fuel and Purchased Power or in Cost of Natural Gas.
SDG&E is allocated and may purchase 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, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations.
Sempra Mexico and Sempra Natural Gas may use natural gas and electricity derivatives, as appropriate, to optimize the earnings of their assets which support the following businesses: liquefied natural gas (LNG), natural gas transportation, power generation, and Sempra Natural Gas’ storage. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues or in Cost of Natural Gas, Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations. Certain of these derivatives may also be designated as cash flow hedges. 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 Condensed Consolidated Statements of Operations.

From time to time, our various businesses, including the California Utilities, may use other energy derivatives to hedge exposures such as the price of vehicle fuel.

We summarize net energy derivative volumes at March 31, 2016 and December 31, 2015 as follows:

NET ENERGY DERIVATIVE VOLUMES
(Quantities in millions)
			March 31,	December 31,
Segment and Commodity		Unit of measure	2016	2015
California Utilities:
SDG&E:
Natural gas		MMBtu(1)	60	70
Electricity		MWh(2)	―	1
Congestion revenue rights		MWh	33	36
SoCalGas – natural gas		MMBtu	―	1

Energy-Related Businesses:
Sempra Natural Gas – natural gas		MMBtu	39	43
(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 contractual obligations and assets, such as natural gas purchases and sales.

INTEREST RATE DERIVATIVES

We are exposed to interest rates primarily as a result of our current and expected use of financing. 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, 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. Interest rate derivatives are generally accounted for as hedges, and 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 energy derivatives. Separately, Otay Mesa VIE has entered into interest rate swap agreements, designated as cash flow hedges, to moderate its exposure to interest rate changes.

At March 31, 2016 and December 31, 2015, the net notional amounts of our interest rate derivatives, excluding the cross-currency swaps discussed below, were:

INTEREST RATE DERIVATIVES
(Dollars in millions)
		March 31, 2016			December 31, 2015
		Notional debt		Maturities	Notional debt		Maturities
Sempra Energy Consolidated:
Cash flow hedges(1)		$	381	2016-2028	$	384	2016-2028
Fair value hedges			300	2016		300	2016
SDG&E:
Cash flow hedge(1)			312	2016-2019		315	2016-2019
(1)	Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE.

FOREIGN CURRENCY DERIVATIVES

We utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries and joint ventures. These cash flow hedges exchange our Mexican-peso denominated principal and interest payments into the U.S. dollar and swap Mexican variable interest rates for U.S. fixed interest rates.

We are also exposed to exchange rate movements at our Mexican subsidiaries and joint ventures, which have U.S. dollar denominated cash balances, receivables, payables and debt (monetary assets and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. They also have deferred income tax assets and liabilities denominated in the Mexican peso, which must be translated to U.S. dollars for financial reporting purposes. In addition, monetary assets and liabilities and certain nonmonetary assets and liabilities are adjusted for Mexican inflation for Mexican income tax purposes. We utilize foreign currency derivatives as a means to manage the risk of exposure to significant fluctuations in our income tax expense and equity earnings from these impacts. In January 2016, we entered into foreign currency derivatives with a notional amount totaling $550 million.

At March 31, 2016 and December 31, 2015, the net notional amounts of our foreign currency derivatives were:

FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	March 31, 2016			December 31, 2015
	Notional debt		Maturities	Notional debt		Maturities
Sempra Mexico:
Cross-currency swaps	$	408	2018-2023	$	408	2018-2023
Other foreign currency derivatives		550	2016		―	―

In addition, Sempra South American Utilities use foreign currency derivatives at its subsidiaries and joint ventures as a means to manage foreign currency rate risk. We discuss such swaps at Chilquinta Energía’s Eletrans joint venture investment in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report.

FINANCIAL STATEMENT PRESENTATION

Each Condensed Consolidated Balance Sheet reflects the offsetting of net derivative positions and cash collateral with the same counterparty when a legal right of offset exists. The following tables provide the fair values of derivative instruments on the Condensed Consolidated Balance Sheets at March 31, 2016 and December 31, 2015, including the amount of cash collateral receivables that were not offset, as the cash collateral is in excess of liability positions.

DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
		March 31, 2016
									Deferred
									credits
			Current				Current		and other
			assets:				liabilities:		liabilities:
			Fixed-price				Fixed-price		Fixed-price
			contracts		Other		contracts		contracts
			and other		assets:		and other		and other
			derivatives(1)		Sundry		derivatives(2)		derivatives
Sempra Energy Consolidated:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments(3)		$	5	$	―	$	(15)	$	(166)
Derivatives not designated as hedging instruments:
Interest rate and foreign exchange instruments			3		―		―		―
Commodity contracts not subject to rate recovery			144		20		(144)		(9)
Associated offsetting commodity contracts			(135)		(9)		135		9
Associated offsetting cash collateral			―		―		7		―
Commodity contracts subject to rate recovery			23		51		(68)		(61)
Associated offsetting commodity contracts			(4)		(1)		4		1
Associated offsetting cash collateral			―		―		31		24
Net amounts presented on the balance sheet			36		61		(50)		(202)
Additional cash collateral for commodity contracts
not subject to rate recovery			20		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			32		―		―		―
Total(4)		$	88	$	61	$	(50)	$	(202)
SDG&E:
Derivatives designated as hedging instruments:
Interest rate instruments(3)		$	―	$	―	$	(14)	$	(25)
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery			―		―		(1)		―
Associated offsetting cash collateral			―		―		1		―
Commodity contracts subject to rate recovery			20		51		(65)		(61)
Associated offsetting commodity contracts			(2)		(1)		2		1
Associated offsetting cash collateral			―		―		31		24
Net amounts presented on the balance sheet			18		50		(46)		(61)
Additional cash collateral for commodity contracts
not subject to rate recovery			2		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			30		―		―		―
Total(4)		$	50	$	50	$	(46)	$	(61)
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery		$	―	$	―	$	(1)	$	―
Associated offsetting cash collateral			―		―		1		―
Commodity contracts subject to rate recovery			3		―		(3)		―
Associated offsetting commodity contracts			(2)		―		2		―
Net amounts presented on the balance sheet			1		―		(1)		―
Additional cash collateral for commodity contracts
not subject to rate recovery			1		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			2		―		―		―
Total		$	4	$	―	$	(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.
(4)	Normal purchase contracts previously measured at fair value are excluded.

DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
		December 31, 2015
									Deferred
									credits
			Current				Current		and other
			assets:				liabilities:		liabilities:
			Fixed-price				Fixed-price		Fixed-price
			contracts		Other		contracts		contracts
			and other		assets:		and other		and other
			derivatives(1)		Sundry		derivatives(2)		derivatives
Sempra Energy Consolidated:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments(3)		$	4	$	1	$	(15)	$	(156)
Commodity contracts not subject to rate recovery			13		―		―		―
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery			245		32		(239)		(21)
Associated offsetting commodity contracts			(232)		(20)		232		20
Associated offsetting cash collateral			(6)		―		4		―
Commodity contracts subject to rate recovery			28		49		(61)		(64)
Associated offsetting commodity contracts			(2)		(2)		2		2
Associated offsetting cash collateral			―		―		28		26
Net amounts presented on the balance sheet			50		60		(49)		(193)
Additional cash collateral for commodity contracts
not subject to rate recovery			2		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			28		―		―		―
Total(4)		$	80	$	60	$	(49)	$	(193)
SDG&E:
Derivatives designated as hedging instruments:
Interest rate instruments(3)		$	―	$	―	$	(14)	$	(23)
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery			―		―		(1)		―
Associated offsetting cash collateral			―		―		1		―
Commodity contracts subject to rate recovery			27		49		(60)		(64)
Associated offsetting commodity contracts			(2)		(2)		2		2
Associated offsetting cash collateral			―		―		28		26
Net amounts presented on the balance sheet			25		47		(44)		(59)
Additional cash collateral for commodity contracts
not subject to rate recovery			1		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			27		―		―		―
Total(4)		$	53	$	47	$	(44)	$	(59)
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery		$	―	$	―	$	(1)	$	―
Associated offsetting cash collateral			―		―		1		―
Commodity contracts subject to rate recovery			1		―		(1)		―
Net amounts presented on the balance sheet			1		―		(1)		―
Additional cash collateral for commodity contracts
subject to rate recovery			1		―		―		―
Total		$	2	$	―	$	(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.
(4)	Normal purchase contracts previously measured at fair value are excluded.

The effects of derivative instruments designated as hedges on the Condensed Consolidated Statements of Operations and in OCI and AOCI for the three months ended March 31 were

FAIR VALUE HEDGE IMPACTS
(Dollars in millions)
			Pretax gain on derivatives
			recognized in earnings
			Three months ended March 31,
		Location	2016		2015
Sempra Energy Consolidated:
Interest rate instruments		Interest Expense	$	2	$	2
Interest rate instruments		Other Income, Net		―		1
Total(1)			$	2	$	3
(1)	There was no hedge ineffectiveness in either the three months ended March 31, 2016 or 2015. All other 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 and recorded in Other Income, Net.

CASH FLOW HEDGE IMPACTS
(Dollars in millions)
		Pretax (loss) gain					Pretax (loss) gain reclassified
		recognized in OCI					from AOCI into earnings
		(effective portion)					(effective portion)
		Three months ended March 31,					Three months ended March 31,
		2016		2015		Location	2016		2015
Sempra Energy Consolidated:
Interest rate and foreign
exchange instruments(1)		$	(11)	$	(18)	Interest Expense	$	(4)	$	(6)
						Equity (Losses) Earnings,
Interest rate instruments			(137)		(78)	Before Income Tax		(3)		(3)
Interest rate and foreign						Equity Earnings,
exchange instruments			(18)		―	Net of Income Tax		(1)		―
Commodity contracts not						Revenues: Energy-Related
subject to rate recovery			1		(1)	Businesses		7		7
Total(2)		$	(165)	$	(97)		$	(1)	$	(2)
SDG&E:
Interest rate instruments(1)(2)		$	(5)	$	(5)	Interest Expense	$	(3)	$	(3)
(1)	Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.
(2)	Amounts include negligible hedge ineffectiveness in the three months ended March 31, 2016 and 2015.

For Sempra Energy Consolidated, we expect that losses of $21 million, which are net of income tax benefit, that are currently recorded in AOCI (including $12 million in noncontrolling interests, substantially all of which is related to Otay Mesa VIE at SDG&E) 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.

SoCalGas expects that negligible losses, 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 remaining term over which we are hedging exposure to the variability of cash flows at March 31, 2016 is approximately 13 years and 3 years for Sempra Energy Consolidated and SDG&E, respectively. The maximum remaining term for which we are hedging exposure to the variability of cash flows at our equity method investees is 19 years.

The effects of derivative instruments not designated as hedging instruments on the Condensed Consolidated Statements of Operations for the three months ended March 31 were

UNDESIGNATED DERIVATIVE IMPACTS
(Dollars in millions)
		Pretax gain (loss) on derivatives
		recognized in earnings
		Three months ended March 31,
	Location	2016		2015
Sempra Energy Consolidated:
Foreign exchange instruments	Other Income, Net	$	3	$	―
Foreign exchange instruments	Equity Earnings,
	Net of Income Tax		2		(1)
Commodity contracts not subject	Revenues: Energy-Related
to rate recovery	Businesses		(1)		3
Commodity contracts subject	Cost of Electric Fuel
to rate recovery	and Purchased Power		(12)		(20)
Commodity contracts subject
to rate recovery	Cost of Natural Gas		(1)		1
Total		$	(9)	$	(17)
SDG&E:
Commodity contracts subject	Cost of Electric Fuel
to rate recovery	and Purchased Power	$	(12)	$	(20)
SoCalGas:
Commodity contracts subject
to rate recovery	Cost of Natural Gas	$	(1)	$	1

CONTINGENT FEATURES

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

For Sempra Energy Consolidated, the total fair value of this group of derivative instruments in a net liability position is $6 million at both March 31, 2016 and December 31, 2015. At March 31, 2016, if the credit ratings of Sempra Energy were reduced below investment grade, $7 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 is $5 million at both March 31, 2016 and December 31, 2015. At March 31, 2016, if the credit ratings of SDG&E were reduced below investment grade, $6 million of additional assets could be required to be posted as collateral for these derivative contracts.

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

The entire disclosure for derivative instruments and hedging activities including, but not limited to, risk management strategies, non-hedging derivative instruments, assets, liabilities, revenue and expenses, and methodologies and assumptions used in determining the amounts.

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-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5580258-113959

Reference 16: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4E
-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5624181-113959

Reference 17: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 25
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6886632&loc=d3e76258-113986

Reference 18: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=56946850&loc=d3e41638-113959

Reference 19: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(n))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

FAIR VALUE MEASUREMENTS

3 Months Ended

Mar. 31, 2016

Fair Value Disclosures [Abstract]

Fair Value Measurements

NOTE 8. FAIR VALUE MEASUREMENTS

We discuss the valuation techniques and inputs we use to measure fair value and the definition of the three levels of the fair value hierarchy in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. We have not changed the valuation techniques or types of inputs we use to measure fair value during the three months ended March 31, 2016.

Recurring Fair Value Measures

The three tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis at March 31, 2016 and December 31, 2015. 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 presented in accordance with our netting policy, as we discuss in Note 7 under “Financial Statement Presentation.”

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

Our financial assets and liabilities that were accounted for at fair value on a recurring basis at March 31, 2016 and December 31, 2015 in the tables below include the following:

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

For commodity contracts, interest rate derivatives and foreign exchange instruments, we primarily use a market approach with market participant assumptions to value these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation techniques. These inputs can be readily observable, market corroborated, or generally unobservable. We have exchange-traded derivatives that are valued based on quoted prices in active markets for the identical instruments (Level 1). We also may have other commodity derivatives that are valued using industry standard models that consider quoted forward prices for commodities, time value, current market and contractual prices for the underlying instruments, volatility factors, and other relevant economic measures (Level 2). Level 3 recurring items relate to CRRs and long-term, fixed-price electricity positions at SDG&E, as we discuss below under “Level 3 Information.”
Rabbi Trust investments include marketable securities that we value using a market approach based on closing prices reported in the active market in which the identical security is traded (Level 1). These investments in marketable securities were negligible at both March 31, 2016 and December 31, 2015.

There were no transfers into or out of Level 1, Level 2 or Level 3 for Sempra Energy Consolidated, SDG&E or SoCalGas during the periods presented.

RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
		Fair value at March 31, 2016
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Nuclear decommissioning trusts:
Equity securities		$	623	$	―	$	―	$	―	$	623
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			62		43		―		―		105
Municipal bonds			―		156		―		―		156
Other securities			―		190		―		―		190
Total debt securities			62		389		―		―		451
Total nuclear decommissioning trusts(2)			685		389		―		―		1,074
Interest rate and foreign exchange instruments			―		8		―		―		8
Commodity contracts not subject to rate recovery			1		19		―		20		40
Commodity contracts subject to rate recovery			―		1		68		32		101
Total		$	686	$	417	$	68	$	52	$	1,223

Liabilities:
Interest rate and foreign exchange instruments		$	―	$	181	$	―	$	―	$	181
Commodity contracts not subject to rate recovery			3		6		―		(7)		2
Commodity contracts subject to rate recovery			―		67		57		(55)		69
Total		$	3	$	254	$	57	$	(62)	$	252

		Fair value at December 31, 2015
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Nuclear decommissioning trusts:
Equity securities		$	619	$	―	$	―	$	―	$	619
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			47		44		―		―		91
Municipal bonds			―		156		―		―		156
Other securities			―		182		―		―		182
Total debt securities			47		382		―		―		429
Total nuclear decommissioning trusts(2)			666		382		―		―		1,048
Interest rate and foreign exchange instruments			―		5		―		―		5
Commodity contracts not subject to rate recovery			22		16		―		(4)		34
Commodity contracts subject to rate recovery			―		1		72		28		101
Total		$	688	$	404	$	72	$	24	$	1,188

Liabilities:
Interest rate and foreign exchange instruments		$	―	$	171	$	―	$	―	$	171
Commodity contracts not subject to rate recovery			5		3		―		(4)		4
Commodity contracts subject to rate recovery			―		68		53		(54)		67
Total		$	5	$	242	$	53	$	(58)	$	242
(1)	Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.
(2)	Excludes cash balances and cash equivalents.

RECURRING FAIR VALUE MEASURES – SDG&E
(Dollars in millions)
		Fair value at March 31, 2016
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Nuclear decommissioning trusts:
Equity securities		$	623	$	―	$	―	$	―	$	623
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			62		43		―		―		105
Municipal bonds			―		156		―		―		156
Other securities			―		190		―		―		190
Total debt securities			62		389		―		―		451
Total nuclear decommissioning trusts(2)			685		389		―		―		1,074
Commodity contracts not subject to rate recovery			―		―		―		2		2
Commodity contracts subject to rate recovery			―		―		68		30		98
Total		$	685	$	389	$	68	$	32	$	1,174

Liabilities:
Interest rate instruments		$	―	$	39	$	―	$	―	$	39
Commodity contracts not subject to rate recovery			1		―		―		(1)		―
Commodity contracts subject to rate recovery			―		66		57		(55)		68
Total		$	1	$	105	$	57	$	(56)	$	107

		Fair value at December 31, 2015
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Nuclear decommissioning trusts:
Equity securities		$	619	$	―	$	―	$	―	$	619
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			47		44		―		―		91
Municipal bonds			―		156		―		―		156
Other securities			―		182		―		―		182
Total debt securities			47		382		―		―		429
Total nuclear decommissioning trusts(2)			666		382		―		―		1,048
Commodity contracts not subject to rate recovery			―		―		―		1		1
Commodity contracts subject to rate recovery			―		―		72		27		99
Total		$	666	$	382	$	72	$	28	$	1,148

Liabilities:
Interest rate instruments		$	―	$	37	$	―	$	―	$	37
Commodity contracts not subject to rate recovery			1		―		―		(1)		―
Commodity contracts subject to rate recovery			―		67		53		(54)		66
Total		$	1	$	104	$	53	$	(55)	$	103
(1)	Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.
(2)	Excludes cash balances and cash equivalents.

RECURRING FAIR VALUE MEASURES – SOCALGAS
(Dollars in millions)
		Fair value at March 31, 2016
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Commodity contracts not subject to rate recovery		$	―	$	―	$	―	$	1	$	1
Commodity contracts subject to rate recovery			―		1		―		2		3
Total		$	―	$	1	$	―	$	3	$	4

Liabilities:
Commodity contracts not subject to rate recovery		$	1	$	―	$	―	$	(1)	$	―
Commodity contracts subject to rate recovery			―		1		―		―		1
Total		$	1	$	1	$	―	$	(1)	$	1

		Fair value at December 31, 2015
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Commodity contracts subject to rate recovery		$	―	$	1	$	―	$	1	$	2
Total		$	―	$	1	$	―	$	1	$	2

Liabilities:
Commodity contracts not subject to rate recovery		$	1	$	―	$	―	$	(1)	$	―
Commodity contracts subject to rate recovery			―		1		―		―		1
Total		$	1	$	1	$	―	$	(1)	$	1
(1)	Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.

Level 3 Information

The following table sets forth reconciliations of changes in the fair value of congestion revenue rights (CRRs) and long-term, fixed-price electricity positions classified as Level 3 in the fair value hierarchy for Sempra Energy Consolidated and SDG&E:

LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Three months ended March 31,
	2016		2015
Balance as of January 1	$	19	$	107
Realized and unrealized (losses) gains		(1)		6
Settlements		(7)		(11)
Balance as of March 31	$	11	$	102
Change in unrealized (losses) gains relating to
instruments still held at March 31	$	(1)	$	1

SDG&E’s Energy and Fuel Procurement department, in conjunction with SDG&E’s finance group, is responsible for determining the appropriate fair value methodologies used to value and classify CRRs and long-term, fixed-price electricity positions on an ongoing basis. Inputs used to determine the fair value of CRRs and fixed-price electricity positions are reviewed and compared with market conditions to determine reasonableness. SDG&E expects all costs related to these instruments to be recoverable through customer rates. As such, there is no impact to earnings from changes in the fair value of these instruments.

CRRs are recorded at fair value based almost entirely on the most current auction prices published by the California Independent System Operator (CAISO), an objective source. Annual auction prices are published once a year, typically in the middle of November, and remain in effect for the following year. The impact associated with discounting is negligible. Because auction prices are a less observable input, these instruments are classified as Level 3. The fair value of these instruments is derived from auction price differences between two locations. From January 1, 2016 to December 31, 2016, the auction prices range from $(24) per MWh to $10 per MWh at a given location, and from January 1, 2015 to December 31, 2015, the auction prices ranged from $(16) per MWh to $8 per MWh at a given location. Positive values between two locations represent expected future reductions in congestion costs, whereas negative values between two locations represent expected future charges. Valuation of our CRRs is sensitive to a change in auction price. If auction prices at one location increase (decrease) relative to another location, this could result in a higher (lower) fair value measurement. We summarize CRR volumes in Note 7.

Long-term, fixed-price electricity positions that are valued using significant unobservable data are classified as Level 3 because the contract terms relate to a delivery location or tenor for which observable market rate information is not available. The fair value of the net electricity positions classified as Level 3 is derived from a discounted cash flow model using market electricity forward price inputs. At March 31, 2016, these electricity forward prices range from $15.85 per MWh to $57.43 per MWh. A significant increase or decrease in market electricity forward prices would result in a significantly higher or lower fair value, respectively. We summarize long-term, fixed-price electricity position volumes in Note 7.

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

Fair Value of Financial Instruments

The fair values of certain of our financial instruments (cash, temporary investments, accounts and notes receivable, current amounts due to/from unconsolidated affiliates, dividends and accounts payable, short-term debt and customer deposits) approximate their carrying amounts because of the short-term nature of these instruments. Investments in life insurance contracts that we hold in support of our Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans are carried at cash surrender values, which represent the amount of cash that could be realized under the contracts. The following table provides the carrying amounts and fair values of certain other financial instruments that are not recorded at fair value on the Condensed Consolidated Balance Sheets at March 31, 2016 and December 31, 2015:

FAIR VALUE OF FINANCIAL INSTRUMENTS
(Dollars in millions)
		March 31, 2016
		Carrying		Fair value
		amount		Level 1		Level 2		Level 3		Total
Sempra Energy Consolidated:
Noncurrent due from unconsolidated affiliates(1)		$	173	$	―	$	92	$	72	$	164
Total long-term debt(2)(3)			13,761		―		14,363		652		15,015
Preferred stock of subsidiary			20		―		23		―		23
SDG&E:
Total long-term debt(3)(4)		$	4,285	$	―	$	4,517	$	312	$	4,829
SoCalGas:
Total long-term debt(5)		$	2,513	$	―	$	2,731	$	―	$	2,731
Preferred stock			22		―		25		―		25

		December 31, 2015
		Carrying		Fair value
		amount		Level 1		Level 2		Level 3		Total
Sempra Energy Consolidated:
Noncurrent due from unconsolidated affiliates(1)		$	175	$	―	$	97	$	69	$	166
Total long-term debt(2)(3)			13,761		―		13,985		648		14,633
Preferred stock of subsidiary			20		―		23		―		23
SDG&E:
Total long-term debt(3)(4)		$	4,304	$	―	$	4,355	$	315	$	4,670
SoCalGas:
Total long-term debt(5)		$	2,513	$	―	$	2,621	$	―	$	2,621
Preferred stock			22		―		25		―		25
(1)	Excluding accumulated interest outstanding of $13 million and $11 million at March 31, 2016 and December 31, 2015, respectively.
(2)	Before reductions for unamortized discount (net of premium) and debt issuance costs of $106 million and $107 million at March 31, 2016 and December 31, 2015, respectively, and excluding build-to-suit and capital lease obligations of $386 million and $387 million at March 31, 2016 and December 31, 2015, respectively. We discuss our long-term debt in Note 6 above and in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report.
(3)	Level 3 instruments include $312 million and $315 million at March 31, 2016 and December 31, 2015, respectively, related to Otay Mesa VIE.
(4)	Before reductions for unamortized discount and debt issuance costs of $43 million at March 31, 2016 and December 31, 2015, and excluding capital lease obligations of $243 million and $244 million at March 31, 2016 and December 31, 2015, respectively.
(5)	Before reductions for unamortized discount and debt issuance costs of $24 million at March 31, 2016 and December 31, 2015, and excluding capital lease obligations of $1 million at March 31, 2016 and December 31, 2015.

We base the fair value of certain noncurrent amounts due from unconsolidated affiliates, long-term debt and preferred stock on a market approach using quoted market prices for identical or similar securities in thinly-traded markets (Level 2). We value other noncurrent amounts due from unconsolidated affiliates of Sempra South American Utilities using a perpetuity approach based on the obligation’s fixed interest rate, the absence of a stated maturity date and a discount rate reflecting local borrowing costs (Level 3). We value other long-term debt using an income approach based on the present value of estimated future cash flows discounted at rates available for similar securities (Level 3).

We provide the fair values for the securities held in the nuclear decommissioning trust funds related to the San Onofre Nuclear Generating Station (SONGS) in Note 9 below.

Non-Recurring Fair Value Measures – Sempra Energy Consolidated

Sempra Natural Gas – Rockies Express

In March 2016, Sempra Natural Gas agreed to sell its 25-percent interest in Rockies Express to a subsidiary of Tallgrass Development, LP for cash consideration of $440 million, subject to adjustment at closing. We consider the sale price for our equity interest in Rockies Express to be a market participants’ view of the total value of Rockies Express and have measured the fair value of our investment based on the equity sale price. In March 2016, we recorded a noncash impairment of our investment in Rockies Express of $44 million ($27 million after-tax), which is included in Equity Earnings, Before Income Tax, on the Condensed Consolidated Statement of Operations for the three months ended March 31, 2016. Use of this market participant input as the indicator of fair value is a Level 2 measurement in the fair value hierarchy.

The following table summarizes significant inputs impacting non-recurring fair value measures related to our investment in Rockies Express:

NON-RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
		Estimated				Fair	% of	Inputs used to
		fair				value	fair value	develop	Range of
		value			Valuation technique	hierarchy	measurement	measurement	inputs
Investment in
Rockies Express		$	440	(1)	Market approach	Level 2	100%	Equity sale price	100%
(1)	At measurement date of March 29, 2016. At March 31, 2016, our investment in Rockies Express had a carrying value of $436 million, reflecting subsequent equity method activity to record a distribution.

Sempra Utilities' Regulatory Matters

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

+ References + Details

CALIFORNIA UTILITIES' REGULATORY MATTERS

3 Months Ended

Mar. 31, 2016

Regulated Operations [Abstract]

NOTE 9. SAN ONOFRE NUCLEAR GENERATING STATION (SONGS)

SDG&E has a 20-percent ownership interest in SONGS, a nuclear generating facility near San Clemente, California, which ceased operations in June 2013. On June 6, 2013, after an extended outage beginning in 2012, Southern California Edison Company (Edison), the majority owner and operator of SONGS, notified SDG&E that it had reached a decision to permanently retire SONGS and seek approval from the Nuclear Regulatory Commission (NRC) to start the decommissioning activities for the entire facility. SONGS is subject to the jurisdiction of the NRC and the CPUC.

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

SONGS Steam Generator Replacement Project

As part of the Steam Generator Replacement Project (SGRP), the steam generators were replaced in SONGS Units 2 and 3, and the Units returned to service in 2010 and 2011, respectively. Both Units were shut down in early 2012 after a water leak occurred in the Unit 3 steam generator. Edison concluded that the leak was due to unexpected wear from tube-to-tube contact. At the time the leak was identified, Edison also inspected and tested Unit 2 and subsequently found unexpected tube wear in Unit 2’s steam generator. These issues with the steam generators ultimately resulted in Edison’s decision to permanently retire SONGS.

The replacement steam generators were designed and provided by Mitsubishi Heavy Industries, Ltd., Mitsubishi Nuclear Energy Systems, Inc., and Mitsubishi Heavy Industries America, Inc. (collectively MHI). In July 2013, SDG&E filed a lawsuit against MHI seeking to recover damages SDG&E has incurred and will incur related to the design defects in the steam generators. In October 2013, Edison instituted binding arbitration proceedings against MHI seeking damages as well. SDG&E is participating in the arbitration as a claimant and respondent. We discuss these proceedings in Note 11.

Settlement Agreement to Resolve the CPUC’s Order Instituting Investigation (OII) into the SONGS Outage (SONGS OII)

In November 2012, in response to the outage, the CPUC issued the SONGS OII, which was intended to determine the ultimate recovery of the investment in SONGS and the costs incurred since the commencement of this outage, including purchased replacement power costs, which are typically recovered through the Energy Resource Recovery Account (ERRA).

In April 2014, SDG&E filed with the CPUC a Settlement Agreement, along with Edison, The Utility Reform Network (TURN), the CPUC Office of Ratepayer Advocates (ORA) and two other intervenors who joined the Settlement Agreement to the SONGS OII proceeding (collectively, the Settling Parties).

In September 2014, the Settling Parties executed an Amended and Restated Settlement Agreement (Amended Settlement Agreement), which amended the Settlement Agreement, and in November 2014, the CPUC issued a final decision approving the Amended Settlement Agreement. The Amended Settlement Agreement does not affect on-going or future proceedings before the NRC, or litigation or arbitration related to potential future recoveries from third parties (except for the allocation to ratepayers of any recoveries as described below) or proceedings addressing decommissioning activities and costs. We discuss the terms of the Amended Settlement Agreement and related filings in Note 13 of the Notes to Consolidated Financial Statements in the Annual Report.

In April 2015, a petition for modification (PFM) was filed with the CPUC by Alliance for Nuclear Responsibility (A4NR), an intervenor in the SONGS OII proceeding, asking the CPUC to set aside its decision approving the Amended Settlement Agreement and reopen the SONGS OII proceeding. In June 2015, TURN, a party to the Amended Settlement Agreement, filed a response supporting the A4NR petition. TURN does not question the merits of the Amended Settlement Agreement, but is concerned that certain allegations regarding Edison raised by A4NR have undermined the public’s confidence in the regulatory process. SDG&E has responded that TURN’s concerns regarding public perception do not impact the reasonableness of the Amended Settlement Agreement and are insufficient to overturn it. SDG&E is unable to determine what actions the CPUC will take, if any, in response to the A4NR PFM.

In August 2015, ORA, also a party to the Amended Settlement Agreement, filed a PFM with the CPUC, withdrawing its support for the Amended Settlement Agreement and asking the CPUC to reopen the SONGS OII proceeding. The ORA does not question the merits of the Amended Settlement Agreement, but is concerned with the CPUC’s approach toward recent disclosures concerning Edison ex parte communications with the CPUC. SDG&E responded that the ORA’s PFM is insufficient to overturn the Amended Settlement Agreement, because the ORA fails to make a case that the Amended Settlement Agreement is no longer in the public interest. SDG&E is unable to determine what actions the CPUC will take, if any, in response to the ORA PFM.

Accounting and Financial Impacts

Through December 31, 2015 and March 31, 2016, the cumulative after-tax loss from plant closure recorded by Sempra Energy and SDG&E is $125 million, including a reduction in the after-tax loss of $13 million in the first quarter of 2015 based on the CPUC’s approval in March 2015 of SDG&E’s compliance filing and establishment of the SONGS settlement revenue requirement.

The regulatory asset for the expected recovery of SONGS costs, consistent with the Amended Settlement Agreement, is $243 million ($43 million current and $200 million long-term) at March 31, 2016 and is recorded on the Condensed Consolidated Balance Sheets in Other Current Assets and Regulatory Assets Noncurrent, respectively, at Sempra Energy, and in Regulatory Assets Current and Other Regulatory Assets Noncurrent, respectively, at SDG&E. The amortization period prescribed for the regulatory asset is 10 years, which began on February 1, 2012. However, since the CPUC’s final decision approving the Amended Settlement Agreement was not issued until November 2014, amortization did not commence until January 2015.

Settlement with Nuclear Electric Insurance Limited (NEIL)

NEIL insures domestic and international nuclear utilities for the costs associated with interruptions, damages, decontaminations and related nuclear risks. In October 2015, the SONGS co-owners (Edison, SDG&E and the City of Riverside) reached an agreement with NEIL to resolve all of SONGS’ insurance claims arising out of the failures of the replacement steam generators for a total payment by NEIL of $400 million, SDG&E’s share of which is $80 million. Pursuant to the terms of the SONGS OII Amended Settlement Agreement, after reimbursement of legal fees and a 5-percent allocation to shareholders, the net proceeds of $75 million were allocated to ratepayers through ERRA. We discuss NEIL further in Note 11.

Nuclear Decommissioning and Funding

As a result of Edison’s decision to permanently retire SONGS Units 2 and 3, Edison has begun the decommissioning phase of the plant. We discuss the process of decommissioning SONGS and oversight by the NRC in Note 13 of the Notes to Consolidated Financial Statements in the Annual Report.

In accordance with state and federal requirements and regulations, SDG&E has assets held in trusts, referred to as the Nuclear Decommissioning Trusts (NDT), to fund decommissioning costs for SONGS Units 1, 2 and 3. Decommissioning of Unit 1, removed from service in 1992, is largely complete. The remaining work will be done when Units 2 and 3 are decommissioned. At March 31, 2016, the fair value of SDG&E’s NDT assets was $1.1 billion. Except for the use of funds for the planning of decommissioning activities or NDT administrative costs, CPUC approval is required for SDG&E to access the NDT assets to fund SONGS decommissioning costs for Units 2 and 3. In July 2015, the CPUC authorized SDG&E’s request to access trust funds for up to $55 million in decommissioning costs incurred in 2013, including $18 million that is expected to be withdrawn pending satisfactory clarification by the Internal Revenue Service (IRS) that certain spent fuel costs and other costs are eligible decommissioning costs, payable from qualified nuclear decommissioning trusts. We are uncertain as to when such clarification will be provided.

In November 2015, the CPUC authorized SDG&E’s request to access trust funds for $36 million for SONGS Units 2 and 3 decommissioning costs incurred in 2014, including $13 million that also will be withdrawn pending satisfactory clarification by the IRS. SDG&E expects to request and receive approval in the second quarter of 2016 to access trust funds for Units 2 and 3 decommissioning costs incurred in 2015.

In April 2016, the CPUC adopted a decision approving a total decommissioning cost estimate for SONGS Units 2 and 3 of $4.411 billion, of which SDG&E’s share is $899 million. The decision also approves an annual advice letter request process for SDG&E to request trust fund disbursements for decommissioning costs based on a forecast for 2016 and thereafter. Disbursements from the trust will then be made up to this annual forecast amount as decommissioning expenses are incurred. All disbursements will be subject to future refund until a reasonableness review of the actual decommissioning costs is conducted, which would be no less frequently than every three years.

We discuss the NDT and matters related to its funding and the funding of decommissioning costs by the NDT further in Note 13 of the Notes to Consolidated Financial Statements in the Annual Report.

Nuclear Decommissioning Trusts

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 presented on the Sempra Energy and SDG&E Condensed 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 NDT. We provide additional fair value disclosures for the NDT in Note 8.

NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
					Gross		Gross		Estimated
					unrealized		unrealized		fair
			Cost		gains		losses		value
At March 31, 2016:
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies(1)		$	101	$	4	$	―	$	105
Municipal bonds(2)			146		10		―		156
Other securities(2)			192		6		(8)		190
Total debt securities			439		20		(8)		451
Equity securities			214		413		(4)		623
Cash and cash equivalents			9		―		(1)		8
Total		$	662	$	433	$	(13)	$	1,082
At December 31, 2015:
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies		$	89	$	2	$	―	$	91
Municipal bonds			148		8		―		156
Other securities			194		1		(13)		182
Total debt securities			431		11		(13)		429
Equity securities			214		412		(7)		619
Cash and cash equivalents			15		―		―		15
Total		$	660	$	423	$	(20)	$	1,063
(1)	Maturity dates are 2016-2065.
(2)	Maturity dates are 2016-2115.

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

SALES OF SECURITIES
(Dollars in millions)
		Three months ended March 31,
		2016		2015
Proceeds from sales(1)		$	93	$	94
Gross realized gains			3		2
Gross realized losses			(8)		(4)
(1)	Excludes securities that are held to maturity.

Net unrealized gains (losses) are included in Regulatory Liabilities Arising from Removal Obligations on Sempra Energy’s and SDG&E’s Condensed Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification.

We provide additional information about SONGS in Note 11.

NOTE 10. CALIFORNIA UTILITIES' REGULATORY MATTERS

We discuss regulatory matters affecting our California Utilities in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report, and provide updates to those discussions and details of any new matters below.

JOINT MATTERS

CPUC General Rate Case (GRC)

The CPUC uses a general rate case proceeding to set sufficient rates 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.

The California Utilities filed their 2016 General Rate Case (2016 GRC) applications in November 2014. These filings requested revenue requirement increases of $133 million and $256 million for SDG&E and SoCalGas, respectively, over their 2015 revenue requirements.

In September 2015, the California Utilities filed settlement agreements with the CPUC that resolve all material matters related to the proceeding, except for the revenue requirement implications of certain income tax benefits associated with flow-through repair allowance tax deductions, discussed below. The settlement agreements are with eight of eleven intervening parties. For SoCalGas, the settlement proposes a total revenue requirement in 2016 of $2.219 billion, which is $133 million less than its original request. The proposed settlement represents an increase of $122 million, or 6 percent, over the 2015 total revenue requirement. For SDG&E, the settlement proposes a total revenue requirement in 2016 of $1.811 billion, which is $100 million less than its original request (as revised). The proposed settlement represents an increase of $17 million, or one percent, over the 2015 total revenue requirement. This increase reflects a $16 million adjustment to the 2015 estimated revenue requirement since the November 2014 filings. The filed settlement agreements also call for attrition adjustments of 3.5 percent for both 2017 and 2018. Because the 2016 settlement has not been finalized, the California Utilities will collect rates identical to 2015 authorized amounts until a 2016 decision is approved.

The California Utilities also filed a separate agreement, reached with ORA, proposing that a fourth year (2019) be added to the GRC period, with a revenue requirement increase of 4.3 percent over 2018. On April 29, 2016, the CPUC issued a proposed decision in a separate proceeding denying the potential of four-year GRC cycles citing that an extension to the GRC period would delay the implementation of the risk-based decision making framework.

The settlement agreements described above exclude a proposal, for both SDG&E and SoCalGas, regarding certain intra-rate case income tax benefits. The proposal recommends that the CPUC adjust SoCalGas’ rate base by $92 million and SDG&E’s rate base by $93 million, and additionally reduce both utilities’ revenue requirements by amounts tracked in tax memorandum accounts for the year 2015, which total $74 million for SoCalGas and $39 million for SDG&E. We believe the proposed treatment would violate and contradict long standing rate making and income tax policy, and would represent a material departure from historical practice. If this proposal is adopted, the outcome would reduce the revenue requirement amounts agreed to in the respective settlement agreements described above. SDG&E and SoCalGas do not expect that the prospective reduction to rate base described above would result in an immediate earnings impact if this proposal is adopted. However, if this proposal is adopted, SDG&E and SoCalGas may record a material charge against earnings for amounts in the tax memorandum accounts when the proposed decision is received.

We anticipate all matters to be resolved in the CPUC’s final decision on the 2016 GRC proceeding. We expect the CPUC to issue a final decision in the proceeding in the second quarter of 2016.

Natural Gas Pipeline Operations Safety Assessments

In June 2014, the CPUC issued a final decision addressing SDG&E’s and SoCalGas’ Pipeline Safety Enhancement Plan (PSEP). Specifically, the decision determined the following for Phase 1 of the program:

approved the utilities’ model for implementing PSEP;
approved a process, including a reasonableness review, to determine the amount that the utilities will be authorized to recover from ratepayers for the interim costs incurred through the date of the final decision to implement PSEP, which is recorded in regulatory accounts authorized by the CPUC;
approved balancing account treatment, subject to a reasonableness review, for incremental costs yet to be incurred to implement PSEP; and
established the criteria to determine the amounts that would not be eligible for cost recovery, including:

certain costs incurred or to be incurred searching for pipeline test records,
the cost of pressure testing pipelines installed after July 1, 1961 for which the company has not found sufficient records of testing, and
any undepreciated balances for pipelines installed after 1961 that were replaced due to insufficient documentation of pressure testing.

As a result of this decision, SoCalGas recorded an after-tax earnings charge of $5 million in 2014 for costs incurred in prior periods that were no longer subject to recovery. After taking the amounts disallowed for recovery into consideration, as of March 31, 2016, SDG&E and SoCalGas have recorded PSEP costs of $12 million and $177 million, respectively, in the CPUC-authorized regulatory account. In regard to requesting recovery from customers for PSEP costs incurred and recorded in accordance with the Triennial Cost Allocation Proceeding (TCAP) decision, SDG&E and SoCalGas are authorized to file an application with the CPUC for recovery of such costs up to the date of the TCAP decision and then annually for costs incurred through the end of each calendar year beginning with the period ended December 31, 2015. SoCalGas and SDG&E currently expect to file such applications no later than the second quarter of the year following and would expect a decision from the CPUC approximately 12 to 18 months following the date of the application (i.e., a decision on the recovery of costs recorded in the PSEP regulatory accounts as of December 31, 2015 would be expected by mid-2017).

In October 2014, SDG&E and SoCalGas filed a PFM with the CPUC requesting authority to begin to recover PSEP costs from customers in the year in which the costs are incurred, subject to refund pending the results of a reasonableness review by the CPUC, instead of in a subsequent year. This request is pending at the CPUC.

In December 2014, SDG&E and SoCalGas filed an application with the CPUC for recovery of $0.1 million and $46 million, respectively, in costs recorded in the regulatory account through June 11, 2014. In June 2015, SDG&E and SoCalGas agreed to remove certain projects from the filing and defer their review to future proceedings and, as a result, are now requesting recovery of $0.1 million and $26.8 million, respectively. The ORA, TURN, and the Southern California Generation Coalition (SCGC) have recommended disallowances related to completed projects, as well as facilities build-out costs, de-scoped projects, and project management and consulting costs. We expect a decision on this application in the second quarter of 2016.

In July 2014, the ORA and TURN filed a joint application for rehearing of the CPUC’s June 2014 final decision. In March 2015, the CPUC issued a decision denying the ORA’s and TURN’s second request for rehearing, but keeping the record open to admit additional evidence on the limited issue of pressure testing or replacing pipelines installed between January 1, 1956 and July 1, 1961. The ORA and TURN allege that the CPUC made a legal error in directing that ratepayers, not shareholders, be responsible for the costs associated with testing or replacing transmission pipelines that were installed between January 1, 1956 and July 1, 1961 for which the California Utilities do not have a record of a pressure test. In December 2015, the CPUC issued a final decision finding that ratepayers should not bear the costs associated with pressure testing subject pipelines, or, if replaced, ratepayers should bear neither the average cost of pressure testing nor the undepreciated balance of abandoned pipelines. Through March 31, 2016, the after-tax disallowed costs for SoCalGas and SDG&E are $2.6 million and $0.5 million, respectively. In January 2016, SoCalGas and SDG&E jointly filed a request with the CPUC seeking rehearing of its December 2015 decision. A CPUC decision on the rehearing request is expected in 2016.

SDG&E MATTERS

SONGS

We discuss regulatory and other matters related to SONGS in Note 9.

Wildfire Claims Cost Recovery

In September 2015, SDG&E filed an application with the CPUC requesting rate recovery of an estimated $379 million in costs related to the October 2007 wildfires that have been recorded to the Wildfire Expense Memorandum Account (WEMA). These costs represent a portion of the estimated total of $2.4 billion in costs and legal fees that SDG&E has incurred to resolve third-party damage claims arising from the October 2007 wildfires. The requested amount of $379 million is the net estimated cost incurred by SDG&E after deductions for insurance reimbursement ($1.1 billion), third party settlement recoveries ($824 million) and allocations to Federal Energy Regulatory Commission (FERC)-jurisdictional rates ($80 million), and reflects a voluntary 10 percent shareholder contribution applied to the net WEMA balance ($42 million). SDG&E requested a CPUC decision by the end of 2016 and is proposing to recover the costs in rates over a six- to ten-year period. In April 2016, a ruling was issued establishing the scope and schedule for the proceeding, which will be managed in two phases. Phase 1 will address SDG&E’s operational and management prudence surrounding the 2007 wildfires. Phase 2 will address whether SDG&E’s actions and decision-making in connection with settling legal claims in relation to the wildfires were reasonable. Evidentiary hearings in Phase 1 are scheduled to be held in January 2017, with a final decision scheduled to be issued in the second half of 2017. The procedural schedule for Phase 2 will be determined after Phase 1 is concluded.

In September 2015, the presiding judge assigned by the FERC to SDG&E’s annual Electric Transmission Formula Rate filing (TO4 Formula Cycle 2) issued an initial decision and an order on summary judgment that authorized SDG&E to recover all of the costs incurred and allocated to SDG&E’s FERC-regulated operations, including $23.1 million of costs associated with the 2007 wildfires. In October 2015, the CPUC filed a request for rehearing of the FERC’s September 2015 order, which requested abeyance of SDG&E’s request to recover 2007 wildfire damage expenses. On April 21, 2016, the FERC affirmed its findings in the September 2015 order and denied the CPUC’s request for rehearing. The FERC decision finalizes SDG&E’s base transmission revenue requirement and the $23.1 million of wildfire damage expenses.

We provide additional information about wildfire litigation costs and their recovery in Note 11.

SOCALGAS MATTERS

Aliso Canyon Natural Gas Storage Facility

We discuss various regulatory matters regarding the Aliso Canyon natural gas storage facility and leak in Note 11.

CALIFORNIA UTILITIES — MAJOR PROJECTS

We discuss the California Utilities’ major projects in detail in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report, and provide updates to those discussions and details in the tables below.

MAJOR PROJECTS – UPDATES

Joint Utilities Projects
Southern Gas System Reliability Project
§	In April 2016, the CPUC issued a proposed decision finding that there is a need for enhanced system reliability for the southern portion of the SoCalGas and SDG&E gas system, but concluding that the utilities have failed to demonstrate that there is a need for their proposed pipeline project. Instead, the proposed decision determines that certain non-physical alternatives will provide enhanced supply reliability, without the need to construct pipeline facilities.
§	At March 31, 2016, SoCalGas has approximately $23 million of development costs invested in the project, classified as Property, Plant and Equipment on Sempra Energy's and SoCalGas' Condensed Consolidated Balance Sheets. Some or all of these assets could become impaired if the project and potential alternative uses for these assets were ultimately rejected by the CPUC. SoCalGas and SDG&E filed comments with the CPUC in April 2016.
Pipeline Safety & Reliability Project
§	SDG&E and SoCalGas filed an amended application with the CPUC in March 2016 providing detailed analysis and testimony supporting the proposed project. The revised request also presents additional information on the costs and benefits of project alternatives, safety evaluation and compliance analysis, and statutory and procedural requirements. SDG&E and SoCalGas seek approval to construct the proposed project, estimated at a cost of $633 million, and authority to recover the associated revenue requirement in rates.

SDG&E Projects
Cleveland National Forest (CNF) Transmission Projects
§	In March 2016, the U.S. Forest Service issued a final decision authorizing issuance of the CNF Master Special Use Permit renewing SDG&E's land rights and authorizing the construction, operation and maintenance of facilities located on national forest lands for the next 50 years, as well as approving the majority of the fire-hardening activities proposed by SDG&E.
§	Proposed decision issued by the CPUC in April 2016, which granted SDG&E a permit to construct. Final CPUC decision expected in the second quarter of 2016.
Sycamore-Peñasquitos Transmission Project
§	March 2016 final environmental impact report (EIR) recommended an alternative that undergrounds more of the project than originally proposed, and is viewed as environmentally superior. The CPUC may consider this alternative.
§	CPUC's recommended alternative has an estimated cost of $250 million to $300 million, compared to the original project cost estimate of $120 million to $150 million, and would also delay the project schedule by approximately 10 months.
§	CPUC decision expected in the second half of 2016.
South Orange County Reliability Enhancement
§	CPUC issued its final EIR for the project in April 2016. The EIR concluded that an alternative project is considered environmentally superior to SDG&E's proposal. The final EIR states that the CPUC is not required to adopt the environmentally superior alternative if there are overriding considerations in favor of another alternative. The CPUC will consider the findings in determining whether to approve SDG&E's proposed project or an alternative to it.
§	Final CPUC decision expected in the second half of 2016.

COMMITMENTS AND CONTINGENCIES

3 Months Ended

Mar. 31, 2016

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

NOTE 11. COMMITMENTS AND CONTINGENCIES

LEGAL PROCEEDINGS

We accrue losses for a legal proceeding when it is probable that a loss has been incurred and the amount of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to 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 coverage and could materially adversely affect our business, cash flows, results of operations, financial condition and prospects. Unless otherwise indicated, we are unable to estimate reasonably possible losses in excess of any amounts accrued.

At March 31, 2016, Sempra Energy’s accrued liabilities for legal proceedings, including associated legal fees and costs of litigation, on a consolidated basis, were $37 million. At March 31, 2016, accrued liabilities for legal proceedings for SDG&E and SoCalGas were $29 million and $6 million, respectively, excluding amounts for matters related to the Aliso Canyon natural gas leak, which we discuss 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.” A September 2008 staff report issued by the CPUC’s Consumer Protection and Safety Division, now known as the Safety and Enforcement Division, 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.

Numerous parties 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. They asserted 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. SDG&E has resolved almost all of these lawsuits. One case remains subject to a damages-only trial, where the value of any compensatory damages resulting from the fires will be determined. Two appeals are pending after judgment in the trial court. SDG&E does not expect additional plaintiffs to file lawsuits given the applicable statutes of limitation, but could receive additional settlement demands and damage estimates from the remaining plaintiff until the case is resolved. SDG&E establishes reserves for the wildfire litigation as information becomes available and amounts are estimable.

SDG&E has concluded that it is probable that it will be permitted to recover in rates a substantial portion of the costs incurred to resolve wildfire claims in excess of its liability insurance coverage and the amounts recovered from third parties. Accordingly, at March 31, 2016, Sempra Energy and SDG&E have recorded assets of $363 million in Other Regulatory Assets (long-term) on their Condensed Consolidated Balance Sheets, including $360 million related to CPUC-regulated operations, which represents the amount substantially equal to the aggregate amount it has paid and reserved for payment for the resolution of wildfire claims and related costs in excess of its liability insurance coverage and amounts recovered from third parties. On September 25, 2015, SDG&E filed an application with the CPUC seeking authority to recover these costs, as we discuss in Note 10. Should SDG&E conclude that recovery in rates is no longer probable, SDG&E will record a charge against earnings at the time such conclusion is reached. If SDG&E had concluded that the recovery of regulatory assets related to CPUC-regulated operations was no longer probable or was less than currently estimated at March 31, 2016, the resulting after-tax charge against earnings would have been up to approximately $213 million. A failure to obtain substantial or full recovery of these costs from customers, or any negative assessment of the likelihood of recovery, would likely have a material adverse effect on Sempra Energy’s and SDG&E’s results of operations and cash flows.

We provide additional information about excess wildfire claims cost recovery and related CPUC actions in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report and discuss how we assess the probability of recovery of our regulatory assets in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

Smart Meters Patent Infringement Lawsuit

In October 2011, SDG&E was sued by a Texas design and manufacturing company in Federal District Court, Southern District of California, and later transferred to the Federal District Court, Western District of Oklahoma as part of Multi-District Litigation (MDL) proceedings, 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. The MDL court has finished ruling on pre-trial matters, and SDG&E expects that it will return the case to the Southern District of California.

Lawsuit Against Mitsubishi Heavy Industries, Ltd.

On July 18, 2013, SDG&E filed a lawsuit in the Superior Court of California in the County of San Diego against Mitsubishi Heavy Industries, Ltd., Mitsubishi Nuclear Energy Systems, Inc., and Mitsubishi Heavy Industries America, Inc. (collectively MHI). The lawsuit seeks to recover damages SDG&E has incurred and will incur related to the design defects in the steam generators MHI provided to the SONGS nuclear power plant. The lawsuit asserts a number of causes of action, including fraud, based on the representations MHI made about its qualifications and ability to design generators free from defects of the kind that resulted in the permanent shutdown of the plant and further seeks to set aside the contractual limitation of damages that MHI has asserted. On July 24, 2013, MHI removed the lawsuit to the United States District Court for the Southern District of California and on August 8, 2013, MHI moved to stay the proceeding pending resolution of the dispute resolution process involving MHI and Edison arising from their contract for the purchase and sale of the steam generators. On October 16, 2013, Edison initiated an arbitration proceeding against MHI seeking damages stemming from the failure of the replacement steam generators. In late December 2013, MHI answered and filed a counterclaim against Edison. On March 14, 2014, MHI’s motion to stay the United States District Court proceeding was granted with instructions that require the parties to allow SDG&E to participate in the ongoing Edison/MHI arbitration. As a result, SDG&E participated in the arbitration as a claimant and respondent. The arbitration hearing concluded at the end of April 2016, and a decision could come as early as this year.

Investment in Wind Farm

In 2011, the CPUC and FERC approved SDG&E’s estimated $285 million tax equity investment in a wind farm project and its purchase of renewable energy credits from that project. SDG&E’s contractual obligations to both invest in the Rim Rock wind farm and to purchase renewable energy credits from the wind farm under the power purchase agreement are subject to the satisfaction of certain conditions which, if not achieved, would allow SDG&E to terminate the power purchase agreement and not make the investment. In December 2013, SDG&E received a closing notice from the project developer indicating that all such conditions had been met. SDG&E responded to the closing notice asserting that the contractual conditions had not been satisfied. On December 19, 2013, SDG&E filed a complaint against the project developer in San Diego Superior Court, asking that the court determine that SDG&E is entitled to terminate both the investment contract and the power purchase agreement due to the project developer’s failure to satisfy certain conditions. The project developer filed a separate complaint against SDG&E in Montana state court asking that court to determine that SDG&E breached the investment contract and the power purchase agreement, and asking for several categories of relief, including requiring SDG&E to invest in the project, requiring SDG&E to continue performing under the power purchase agreement, and payment of damages.

On January 27, 2014, the Montana court ordered SDG&E to continue making payments under the power purchase agreement pending a hearing on the project developer’s preliminary injunction motion. On March 14, 2014, SDG&E notified the project developer that the investment agreement expired by its own terms because a closing had not occurred by that date. The project developer disputed SDG&E’s position. On March 28, 2014, SDG&E filed an amended complaint against the project developer in San Diego seeking damages and declaratory relief that SDG&E was entitled to terminate the power purchase agreement and to permit the investment agreement to expire. On April 25, 2014, the Montana court granted the project developer’s preliminary injunction motion to prevent SDG&E from terminating the power purchase agreement on the grounds that the project developer would be irreparably harmed if the payments were not made while the parties’ respective rights were being determined in the litigation. The court did not rule on the merits of the parties’ claims. On July 18, 2014, the Montana Supreme Court determined that the parties’ contractual agreement to resolve any disputes in San Diego was mandatory, and ordered that the Montana action be dismissed. The San Diego court has scheduled a trial in May 2016. On February 11, 2016, SDG&E, the project developer and several of the project developer’s parent and affiliated entities entered into a conditional settlement agreement. Under the conditional settlement agreement, among other things, the parties agreed to terminate the tax equity investment arrangement, continue the power purchase agreement for the wind farm generation, and release all claims against each other. The conditional settlement agreement will not result in rate increases to SDG&E customers or a material impact on Sempra Energy’s or SDG&E’s financial condition, results of operations or cash flows. On February 16, 2016, SDG&E and the project developer filed a petition for approval of the settlement agreement with the CPUC. The conditional settlement agreement is not fully effective until approved by the CPUC; SDG&E expects a decision in 2016. The May 2016 trial date set in the San Diego court has been stayed until the settlement is addressed by the CPUC.

SoCalGas

Aliso Canyon Natural Gas Storage Facility Gas Leak

In October 2015, SoCalGas discovered a leak at one of its injection and withdrawal wells, SS25, at its Aliso Canyon natural gas storage facility, located in the northern part of the San Fernando Valley in Los Angeles County. The Aliso Canyon facility has been operated by SoCalGas since 1972. SS25 is more than one mile away from and 1,200 feet above the closest homes. It is one of more than 100 injection and withdrawal wells at the storage facility.

Stopping the Leak, and Local Community Mitigation Efforts. SoCalGas worked closely with several of the world’s leading experts to stop the leak, including planning and obtaining all necessary approvals for drilling relief wells. On February 18, 2016, the California Department of Conservation’s Division of Oil, Gas, and Geothermal Resources (DOGGR) confirmed that the well was permanently sealed.

On December 24, 2015, by stipulation and court order, SoCalGas agreed to implement a formal plan for assisting residents in the nearby community to temporarily relocate, as well as to pay for additional overtime and costs associated with extra Los Angeles Police Department security patrols, among other things. SoCalGas has been providing temporary relocation support to residents in the nearby community who requested it before the well was permanently sealed. In addition, SoCalGas provided air filtration and purification systems to those residents in the nearby community requesting them.

As a result of receiving the confirmation from DOGGR that SS25 was permanently sealed, SoCalGas started winding down its temporary relocation support in accordance with the terms of the formal relocation plan. Subject to certain exceptions, the period for temporary relocation support to residents who temporarily relocated to short-term housing, such as hotels, was scheduled to end on February 25, 2016. This deadline was challenged by the County of Los Angeles (County), who expressed concern about potential lingering health effects and stated that they intended to perform indoor air testing. The California Superior Court issued an order extending such period for an additional 22 days for certain residents. On March 18, 2016, the County sought a further extension through the end of the litigation, which was denied, but the Superior Court stayed its order pending a potential appeal to the California Court of Appeal. Following an appeal by the County, on April 13, 2016, the Court of Appeal remanded the matter back to the California Superior Court for further consideration of the record and extended the relocation support term to at least April 27, 2016. The Superior Court set the matter for hearing on April 27, 2016, and gave the parties an opportunity to file supplemental briefing and evidence. On April 27, 2016, the Superior Court heard oral argument on the matter and ultimately entered an order further extending the relocation support term pending the completion of the County’s indoor testing. The Superior Court set a case management conference on June 7, 2016, for further consideration of the relocation program, and instructed the County and SoCalGas to file a joint update with the Court on May 31, 2016 regarding the status of the relocation support.

To put the relocation dispute in perspective, on January 31, 2016, the Los Angeles County Department of Public Health (LA County DPH) stated, “The average levels of benzene and other trace chemicals that have been measured in the community are currently at or below levels seen elsewhere in the county, and do not pose an increase in the risk of short‐term or long‐term health effects.” Following the sealing of the well, included in its April 9, 2016 update to its Aliso Canyon webpage, the LA County DPH affirmed that “levels of chemicals of concern are now consistent with expected background levels for the Los Angeles air basin.”

In seeking the extension of the relocation support term, the County has contended that indoor testing is required in order to determine whether it is safe for residents to return home. On March 24, 2016, the County released its indoor sampling work plan to test approximately 100 houses for a broad range of chemicals, including volatile organic compounds, semi-volatile organic compounds, metals, and sulfur compounds in the air and on surfaces. These substances are commonly found in households at varying levels. We were informed that this testing was completed on April 8, 2016, and that the County is currently analyzing the results. The County has reported that it anticipates completing its analysis and releasing a final report by late May 2016. In mid-March 2016, a third party engaged by SoCalGas conducted screening of indoor air for methane and mercaptans (odorants added to natural gas) in 71 houses in the Porter Ranch community near the Aliso Canyon storage facility. Based on this screening, no mercaptans were detected, and concentrations of methane were well below levels of concern as established by the California Environmental Protection Agency’s Department of Toxic Substances Control.

The total costs incurred to remediate and stop the leak and to mitigate local community impacts will be significant, and to the extent not covered by insurance, or if there were to be significant delays in receiving insurance recoveries, such costs could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

Cost Estimates and Accounting Impact. At March 31, 2016, SoCalGas recorded estimated costs of $665 million related to the leak. Of this amount, approximately 70 percent is for the temporary relocation program and approximately 15 percent is for attempts to control the well, stop the leak, stop or reduce the emissions, and the estimated cost of the root cause analysis being conducted to determine the cause of the leak. The remaining amount includes estimated legal costs necessary to defend litigation, the value of lost gas, the costs to mitigate the actual natural gas released, and other costs. SoCalGas made a commitment in December 2015 to mitigate the actual natural gas released and has been working on a plan to accomplish the mitigation. The $665 million represents management’s best estimate of these costs related to the leak. Of these costs, certain amounts have been paid and $302 million is recorded as Reserve for Aliso Canyon Costs at March 31, 2016 on SoCalGas’ and Sempra Energy’s Condensed Consolidated Balance Sheets for amounts expected to be paid after March 31, 2016. We will refine these estimates as further information becomes available. SoCalGas’ estimate of temporary relocation costs was primarily determined considering the current experience of temporary relocations through the hearing date of April 27, 2016 discussed above. The remainder of the reserve was estimated primarily based on work plans, the rate of cost accumulation and estimated duration of the various activities, or other estimates. Any differences in actual costs incurred will impact these estimates. Based on the order of the Superior Court on April 27, 2016, which scheduled the next hearing on June 7, 2016, for purposes of this estimate we assume the period for temporary relocation support to residents who temporarily relocated has been extended to June 7, 2016. While such support period could end before June 7, 2016, due to the fact that temporary relocation support has been extended several times, there can be no assurance that future extensions will not be granted. The cost of the temporary relocation support is significant, and the costs of any further extensions of the relocation support term, which are not included in our estimate, could result in a material increase in our cost estimate.

At March 31, 2016, we recorded the expected recovery of the costs described in the immediately preceding paragraph related to the leak (less insurance retentions) of $660 million as Insurance Receivable for Aliso Canyon Costs on SoCalGas’ and Sempra Energy’s Condensed Consolidated Balance Sheets. If we were to conclude that this receivable or a portion of it was no longer probable of recovery from insurers, some or all of this receivable would be charged against earnings.

The above amounts do not include any damage awards, restitution, or any civil or criminal fines, costs or other penalties that may be imposed, as it is not possible to predict the outcome of any criminal or civil proceeding or any administrative action in which such damage awards, restitution or civil or criminal fines, costs or other penalties could be imposed, and any such amounts, if awarded or imposed, cannot be estimated at this time. In addition, the above amounts do not include other potential costs that we currently do not anticipate incurring or we cannot reasonably estimate.

On March 17, 2016, the CPUC issued a decision directing SoCalGas to establish a memorandum account to prospectively track its authorized revenue requirement and all revenues that it receives for its normal, business-as-usual costs to own and operate the Aliso Canyon gas storage field. The CPUC will determine at a later time whether, and to what extent, the tracked revenues may be refunded to ratepayers. Pursuant to the CPUC’s decision, on March 24, 2016, SoCalGas filed an advice letter requesting to establish a memorandum account to track all business-as-usual costs to own and operate the Aliso Canyon storage field, which has been protested by TURN and SCGC. On April 22, 2016, the CPUC’s Energy Division issued a suspension notice for SoCalGas’ advice letter citing the need for additional time for staff review. This suspension period could last up to 120 days.

Insurance. We have at least four kinds of insurance policies that provide in excess of $1 billion in insurance coverage. We cannot predict all of the potential categories of costs or the total amount of costs that we may incur as a result of the leak. In reviewing each of our policies, and subject to various policy limits, exclusions and conditions, based upon what we know as of the filing date of this report, we believe that our insurance policies collectively should cover the following categories of costs: the costs incurred for temporary relocation, costs to address the leak and stop or reduce emissions, the root cause analysis being conducted to determine the cause of the leak, the value of lost natural gas and estimated costs to mitigate the actual natural gas released, the costs associated with litigation and claims by nearby residents and businesses, and, in some circumstances depending on their nature and manner of assessment, fines and penalties. We have been communicating with our insurance carriers and intend to pursue the full extent of our insurance coverage. There can be no assurance that we will be successful in obtaining insurance coverage for these costs under the applicable policies, and to the extent we are not successful, it could result in a material charge against the earnings of SoCalGas and Sempra Energy.

Our estimate at March 31, 2016 of $665 million of certain costs in connection with the Aliso Canyon storage facility leak may rise significantly as more information becomes available, and to the extent not covered by insurance, or if there were to be significant delays in receiving insurance recoveries, such costs could have a material adverse effect on Sempra Energy’s and SoCalGas’ cash flows, financial condition and results of operations. In addition, the costs not included in the $665 million estimate could be material, and to the extent not covered by insurance, could have a material adverse effect on Sempra Energy’s and SoCalGas’ cash flows, financial condition and results of operations.

Governmental Investigations and Civil and Criminal Litigation. Various governmental agencies, including the DOGGR, LA County DPH, South Coast Air Quality Management District (SCAQMD), California Air Resources Board (CARB), California Division of Occupational Safety and Health (DOSH), CPUC, Pipeline and Hazardous Materials Safety Administration (PHMSA), U.S. Environmental Protection Agency (EPA), Los Angeles District Attorney’s Office and California Attorney General’s Office, are investigating this incident. On January 25, 2016, the DOGGR and CPUC selected Blade Energy Partners to conduct an independent analysis under their supervision and to be funded by SoCalGas to investigate the technical root cause of the Aliso Canyon gas leak. We expect the root cause analysis to be completed in late 2016 or early 2017, but the timing is dependent on the DOGGR and the CPUC.

As of April 28, 2016, 138 lawsuits have been filed (134 in Los Angeles County Superior Court, 2 in San Diego County Superior Court, and 2 in the United States District Court for the Southern District of California) against SoCalGas, some of which have also named Sempra Energy, and, in derivative and securities law claims on behalf of Sempra Energy and/or SoCalGas, certain officers and directors of Sempra Energy and/or SoCalGas. These various lawsuits assert causes of action for negligence, strict liability, property damage, fraud, nuisance, trespass, breach of fiduciary duties, and violation of federal securities laws, among other things, and additional litigation may be filed against us in the future related to this incident. Many of these complaints seek class action status, compensatory and punitive damages, injunctive relief, and attorneys’ fees. The Los Angeles City Attorney and Los Angeles County Counsel have also filed a complaint on behalf of the people of the State of California against SoCalGas for public nuisance and violation of the California Unfair Competition Law. The California Attorney General, acting in her independent capacity and on behalf of the people of the State of California and the CARB, joined this lawsuit. The complaint, which as amended includes the California Attorney General, adds allegations of violations of California Health and Safety Code sections 41700, prohibiting discharge of air contaminants that cause annoyance to the public, and 25510, requiring reporting of the release of hazardous material, as well as California Government Code section 12607 for equitable relief for the protection of natural resources. The complaint seeks an order for injunctive relief, to abate the public nuisance, and to impose civil penalties. The SCAQMD also filed a complaint against SoCalGas seeking civil penalties for alleged violations of several nuisance-related statutory provisions arising from the leak and delays in stopping the leak. That suit seeks up to $250,000 in civil penalties for each day the violations occurred.

On February 2, 2016, the Los Angeles District Attorney’s Office filed a misdemeanor criminal complaint against SoCalGas seeking penalties and other remedies for alleged failure to provide timely notice of the leak pursuant to California Health and Safety Code section 25510(a), Los Angeles County Code section 12.56.030, and Title 19 California Code of Regulations section 2703(a), and for violating California Health and Safety Code section 41700 prohibiting discharge of air contaminants that cause annoyance to the public.

The costs of defending against these civil and criminal lawsuits and cooperating with these investigations, and any damages, restitution, and civil and criminal fines, costs and other penalties, if awarded or imposed, could be significant and to the extent not covered by insurance, or if there were to be significant delays in receiving insurance recoveries, could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations.

Governmental Orders, Additional Regulation and Reliability. On January 6, 2016, the Governor of the State of California issued the Governor’s Order proclaiming a state of emergency to exist in Los Angeles County due to the natural gas leak at the Aliso Canyon facility. The Governor’s Order implemented orders to stop the leak and implements various other orders with respect to:

Protecting Public Health and Safety: State agencies will: continue the prohibition against SoCalGas injecting any gas into the Aliso Canyon storage facility until a comprehensive review, utilizing independent experts, of the safety of the storage wells and the air quality of the surrounding community is completed; expand real-time monitoring of emissions in the surrounding community; convene an independent panel of scientific and medical experts to review public health concerns stemming from the natural gas leak and evaluate whether additional measures are needed to protect public health; and take all actions necessary to ensure the continued reliability of natural gas and electricity supplies in the coming months during the moratorium on gas injections into the Aliso Canyon storage facility.

Ensuring Accountability: The CPUC will ensure that SoCalGas covers costs related to the natural gas leak and its response, while protecting ratepayers; and CARB will develop a program to fully mitigate the leak’s emissions of methane by March 31, 2016, with such program to be funded by SoCalGas.

Strengthening Oversight: The DOGGR will promulgate emergency regulations for gas storage facility operators throughout the state, requiring: at least daily inspection of gas storage well heads using gas leak detection technology such as infrared imaging; ongoing verification of the mechanical integrity of all gas storage wells; ongoing measurement of annular gas pressure or annular gas flow within wells; regular testing of all safety valves used in wells; minimum and maximum pressure limits for each gas storage facility in the state; and a comprehensive risk management plan for each facility that evaluates and prepares for risks, including corrosion potential of pipes and equipment. Additionally, the DOGGR, the CPUC, the CARB and the California Energy Commission will submit to the Governor’s Office a report that assesses the long-term viability of natural gas storage facilities in California.

SoCalGas made a commitment in December 2015 to mitigate the actual natural gas released and has been working on a plan to accomplish the mitigation. On March 31, 2016, pursuant to the Governor’s Order, the CARB issued its Aliso Canyon Methane Leak Climate Impacts Mitigation Program, which sets forth its recommended approach to achieve full mitigation of the emissions from the Aliso Canyon natural gas leak. The CARB program preliminarily assumes that the leak released approximately 100,000 metric tons of methane. It states that full mitigation requires that the program generate reductions in short-lived climate pollutants and other greenhouse gases at least equivalent to that amount and that the appropriate global warming potential to be used in deriving the amount of reductions required is a 20-year term rather than the 100-year term the CARB and other state and federal agencies use in regulating emissions, resulting in a target of approximately 8,000,000 metric tons of carbon dioxide equivalent. CARB’s program also requires all of the mitigation to occur in California over the next five to ten years without the use of allowances or offsets. We have not agreed to this proposed formulation and continue to work with CARB on the mitigation plan.

On January 23, 2016, the Hearing Board of the SCAQMD ordered SoCalGas to, among other things: stop all injections of natural gas except as directed by the CPUC, withdraw the maximum amount of natural gas feasible in a contained and safe manner, subject to orders of the CPUC, and permanently seal the well once the leak has ceased; continuously monitor the well site with infrared cameras until 30 days after the leak has ceased; provide the public with daily air monitoring data collected by SoCalGas; provide the SCAQMD with certain natural gas injection, withdrawal and emissions data from the Aliso Canyon facility; prepare and submit to the SCAQMD for its approval an enhanced leak detection and reporting well inspection program for the Aliso Canyon facility; provide the SCAQMD with funding to develop a continuous air monitoring plan for the Aliso Canyon facility and the nearby schools and community; prepare and submit to the SCAQMD for its approval an air quality notification plan to provide notice to SCAQMD, other public agencies and the nearby community in the event of a future reportable release; and provide the SCAQMD with funding to conduct an independent health study on the potential impacts of exposure on the constituents of the natural gas released from the facility, as well as any odor suppressants used to mitigate odors from the leaking well.

On April 1, 2016, the Secretary of the U.S. Department of Energy (DOE) and PHMSA jointly announced the formation of an Interagency Task Force on Natural Gas Storage Safety in response to the leak at Aliso Canyon to assess and make recommendations on best practices, response plans and safe operation of gas storage facilities. PHMSA has indicated plans to initiate additional regulatory actions on natural gas storage nationally. Each of the DOGGR, SCAQMD, EPA and CARB has commenced separate rulemaking proceedings to adopt further regulations covering natural gas storage facilities and injection wells. The U.S. Senate also passed two pieces of legislation, which include a provision requiring the establishment of an Aliso Canyon Task Force. This generally mirrors the focus and structure of the Task Force on Natural Gas Storage Safety. The legislation requires the Task Force to examine a specific set of issues related to the leak, including impacts on health and electricity prices.

Additional hearings in the state legislature as well as with various other federal and state regulatory agencies have been or are expected to be scheduled, additional legislation has been proposed in the state legislature, and additional laws, orders, rules and regulations may be adopted. Higher operating costs and additional capital expenditures incurred by SoCalGas as a result of new laws, orders, rules and regulations arising out of this incident could be significant and may not be recoverable in customer rates, and SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations may be materially adversely affected by any such new regulations.

On April 22, 2016, DOSH issued notices of intent to issue four “serious” citations to SoCalGas, alleging violations of Title 8 of the California Code of Regulations sections 5155(e)(1), 5192(q)(6)(E), 6845(a), and 6851(a). The notices allege (1) a failure to monitor concentrations of airborne contaminant exposure to employees, (2) an Incident Commander did not receive sufficient training, (3) insufficient testing and inspection of well casing and tubing and (4) insufficient inspection and maintenance to prevent leaks. The maximum penalty that DOSH could issue for these four alleged violations is a total of $280,000.

Natural Gas Storage Operations. SoCalGas estimates that approximately 57 billion cubic feet (Bcf) of natural gas has been delivered to customers or moved to other gas storage facilities from an initial starting point of approximately 77 Bcf of gas in storage on October 23, 2015 at the Aliso Canyon facility. The CPUC has directed SoCalGas to maintain a minimum of 15 Bcf of working natural gas to help ensure reliability of the system through the spring and summer months, and based on the CARB estimates of lost gas, the facility is approximately at this level. Effective February 5, 2016, the DOGGR amended the California Code of Regulations to require all underground natural gas storage facility operators, including SoCalGas, to take further steps to help ensure the safety of their gas storage operations. SoCalGas is in the process of conducting a measurement of natural gas lost from the leak and will provide that information to the relevant regulatory bodies.

Natural gas withdrawn from storage is important for service reliability during peak demand periods, including heating needs in the winter, as well as peak electric generation needs in the summer. Aliso Canyon, with a storage capacity of 86 Bcf, is the largest storage facility and an important element of SoCalGas’ delivery system. Aliso Canyon represents 63 percent of SoCalGas’ owned natural gas storage capacity. SoCalGas has not injected natural gas into Aliso Canyon since October 25, 2015, in accordance with the Governor’s Order and subject to contrary CPUC reliability-based direction. On March 4, 2016, the DOGGR issued Order 1109, Order to Take Specific Actions Regarding Aliso Canyon Gas Storage Facility (Safety Review Testing Regime). On April 7, 2016, SoCalGas announced its safety framework to comply with the DOGGR Order 1109, which consists of phased testing for each of the active injection wells in the Aliso Canyon storage facility. SoCalGas will continue this moratorium on further injections until the completion of this review and any necessary approvals have been obtained.

On April 5, 2016, four energy agencies—the CPUC, the California Energy Commission, the California Independent System Operator, and the Los Angeles Department of Water and Power—issued an Aliso Canyon Action Plan to Preserve Gas and Electric Reliability for the Los Angeles Basin. In their Action Plan, the agencies recognized that: Aliso Canyon is critical to meeting peak demand in both winter and summer; the Greater Los Angeles region could face an estimated 16 days of gas curtailments this upcoming summer—assuming no withdrawals of any of the 15 Bcf held at Aliso Canyon; and unless gas is withdrawn from Aliso Canyon, 14 of these days are likely to be large enough to interrupt electric generators located in the LA Basin. To help mitigate concerns about natural gas service reliability to customers, including related impacts on natural gas-fueled power generation, SoCalGas, SDG&E and 24 customer organizations filed a settlement agreement with the CPUC on April 29, 2016 regarding procedures to help deal with service reliability issues this upcoming summer. The procedures, which would address supply shortages and surpluses using temporarily modified Operational Flow Order (OFO) tariff provisions, would be in place through no later than November 30, 2016. SoCalGas, SDG&E, and the other settlement parties have asked the CPUC to approve this package of reliability-related provisions by May 26, 2016. There can be no assurance that these measures, if approved, will prevent gas curtailments or power outages during the period Aliso Canyon remains offline.

If the Aliso Canyon facility were to be taken out of service for any meaningful period of time, it could result in an impairment of the facility, significantly higher than expected operating costs and/or additional capital expenditures, and natural gas reliability and electric generation could be jeopardized. At March 31, 2016, the Aliso Canyon facility has a net book value of $415 million, including $180 million of construction work in progress for the project to construct a new compression station. Any significant impairment of this asset could have a material adverse effect on SoCalGas’ and Sempra Energy’s results of operations for the period in which it is recorded. Higher operating costs and additional capital expenditures incurred by SoCalGas may not be recoverable in customer rates, and SoCalGas’ and Sempra Energy’s results of operations, cash flows and financial condition may be materially adversely affected.

Other

SoCalGas, along with Monsanto Co., Solutia, Inc., Pharmacia Corp. and Pfizer, Inc., are defendants in seven Los Angeles County Superior Court lawsuits filed beginning in April 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. SoCalGas has settled six of the seven lawsuits for an amount that is not significant.

Sempra Mexico

Permit Challenges and Property Disputes

Sempra Mexico has been engaged in a long-running land dispute relating to property adjacent to its Energía Costa Azul LNG terminal near Ensenada, Mexico. Ownership of the adjacent property is not required by any of the environmental or other regulatory permits issued 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, and filed an action in the Federal Court challenging the permits. In February 2011, based on a complaint by the claimant, the municipality of Ensenada opened an administrative proceeding and sought 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. In the second quarter of 2014, the municipality of Ensenada dismissed the administrative proceeding. In the second quarter of 2015, the Administrative Court of Baja California confirmed the municipality of Ensenada’s ruling and dismissed the proceeding. 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 claimant also filed complaints in the federal Agrarian Court challenging the refusal of the Secretaría de la Reforma Agraria (now the Secretaría de Desarrollo Agrario, Territorial y Urbano, or SEDATU) in 2006 to issue a title to him for the disputed property. In November 2013, the Agrarian Court ordered that SEDATU issue the requested title and cause it to be registered. Both SEDATU and Sempra Mexico challenged the ruling, due to lack of notification of the underlying process. In November 2015, the Agrarian Court denied Sempra Mexico’s challenge, but the ruling does not affect any property rights. Another appeal filed by SEDATU is pending. Sempra Mexico expects additional proceedings regarding the claims, although such proceedings are not related to the permit challenges referenced above.

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. In September 2015, the Court granted Sempra Energy’s motion for summary judgment and closed the case. In October 2015, the claimant filed a notice of appeal of the summary judgment and an earlier order dismissing certain of his causes of action.

Additionally, several administrative challenges are pending in Mexico before the Mexican environmental protection agency (SEMARNAT) and the Federal Tax and Administrative Courts seeking revocation of the environmental impact authorization (EIA) issued to Energía Costa Azul in 2003. These cases generally allege that the conditions and mitigation measures in the EIA are inadequate and challenge findings that the activities of the terminal are consistent with regional development guidelines. The Mexican Supreme Court decided to exercise jurisdiction over one such case, and in March 2014, issued a resolution denying the relief sought by the plaintiff on the grounds its action was not timely presented. A similar administrative challenge seeking to revoke the port concession for our marine operations at our Energía Costa Azul LNG terminal was filed with and rejected by the Mexican Communications and Transportation Ministry. In April 2015, the Federal court confirmed the Mexican Communications and Transportation Ministry’s ruling denying the request to revoke the port concession and decided in favor of Energía Costa Azul.

Two real property cases have been filed against Energía Costa Azul in which the plaintiffs seek to annul the recorded property titles for parcels on which the Energía Costa Azul LNG terminal is situated and to obtain possession of different parcels that allegedly sit in the same place; one of these cases was dismissed in September 2013 at the direction of the state appellate court. A third complaint was served in April 2013 seeking to invalidate the contract by which Energía Costa Azul purchased another of the terminal parcels, on the grounds the purchase price was unfair. Sempra Mexico expects further proceedings on the remaining two matters.

Sempra Natural Gas

Since April 2012, a total of 14 lawsuits have been filed against Mobile Gas in Mobile County Circuit Court alleging that in the first half of 2008 Mobile Gas spilled tert-butyl mercaptan, an odorant added to natural gas for safety reasons, in Eight Mile, Alabama. Eleven of the lawsuits have been settled. The remaining three lawsuits, which include approximately 250 individual plaintiffs, allege nuisance, fraud and negligence causes of action, and seek unspecified compensatory and punitive damages.

Other Litigation

Sempra Energy holds a noncontrolling interest in RBS Sempra Commodities LLP (RBS Sempra Commodities), a limited liability partnership in the process of being liquidated. The Royal Bank of Scotland plc (RBS), our partner in the joint venture, was notified by the United Kingdom’s Revenue and Customs Department (HMRC) that it was investigating value-added tax (VAT) refund claims made by various businesses in connection with the purchase and sale of carbon credit allowances. HMRC advised RBS that it had determined that it had grounds to deny such claims by RBS related to transactions by RBS Sempra Energy Europe (RBS SEE), a former indirect subsidiary of RBS Sempra Commodities that was sold to JP Morgan. HMRC asserted that RBS was not entitled to reduce its VAT liability by VAT paid during 2009 because RBS knew or should have known that certain vendors in the trading chain did not remit their own VAT to HMRC. In September 2012, HMRC issued a protective assessment of £86 million for the VAT paid in connection with these transactions. In October 2014, RBS filed a Notice of Appeal of the September 2012 assessment with the First-tier Tribunal. As a condition of the appeal, RBS was required to pay the assessed amount. The payment also stops the accrual of interest that could arise should it ultimately be determined that RBS has a liability for some of the tax. RBS has asserted that HMRC’s assessment was time-barred. A preliminary hearing is scheduled for September 19 to 21, 2016. In June 2015, liquidators for three companies that engaged in carbon credit trading via chains that included a company that RBS SEE traded with directly filed a claim in the High Court of Justice against RBS and RBS Sempra Commodities alleging that RBS Sempra Commodities’ and RBS SEE’s participation in transactions involving the sale and purchase of carbon credits resulted in the companies’ incurring VAT liability they were unable to pay. In October 2015, the liquidators’ counsel filed an amended claim adding seven additional trading companies to the claim and asserting damages of £156 million for all 10 companies. Additionally, the claimants dropped RBS Sempra Commodities LLP as a defendant, adding the successor to RBS SEE and JP Morgan, Mercuria Energy Europe Trading Limited (Mercuria), in its stead. JP Morgan has notified us that Mercuria has sought indemnity for the claim, and JP Morgan has in turn sought indemnity from us. Our remaining balance in RBS Sempra Commodities is accounted for under the equity method. The investment balance of $67 million at March 31, 2016 reflects remaining distributions expected to be received from the partnership as it is liquidated. The timing and amount of distributions may be impacted by these matters. We discuss RBS Sempra Commodities further in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report.

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 January 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 resolved all issues with regard to sales between the California Department of Water Resources and Sempra Commodities in the Pacific Northwest, but potential claims may exist regarding sales in the Pacific Northwest between Sempra Commodities and other parties. 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 Ltd., one of the buyers of RBS Sempra Commodities’ businesses, 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.

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

CONTRACTUAL COMMITMENTS

We discuss below significant changes in the first three months of 2016 to contractual commitments discussed in Note 15 of the Notes to Consolidated Financial Statements in the Annual Report.

Natural Gas Contracts

Sempra Natural Gas’ natural gas purchase and transportation commitments have decreased by $46 million since December 31, 2015, primarily due to payments on existing contracts and changes in forward natural gas prices in the first three months of 2016. Net future payments are expected to decrease by $60 million in 2016, and increase by $10 million in 2017 and $4 million in 2018 compared to December 31, 2015.

LNG Purchase Agreement

Sempra Natural Gas has a purchase agreement for the supply of LNG to the Energía Costa Azul terminal. The agreement is priced using a predetermined formula based on natural gas market indices. Although this contract specifies a number of cargoes to be delivered, under its terms, the customer may divert certain cargoes, which would reduce amounts paid under the contracts by Sempra Natural Gas.

Sempra Natural Gas’ commitment under the LNG purchase agreement, reflecting changes in forward prices since December 31, 2015 and actual transactions for the first three months of 2016, is expected to decrease by $146 million in 2016, $3 million in 2017, $7 million in 2018, $18 million in 2019, and $30 million in 2020 and increase by $20 million thereafter (through contract termination in 2029) compared to December 31, 2015. These amounts are based on forward prices of the index applicable to the contract from 2016 to 2028 and an estimated one percent escalation per year beyond 2028 through contract termination in 2029. The LNG commitment amounts above are based on the requirement for Sempra Natural Gas to accept the maximum possible delivery of cargoes under the agreement. Actual LNG purchases in the current and prior years have been significantly lower than the maximum amounts possible due to the customer electing to divert cargoes as allowed by the agreement.

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 $13.2 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 $50.93 million. This amount is subject to an annual maximum of $7.6 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, subject to a $2.5 million deductible for “each and every loss.” This insurance coverage is provided through Nuclear Electric Insurance Limited (NEIL). The NEIL policies have specific exclusions and limitations that can result in reduced or eliminated coverage. Insured members as a group are subject to retrospective premium assessments to cover losses sustained by NEIL under all issued policies. SDG&E could be assessed up to $9.7 million of retrospective premiums based on overall member claims. See Note 9 under “Settlement with NEIL” for discussion of an agreement between the SONGS co-owners and NEIL to settle all claims under the NEIL policies associated with the SONGS outage.

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.

U.S. DEPARTMENT OF ENERGY NUCLEAR FUEL DISPOSAL

The Nuclear Waste Policy Act of 1982 made the DOE responsible for accepting, transporting, and disposing of spent nuclear fuel. However, it is uncertain when the DOE will begin accepting spent nuclear fuel from SONGS. This delay will lead to increased costs for spent fuel storage. SDG&E will continue to support Edison in its pursuit of claims on behalf of the SONGS co-owners against the DOE for its failure to timely accept the spent nuclear fuel. On April 18, 2016, Edison executed a spent fuel settlement agreement with the DOE for $162 million covering damages incurred from January 1, 2006 through December 31, 2013. SDG&E’s share of the settlement is approximately $32 million.

In October 2015, the California Coastal Commission approved Edison’s application for the proposed expansion of an Independent Spent Fuel Storage Installation (ISFSI) at SONGS. The ISFSI expansion began construction in 2016, will be fully loaded with spent fuel by 2019, and will operate until 2049, when it is assumed that the DOE will have taken custody of all the SONGS spent fuel. The ISFSI would then be decommissioned, and the site restored to its original environmental state.

We provide additional information about SONGS in Note 9 above and in Notes 13 and 15 of the Notes to Consolidated Financial Statements in the Annual Report.

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, southwest Alabama, and Hattiesburg, Mississippi.

As 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, customers and partners to perform on long-term agreements and on our ability to enforce contract terms in the event of nonperformance. We consider many factors, including the negotiation of supplier and customer agreements, when we evaluate and approve development projects.

SEGMENT INFORMATION

3 Months Ended

Mar. 31, 2016

Segment [Abstract]

Segment Information

NOTE 12. SEGMENT INFORMATION

We have six separately managed, reportable segments, as follows:

SDG&E provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County.
SoCalGas is a natural gas distribution utility, serving customers throughout most of Southern California and part of central California.
Sempra South American Utilities develops, owns and operates, or holds interests in, electric transmission, distribution and generation infrastructure in Chile and Peru.
Sempra Mexico develops, owns and operates, or holds interests in, natural gas transmission pipelines and propane and ethane systems, a natural gas distribution utility, electric generation facilities (including wind), a terminal for the import of LNG, and marketing operations for the purchase of LNG and the purchase and sale of natural gas in Mexico. In February 2016, management approved a plan to market and sell the Termoeléctrica de Mexicali natural gas-fired power plant located in Mexicali, Baja California, as discussed in Note 3.
Sempra Renewables develops, owns and operates, or holds interests in, wind and solar energy projects in Arizona, California, Colorado, Hawaii, Indiana, Kansas, Minnesota, Nebraska, Nevada and Pennsylvania to serve wholesale electricity markets in the United States.
Sempra Natural Gas develops, owns and operates, or holds interests in, natural gas pipelines and storage facilities, natural gas distribution utilities and a terminal for the import and export of LNG and sale of natural gas, all within the United States. Sempra Natural Gas also owned and operated the Mesquite Power plant, a natural gas-fired electric generation asset, the remaining 625-MW block of which was sold in April 2015.

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 of the Notes to Consolidated Financial Statements in the Annual Report.

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

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

SEGMENT INFORMATION
(Dollars in millions)
	Three months ended March 31,
	2016				2015
REVENUES
SDG&E	$	991	38	%	$	966	36	%
SoCalGas		1,033	40			1,048	39
Sempra South American Utilities		400	15			389	15
Sempra Mexico		138	5			163	6
Sempra Renewables		7	―			8	―
Sempra Natural Gas		130	5			197	7
Intersegment revenues(1)		(77)	(3)			(89)	(3)
Total	$	2,622	100	%	$	2,682	100	%
INTEREST EXPENSE
SDG&E	$	48			$	52
SoCalGas		22				19
Sempra South American Utilities		9				5
Sempra Mexico		4				5
Sempra Renewables		―				1
Sempra Natural Gas		12				21
All other		72				63
Intercompany eliminations		(24)				(32)
Total	$	143			$	134
INTEREST INCOME
Sempra South American Utilities	$	5			$	4
Sempra Mexico		2				2
Sempra Renewables		1				―
Sempra Natural Gas		16				19
Intercompany eliminations		(18)				(18)
Total	$	6			$	7
DEPRECIATION AND AMORTIZATION
SDG&E	$	159	49	%	$	145	48	%
SoCalGas		122	37			113	37
Sempra South American Utilities		13	4			13	4
Sempra Mexico		17	5			17	6
Sempra Renewables		1	―			2	1
Sempra Natural Gas		13	4			12	4
All other		3	1			1	―
Total	$	328	100	%	$	303	100	%
INCOME TAX EXPENSE (BENEFIT)
SDG&E	$	72			$	88
SoCalGas		87				95
Sempra South American Utilities		14				16
Sempra Mexico		41				8
Sempra Renewables		(12)				(17)
Sempra Natural Gas		(25)				2
All other		(35)				(29)
Total	$	142			$	163

SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
		Three months ended March 31,
		2016				2015
EQUITY EARNINGS (LOSSES)
Earnings (losses) recorded before tax:
Sempra Renewables		$	7			$	2
Sempra Natural Gas			(29)				17
Total		$	(22)			$	19
Earnings (losses) recorded net of tax:
Sempra South American Utilities		$	2			$	(1)
Sempra Mexico			15				16
Total		$	17			$	15
EARNINGS (LOSSES)
SDG&E		$	129	40	%	$	147	34	%
SoCalGas(2)			195	61			214	49
Sempra South American Utilities			38	12			41	9
Sempra Mexico			17	5			47	11
Sempra Renewables			13	4			13	3
Sempra Natural Gas			(36)	(11)			2	―
All other			(37)	(11)			(27)	(6)
Total		$	319	100	%	$	437	100	%
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E		$	329	34	%	$	355	46	%
SoCalGas			340	35			315	40
Sempra South American Utilities			43	4			31	4
Sempra Mexico			40	4			55	7
Sempra Renewables			181	19			3	1
Sempra Natural Gas			35	4			10	1
All other			3	―			11	1
Total		$	971	100	%	$	780	100	%
		March 31, 2016				December 31, 2015
ASSETS
SDG&E		$	16,625	40	%	$	16,515	40	%
SoCalGas			12,427	30			12,104	29
Sempra South American Utilities			3,434	8			3,235	8
Sempra Mexico			3,843	9			3,783	9
Sempra Renewables			1,454	3			1,441	4
Sempra Natural Gas			5,395	13			5,566	13
All other			741	2			734	2
Intersegment receivables			(2,084)	(5)			(2,228)	(5)
Total		$	41,835	100	%	$	41,150	100	%
EQUITY METHOD AND OTHER INVESTMENTS
Sempra South American Utilities		$	(2)			$	(4)
Sempra Mexico			522				519
Sempra Renewables			823				855
Sempra Natural Gas			1,308				1,460
All other			76				75
Total		$	2,727			$	2,905
(1)	Revenues for reportable segments include intersegment revenues of $3 million, $17 million, $27 million and $30 million for the three months ended March 31, 2016 and $2 million, $19 million, $25 million and $43 million for the three months ended March 31, 2015 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively.
(2)	After preferred dividends.

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

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Assets Held for Sale Table

SUBSEQUENT EVENTS	3 Months Ended
SUBSEQUENT EVENTS	Mar. 31, 2016
Subsequent Events (Abstract)
Subsequent Events	NOTE 13. SUBSEQUENT EVENT SEMPRA NATURAL GAS In April 2016, Sempra Natural Gas signed a definitive agreement to sell the parent company of Mobile Gas and Willmut Gas. We expect to receive cash proceeds of approximately $323 million, subject to normal adjustments at closing, and the buyer will assume existing debt of approximately $67 million. In April 2016, we reclassified the assets and liabilities of Mobile Gas and Willmut Gas to held for sale. The transaction is subject to customary regulatory approvals, and we expect the sale to close in 2016.

SIGNIFICANT ACCOUNTING POLICIES (Policies)	3 Months Ended
SIGNIFICANT ACCOUNTING POLICIES (Policies)	Mar. 31, 2016
Significant Accounting Policies
New Accounting Standards Policy	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 Accounting Standards Update (ASU) 2014-09, “Revenue from Contracts with Customers,” ASU 2015-14, “Revenue from Contracts with Customers: Deferral of the Effective Date,” ASU 2016-08, “Revenue from Contracts with Customers: Principal versus Agent Considerations (Reporting Revenue Gross versus Net),” and ASU 2016-10, “Revenue from Contracts with Customers: Identifying Performance Obligations and Licensing”: ASU 2014-09 provides accounting guidance for revenue from contracts with customers and affects all entities that enter into contracts to provide goods or services to their customers. The guidance also provides a model for the measurement and recognition of gains and losses on the sale of certain nonfinancial assets, such as property and equipment, including real estate. This guidance must be adopted using either a full retrospective approach for all periods presented in the period of adoption or a modified retrospective approach. Amending ASU 2014-09, ASU 2016-08 clarifies the implementation guidance on principal versus agent considerations and ASU 2016-10 clarifies the determination of whether a good or service is separately identifiable from other promises and revenue recognition related to licenses of intellectual property. ASU 2015-14 defers the effective date of ASU 2014-09 by one year for all entities and permits early adoption on a limited basis. For public entities, ASU 2014-09 is effective for fiscal years beginning after December 15, 2017, with early adoption permitted for fiscal years beginning after December 15, 2016, and is effective for interim periods in the year of adoption. We are currently evaluating the effect of the standards on our ongoing financial reporting and have not yet selected the year in which we will adopt the standards or our transition method. ASU 2016-01, “Recognition and Measurement of Financial Assets and Financial Liabilities”: In addition to the presentation and disclosure requirements for financial instruments, ASU 2016-01 requires entities to measure equity investments not accounted for under the equity method at fair value and recognize changes in fair value in net income. Entities will no longer be able to use the cost method of accounting for equity securities. However, for equity investments without readily determinable fair values, entities may elect a measurement alternative that will allow those investments to be recorded at cost, less impairment, and adjusted for subsequent observable price changes. Upon adoption, entities must record a cumulative-effect adjustment to the balance sheet as of the beginning of the first reporting period in which the standard is adopted. The guidance on equity securities without readily determinable fair value will be applied prospectively to all equity investments that exist as of the date of adoption of the standard. For public entities, ASU 2016-01 is effective for fiscal years beginning after December 15, 2017. We will adopt ASU 2016-01 on January 1, 2018 as required and do not expect it to materially affect our financial condition, results of operations or cash flows. We will make the required changes to our disclosures upon adoption. ASU 2016-02, “Leases”: ASU 2016-02 requires entities to include substantially all leases on the balance sheet by requiring the recognition of right-of-use assets and lease liabilities for all leases. Entities may elect to exclude from the balance sheet those leases with a maximum possible term of less than 12 months. For lessees, a lease is classified as finance or operating and the asset and liability are initially measured at the present value of the lease payments. For lessors, accounting for leases is largely unchanged from previous U.S. GAAP, other than certain changes to align lessor accounting to specific changes made to lessee accounting and ASU 2014-09. ASU 2016-02 also requires qualitative disclosures along with specific quantitative disclosures for both lessees and lessors. For public entities, ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, with early adoption permitted, and is effective for interim periods in the year of adoption. The standard requires lessees and lessors to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The modified retrospective approach includes optional practical expedients that may be elected, which would allow entities to continue to account for leases that commence before the effective date of the standard in accordance with previous U.S. GAAP unless the lease is modified, except for the lessee requirement to recognize right-of-use assets and lease liabilities for all operating leases at the reporting date. We are currently evaluating the effect of the standard on our ongoing financial reporting, and have not yet selected the year in which we will adopt the standard. ASU 2016-05, “Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships”: ASU 2016-05 provides clarification that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge accounting criteria continue to be met. ASU 2016-05 may be adopted prospectively or using a modified retrospective approach. We prospectively adopted ASU 2016-05 on January 1, 2016 and it did not affect our financial condition, results of operations or cash flows. ASU 2016-09, “Improvements to Employee Share-Based Payment Accounting”: ASU 2016-09 is intended to simplify several aspects of the accounting for employee share-based payment transactions. Under ASU 2016-09, excess tax benefits and tax deficiencies are required to be recorded in earnings, and the requirement to reclassify excess tax benefits from operating to financing activities on the statement of cash flows has been eliminated. ASU 2016-09 also allows entities to withhold taxes up to the maximum individual statutory tax rate without resulting in liability classification of the award and clarifies that cash payments made to taxing authorities in connection with withheld shares should be classified as financing activities in the statement of cash flows. Additionally, the standard provides for an accounting policy election to either continue to estimate forfeitures or account for them as they occur. For public entities, ASU 2016-09 is effective for fiscal years beginning after December 15, 2016, with early adoption permitted, and is effective for interim periods in the year of adoption. We are currently evaluating the full effect of the standard on our ongoing financial reporting, and have not yet concluded as to whether we will elect an early adoption. If we early adopt in 2016, we will recognize a $34 million tax benefit in earnings, which is currently recorded in Shareholders’ Equity, related to the three months ended March 31, 2016, and a benefit to retained earnings as of January 1, 2016 of approximately $107 million, both associated with the provision in ASU 2016-09 to recognize all excess tax benefits related to share-based compensation.
Consolidation Variable Interest Entity Policy	VARIABLE INTEREST ENTITIES We consolidate a VIE if we are the primary beneficiary of the VIE. Our determination of whether we are the primary beneficiary is based 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.
Noncontrolling Interest Policy	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 Condensed Consolidated Balance Sheets. Earnings or losses attributable to noncontrolling interests are separately identified on the Condensed Consolidated Statements of Operations, and comprehensive income or loss attributable to noncontrolling interests is separately identified on the Condensed Consolidated Statements of Comprehensive Income (Loss).
Earnings Per Share Policy	Basic EPS is calculated by dividing earnings attributable to common stock by the weighted-average number of common shares outstanding for the period. Diluted EPS includes the potential dilution of common stock equivalent shares that could occur if securities or other contracts to issue common stock were exercised or converted into common stock. The 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 recognized, minus tax shortfalls recognized, 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 of dilutive common stock equivalents 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). The dilution from unvested restricted stock awards (RSAs) and restricted stock units (RSUs) is also based on the treasury stock method. Proceeds equal to the unearned compensation and windfall tax benefits recognized, minus tax shortfalls recognized, 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 recognized 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. Our performance-based RSUs include awards that vest at the end of three-year (for awards granted during or after 2015) or four-year performance periods based on Sempra Energy’s total return to shareholders relative to that of specified market indices (Total Shareholder Return or TSR RSUs) or based on the compound annual growth rate of Sempra Energy’s EPS (EPS RSUs). The comparative market indices for the TSR RSUs are the Standard & Poor’s (S&P) 500 Utilities Index and the S&P 500 Index. We primarily use long-term analyst consensus growth estimates for S&P 500 Utilities Index peer companies to develop our EPS RSU targets. TSR RSUs represent the right to receive from zero to 1.5 shares (2.0 shares for awards granted during or after 2014) of Sempra Energy common stock if performance targets are met. EPS RSUs represent the right to receive from zero to 2.0 shares of Sempra Energy common stock if performance targets are met. If performance falls between the targets specified for each performance metric, we calculate the payout using linear interpolation. Participants also receive additional shares for dividend equivalents on shares subject to RSUs, which are deemed reinvested to purchase additional units that become subject to the same vesting conditions as the RSUs to which the dividends relate. Our RSAs, which are solely service-based, and those RSUs that are service-based or issued in connection with certain other performance goals represent the right to receive up to 1.0 share if the service requirements or certain other vesting conditions are met. These RSAs and RSUs have the same dividend equivalent rights as the performance-based RSUs described above. We include RSAs and these RSUs in potential dilutive shares at 100 percent, subject to the application of the treasury stock method. We include our TSR RSUs and EPS RSUs in potential dilutive shares at zero to up to 200 percent to the extent that they currently meet the performance requirements for vesting, subject to the application of the treasury stock method.
Interim period effective tax rate policy	Sempra Energy, SDG&E and SoCalGas record income taxes for interim periods utilizing a forecasted effective tax rate anticipated for the full year, as required by U.S. GAAP. The income tax effect of items that can be reliably forecasted is factored into the forecasted effective tax rate, and the impact is recognized proportionately over the year. Items that cannot be reliably forecasted (e.g., resolution of prior years’ income tax items, remeasurement of deferred tax asset valuation allowances, Mexican currency translation and inflation adjustments, and deferred income tax benefit associated with the impairment of a book investment) are recorded in the interim period in which they actually occur, which can result in variability in income tax expense. Sempra Energy’s income tax expense in the three months ended March 31, 2016 includes deferred income tax expense related to Sempra Mexico’s power plant held for sale, as we discuss in Note 3. For SDG&E and SoCalGas, the California Public Utilities Commission (CPUC) requires flow-through rate-making treatment for the current income tax benefit or expense arising from certain property-related and other temporary differences between the treatment for financial reporting and income tax, which will reverse over time. Under the regulatory accounting treatment required for these flow-through temporary differences, deferred income tax assets and liabilities are not recorded to deferred income tax expense, but rather to a regulatory asset or liability, which impacts the current effective income tax rate. 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: repairs expenditures related to a certain portion of utility plant assets the equity portion of AFUDC a portion of the cost of removal of utility plant assets utility self-developed software expenditures depreciation on a certain portion of utility plant assets state income taxes The AFUDC related to equity recorded for regulated construction projects at Sempra Mexico has similar flow-through treatment.
Fair Value Measurement Policy	We classify financial assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities, and their placement within the fair value hierarchy levels. The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 7 under “Financial Statement Presentation.” The determination of fair values, shown in the tables below, incorporates various factors, including but not limited to, the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits, letters of credit and priority interests). Our financial assets and liabilities that were accounted for at fair value on a recurring basis at March 31, 2016 and December 31, 2015 in the tables below include the following: Nuclear decommissioning trusts reflect the assets of SDG&E’s nuclear decommissioning trusts, excluding cash balances. A third party trustee values the trust assets using prices from a pricing service based on a market approach. We validate these prices by comparison to prices from other independent data sources. Equity and certain debt securities are valued using quoted prices listed on nationally recognized securities exchanges or based on closing prices reported in the active market in which the identical security is traded (Level 1). Other debt securities are valued based on yields that are currently available for comparable securities of issuers with similar credit ratings (Level 2). For commodity contracts, interest rate derivatives and foreign exchange instruments, we primarily use a market approach with market participant assumptions to value these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation techniques. These inputs can be readily observable, market corroborated, or generally unobservable. We have exchange-traded derivatives that are valued based on quoted prices in active markets for the identical instruments (Level 1). We also may have other commodity derivatives that are valued using industry standard models that consider quoted forward prices for commodities, time value, current market and contractual prices for the underlying instruments, volatility factors, and other relevant economic measures (Level 2). Level 3 recurring items relate to CRRs and long-term, fixed-price electricity positions at SDG&E, as we discuss below under “Level 3 Information.” Rabbi Trust investments include marketable securities that we value using a market approach based on closing prices reported in the active market in which the identical security is traded (Level 1). These investments in marketable securities were negligible at both March 31, 2016 and December 31, 2015. SDG&E’s Energy and Fuel Procurement department, in conjunction with SDG&E’s finance group, is responsible for determining the appropriate fair value methodologies used to value and classify CRRs and long-term, fixed-price electricity positions on an ongoing basis. Inputs used to determine the fair value of CRRs and fixed-price electricity positions are reviewed and compared with market conditions to determine reasonableness. SDG&E expects all costs related to these instruments to be recoverable through customer rates. As such, there is no impact to earnings from changes in the fair value of these instruments. CRRs are recorded at fair value based almost entirely on the most current auction prices published by the California Independent System Operator (CAISO), an objective source. Annual auction prices are published once a year, typically in the middle of November, and remain in effect for the following year. The impact associated with discounting is negligible. Because auction prices are a less observable input, these instruments are classified as Level 3. The fair value of these instruments is derived from auction price differences between two locations. From January 1, 2016 to December 31, 2016, the auction prices range from $(24) per MWh to $10 per MWh at a given location, and from January 1, 2015 to December 31, 2015, the auction prices ranged from $(16) per MWh to $8 per MWh at a given location. Positive values between two locations represent expected future reductions in congestion costs, whereas negative values between two locations represent expected future charges. Valuation of our CRRs is sensitive to a change in auction price. If auction prices at one location increase (decrease) relative to another location, this could result in a higher (lower) fair value measurement. We summarize CRR volumes in Note 7. Long-term, fixed-price electricity positions that are valued using significant unobservable data are classified as Level 3 because the contract terms relate to a delivery location or tenor for which observable market rate information is not available. The fair value of the net electricity positions classified as Level 3 is derived from a discounted cash flow model using market electricity forward price inputs. At March 31, 2016, these electricity forward prices range from $15.85 per MWh to $57.43 per MWh. A significant increase or decrease in market electricity forward prices would result in a significantly higher or lower fair value, respectively. We summarize long-term, fixed-price electricity position volumes in Note 7. Realized gains and losses associated with CRRs and long-term electricity positions, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations. Unrealized gains and losses are recorded as regulatory assets and liabilities and therefore also do not affect earnings. Fair Value of Financial Instruments The fair values of certain of our financial instruments (cash, temporary investments, accounts and notes receivable, current amounts due to/from unconsolidated affiliates, dividends and accounts payable, short-term debt and customer deposits) approximate their carrying amounts because of the short-term nature of these instruments. Investments in life insurance contracts that we hold in support of our Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans are carried at cash surrender values, which represent the amount of cash that could be realized under the contracts. We base the fair value of certain noncurrent amounts due from unconsolidated affiliates, long-term debt and preferred stock on a market approach using quoted market prices for identical or similar securities in thinly-traded markets (Level 2). We value other noncurrent amounts due from unconsolidated affiliates of Sempra South American Utilities using a perpetuity approach based on the obligation’s fixed interest rate, the absence of a stated maturity date and a discount rate reflecting local borrowing costs (Level 3). We value other long-term debt using an income approach based on the present value of estimated future cash flows discounted at rates available for similar securities (Level 3).
Derivatives Policy	We use derivative instruments primarily to manage exposures arising in the normal course of business. Our principal exposures are commodity market risk, benchmark interest rate risk and foreign exchange rate exposures. Our use of derivatives for these risks is integrated into the economic management of our anticipated revenues, anticipated expenses, assets and liabilities. Derivatives may be effective in mitigating these risks (1) that could lead to declines in anticipated revenues or increases in anticipated expenses, or (2) that our asset values may fall or our liabilities increase. Accordingly, our derivative activity summarized below generally represents an impact that is intended to offset associated revenues, expenses, assets or liabilities that are not included in the tables below. In certain cases, we apply the normal purchase or sale exception to derivative instruments and have other commodity contracts that are not derivatives. These contracts are not recorded at fair value and are therefore excluded from the disclosures below. In all other cases, we record derivatives at fair value on the Condensed Consolidated Balance Sheets. We designate each derivative as (1) a cash flow hedge, (2) a fair value hedge, or (3) undesignated. Depending on the applicability of hedge accounting and, for the California Utilities and other operations subject to regulatory accounting, the requirement to pass impacts through to customers, the impact of derivative instruments may be offset in other comprehensive income (loss) (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 Condensed Consolidated Statements of Cash Flows. HEDGE ACCOUNTING We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated cash flows associated with revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accounting for derivative commodity instruments, foreign currency instruments and interest rate instruments. Designating cash flow hedges is dependent on the business context in which the instrument is being used, the effectiveness of the instrument in offsetting the risk that the future cash flows of a given revenue or expense item may vary, and other criteria. 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 instrument 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, as follows: The California Utilities use energy derivatives, both natural gas and electricity, for the benefit of customers, with the objective of managing price risk and basis risks, and stabilizing and lowering natural gas and electricity costs. These derivatives include fixed price natural gas and electricity positions, options, and basis risk instruments, which are either exchange-traded or over-the-counter financial instruments, or bilateral physical transactions. This activity is governed by risk management and transacting activity plans that have been filed with and approved by the CPUC. Natural gas and electricity derivative activities are recorded as commodity costs that are offset by regulatory account balances and are recovered in rates. Net commodity cost impacts on the Condensed Consolidated Statements of Operations are reflected in Cost of Electric Fuel and Purchased Power or in Cost of Natural Gas. SDG&E is allocated and may purchase 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, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations. Sempra Mexico and Sempra Natural Gas may use natural gas and electricity derivatives, as appropriate, to optimize the earnings of their assets which support the following businesses: liquefied natural gas (LNG), natural gas transportation, power generation, and Sempra Natural Gas’ storage. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues or in Cost of Natural Gas, Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations. Certain of these derivatives may also be designated as cash flow hedges. 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 Condensed Consolidated Statements of Operations. From time to time, our various businesses, including the California Utilities, may use other energy derivatives to hedge exposures such as the price of vehicle fuel. In addition to the amounts noted above, we frequently use commodity derivatives to manage risks associated with the physical locations of contractual obligations and assets, such as natural gas purchases and sales. INTEREST RATE DERIVATIVES We are exposed to interest rates primarily as a result of our current and expected use of financing. 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, 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. Interest rate derivatives are generally accounted for as hedges, and 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 energy derivatives. Separately, Otay Mesa VIE has entered into interest rate swap agreements, designated as cash flow hedges, to moderate its exposure to interest rate changes. FOREIGN CURRENCY DERIVATIVES We utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries and joint ventures. These cash flow hedges exchange our Mexican-peso denominated principal and interest payments into the U.S. dollar and swap Mexican variable interest rates for U.S. fixed interest rates. We are also exposed to exchange rate movements at our Mexican subsidiaries and joint ventures, which have U.S. dollar denominated cash balances, receivables, payables and debt (monetary assets and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. They also have deferred income tax assets and liabilities denominated in the Mexican peso, which must be translated to U.S. dollars for financial reporting purposes. In addition, monetary assets and liabilities and certain nonmonetary assets and liabilities are adjusted for Mexican inflation for Mexican income tax purposes. We utilize foreign currency derivatives as a means to manage the risk of exposure to significant fluctuations in our income tax expense and equity earnings from these impacts. In January 2016, we entered into foreign currency derivatives with a notional amount totaling $550 million.
Legal Costs Policy	LEGAL PROCEEDINGS We accrue losses for a legal proceeding when it is probable that a loss has been incurred and the amount of the loss can be reasonably estimated.
Segment Policy	Common services shared by the business segments are assigned directly or allocated based on various cost factors, depending on the nature of the service provided. Interest income and expense is recorded on intercompany loans. The loan balances and related interest are eliminated in consolidation.

RECENT INVESTMENT ACTIVITY (Tables)

3 Months Ended

Mar. 31, 2016

Investments [Abstract]

ASSETS HELD FOR SALE, POWER PLANT
(Dollars in millions)
		March 31, 2016
Cash and cash equivalents		$	1
Inventories			8
Other current assets			29
Other assets			15
Property, plant and equipment, net			250
Total assets held for sale		$	303

Accounts payable		$	1
Other current liabilities			7
Deferred income taxes			16
Asset retirement obligations			4
Other liabilities			15
Total liabilities held for sale(1)		$	43
(1)	Included in Other Current Liabilities on the Sempra Energy Condensed Consolidated Balance Sheet.

Tabular disclosure of information related to a disposal group. Includes, but is not limited to, a discontinued operation, disposal classified as held-for-sale or disposed of by means other than sale or disposal of an individually significant component.

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Net Periodic Benefit Cost Table

OTHER FINANCIAL DATA (Tables)

3 Months Ended

Mar. 31, 2016

Disclosure Text Block [Abstract]

NET PERIODIC BENEFIT COST – SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended March 31,
	2016		2015		2016		2015
Service cost	$	28	$	30	$	5	$	7
Interest cost		40		39		11		12
Expected return on assets		(42)		(44)		(17)		(17)
Amortization of:
Prior service cost (credit)		3		3		―		(1)
Actuarial loss		6		8		―		―
Regulatory adjustment		(28)		(29)		2		―
Total net periodic benefit cost	$	7	$	7	$	1	$	1

NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended March 31,
	2016		2015		2016		2015
Service cost	$	7	$	8	$	1	$	2
Interest cost		10		10		2		2
Expected return on assets		(12)		(14)		(3)		(3)
Amortization of:
Prior service cost		―		―		1		1
Actuarial loss		3		2		―		―
Regulatory adjustment		(7)		(5)		(1)		(2)
Total net periodic benefit cost	$	1	$	1	$	―	$	―

NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended March 31,
	2016		2015		2016		2015
Service cost	$	17	$	19	$	4	$	5
Interest cost		25		25		8		9
Expected return on assets		(25)		(27)		(14)		(14)
Amortization of:
Prior service cost (credit)		2		2		(1)		(2)
Actuarial loss		3		5		―		―
Regulatory adjustment		(21)		(24)		3		2
Total net periodic benefit cost	$	1	$	―	$	―	$	―

Contributions to Benefit Plans Table

BENEFIT PLAN CONTRIBUTIONS
(Dollars in millions)
	Sempra Energy
	Consolidated		SDG&E		SoCalGas
Contributions through March 31, 2016:
Pension plans	$	15	$	2	$	―
Other postretirement benefit plans		1		―		―
Total expected contributions in 2016:
Pension plans	$	123	$	4	$	77
Other postretirement benefit plans		6		2		1

Earnings Per Share Computations Table

EARNINGS PER SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
		Three months ended March 31,
		2016		2015
Numerator:
Earnings/Income attributable to common shares		$	319	$	437

Denominator:
Weighted-average common shares
	outstanding for basic EPS(1)		249,734		247,722
Dilutive effect of stock options, restricted
	stock awards and restricted stock units		1,678		3,484
Weighted-average common shares
	outstanding for diluted EPS		251,412		251,206

Earnings per share:
Basic		$	1.28	$	1.76
Diluted		$	1.27	$	1.74
(1)	Includes 555 and 452 average fully vested restricted stock units held in our Deferred Compensation Plan for the three months ended March 31, 2016 and 2015, respectively. These fully vested restricted stock units are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

Capitalized Financing Costs Table

CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Three months ended March 31,
	2016		2015
Sempra Energy Consolidated:
AFUDC related to debt	$	7	$	6
AFUDC related to equity		27		27
Other capitalized interest		18		17
Total Sempra Energy Consolidated	$	52	$	50
SDG&E:
AFUDC related to debt	$	4	$	3
AFUDC related to equity		11		8
Total SDG&E	$	15	$	11
SoCalGas:
AFUDC related to debt	$	3	$	3
AFUDC related to equity		10		9
Total SoCalGas	$	13	$	12

Changes in Components of Accumulated Comprehensive Income Table

CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1)
SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
		Three months ended March 31, 2016 and 2015
		Foreign						Total
		currency				Pension and other		accumulated other
		translation		Financial		postretirement		comprehensive
		adjustments		instruments		benefits		income (loss)
2016:
Balance as of December 31, 2015		$	(582)	$	(137)	$	(87)	$	(806)
Other comprehensive income (loss) before
reclassifications			68		(82)		―		(14)
Amounts reclassified from accumulated other
comprehensive income			―		(2)		1		(1)
Net other comprehensive income (loss)			68		(84)		1		(15)
Balance as of March 31, 2016		$	(514)	$	(221)	$	(86)	$	(821)
2015:
Balance as of December 31, 2014		$	(322)	$	(90)	$	(85)	$	(497)
Other comprehensive loss before
reclassifications			(62)		(54)		―		(116)
Amounts reclassified from accumulated other
comprehensive income			―		(1)		1		―
Net other comprehensive (loss) income			(62)		(55)		1		(116)
Balance as of March 31, 2015		$	(384)	$	(145)	$	(84)	$	(613)
(1)	All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests.

Reclassifications out of AOCI Table

RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
		Amounts reclassified
Details about accumulated		from accumulated other				Affected line item on Condensed
other comprehensive income (loss) components		comprehensive income (loss)				Consolidated Statements of Operations
		Three months ended March 31,
		2016		2015
Sempra Energy Consolidated:
Financial instruments:
Interest rate and foreign exchange instruments		$	4	$	6	Interest Expense
Interest rate instruments			3		3	Equity (Losses) Earnings, Before Income Tax
Interest rate and foreign exchange instruments			1		―	Equity Earnings, Net of Income Tax
Commodity contracts not subject
	to rate recovery		(7)		(7)	Revenues: Energy-Related Businesses
Total before income tax			1		2
			―		1	Income Tax Expense
Net of income tax			1		3
			(3)		(4)	Earnings Attributable to Noncontrolling Interests
		$	(2)	$	(1)

Pension and other postretirement benefits:
Amortization of actuarial loss		$	2	$	2	See note (1) below
			(1)		(1)	Income Tax Expense
Net of income tax		$	1	$	1

Total reclassifications for the period, net of tax		$	(1)	$	―
SDG&E:
Financial instruments:
Interest rate instruments		$	3	$	3	Interest Expense
			(3)		(3)	Earnings Attributable to Noncontrolling Interest
Total reclassifications for the period		$	―	$	―
(1)	Amounts are included in the computation of net periodic benefit cost (see "Pension and Other Postretirement Benefits" above).

Shareholders' Equity and Noncontrolling Interests Table

SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS – SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
			Sempra Energy		Non-
			shareholders’		controlling		Total
			equity		interests(1)		equity
Balance at December 31, 2015		$	11,809	$	770	$	12,579
Comprehensive income			304		11		315
Share-based compensation expense			13		―		13
Common stock dividends declared			(188)		―		(188)
Issuances of common stock			28		―		28
Repurchases of common stock			(54)		―		(54)
Tax benefit related to share-based compensation			34		―		34
Distributions to noncontrolling interests			―		(3)		(3)
Balance at March 31, 2016		$	11,946	$	778	$	12,724
Balance at December 31, 2014		$	11,326	$	774	$	12,100
Comprehensive income			321		8		329
Share-based compensation expense			13		―		13
Common stock dividends declared			(173)		―		(173)
Issuances of common stock			30		―		30
Repurchases of common stock			(65)		―		(65)
Tax benefit related to share-based compensation			52		―		52
Distributions to noncontrolling interests			―		(5)		(5)
Balance at March 31, 2015		$	11,504	$	777	$	12,281
(1)	Noncontrolling interests include the preferred stock of SoCalGas and other noncontrolling interests as listed in the table below under "Other Noncontrolling Interests."

SHAREHOLDER'S EQUITY AND NONCONTROLLING INTEREST – SDG&E
(Dollars in millions)
		SDG&E		Non-
		shareholder’s		controlling		Total
		equity		interest		equity
Balance at December 31, 2015	$	5,223	$	53	$	5,276
Comprehensive income (loss)		129		(1)		128
Distributions to noncontrolling interest		―		(1)		(1)
Balance at March 31, 2016	$	5,352	$	51	$	5,403
Balance at December 31, 2014	$	4,932	$	60	$	4,992
Comprehensive income		147		2		149
Distributions to noncontrolling interest		―		(3)		(3)
Balance at March 31, 2015	$	5,079	$	59	$	5,138

Amounts Due To and From Affiliates at SDG&E and SoCalGas Table

AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
		March 31, 2016		December 31, 2015
Sempra Energy Consolidated:
Total due from various unconsolidated affiliates - current		$	7	$	6

Sempra South American Utilities(1):
Eletrans S.A. and Eletrans II S.A.:
4% Note(2)		$	76	$	72
Other related party receivables			1		―
Sempra Mexico(1):
Affiliate of joint venture with PEMEX:
Note due November 13, 2017(3)			3		3
Note due November 14, 2018(3)			42		42
Note due November 14, 2018(3)			34		34
Note due November 14, 2018(3)			8		8
Energía Sierra Juárez:
Note due June 15, 2018(4)			17		24
Sempra Natural Gas:
Cameron LNG JV			5		3
Total due from unconsolidated affiliates - noncurrent		$	186	$	186

Total due to various unconsolidated affiliates - current		$	(13)	$	(14)
SDG&E:
Total due from various unconsolidated affiliates - current		$	1	$	1

Sempra Energy		$	(35)	$	(34)
SoCalGas			(8)		(13)
Affiliate			(6)		(8)
Total due to unconsolidated affiliates - current		$	(49)	$	(55)

Income taxes due (to) from Sempra Energy(5)		$	(32)	$	28
SoCalGas:
Sempra Energy(6)		$	―	$	35
SDG&E			8		13
Total due from unconsolidated affiliates - current		$	8	$	48

Sempra Energy		$	(34)	$	―
Total due to unconsolidated affiliate - current		$	(34)	$	―

Income taxes due (to) from Sempra Energy(5)		$	(23)	$	1
(1)	Amounts include principal balances plus accumulated interest outstanding.
(2)	U.S. dollar-denominated loan, at a fixed interest rate with no stated maturity date, to provide project financing for the construction of transmission lines at Eletrans S.A. and Eletrans II S.A., both of which are joint ventures at Chilquinta Energía.
(3)	U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 450 basis points (4.94 percent at March 31, 2016), to finance the Los Ramones Norte pipeline project.
(4)	U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 637.5 basis points (6.81 percent at March 31, 2016), to finance the first phase of the Energía Sierra Juárez wind project.
(5)	SDG&E and SoCalGas are included in the consolidated income tax return of Sempra Energy and are allocated income tax expense from Sempra Energy in an amount equal to that which would result from each company having always filed a separate return.
(6)	At December 31, 2015, net receivable included outstanding advances to Sempra Energy of $50 million at an interest rate of 0.11 percent.

Revenues From Unconsolidated Affiliates at SDG&E and SoCalGas Table

REVENUES AND COST OF SALES FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended March 31,
	2016		2015
REVENUES
Sempra Energy Consolidated	$	5	$	8
SDG&E		3		3
SoCalGas		17		19
COST OF SALES
Sempra Energy Consolidated	$	30	$	19
SDG&E		14		5

Other Income and Expense Table

OTHER INCOME, NET
(Dollars in millions)
		Three months ended March 31,
		2016		2015
Sempra Energy Consolidated:
Allowance for equity funds used during construction		$	27	$	27
Investment gains(1)			10		9
Electrical infrastructure relocation income(2)			1		―
Gains on interest rate and foreign exchange instruments, net			3		―
Sale of other investments			1		―
Foreign currency transaction losses			(2)		(1)
Regulatory interest, net(3)			2		1
Sundry, net			7		3
Total		$	49	$	39
SDG&E:
Allowance for equity funds used during construction		$	11	$	8
Regulatory interest, net(3)			2		1
Sundry, net			1		―
Total		$	14	$	9
SoCalGas:
Allowance for equity funds used during construction		$	10	$	9
Sundry, net			―		(1)
Total		$	10	$	8
(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)	Income at Luz del Sur associated with the relocation of electrical infrastructure.
(3)	Interest on regulatory balancing accounts.

Income Tax Expense and Effective Income Tax Rates Table

INCOME TAX EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
			Effective				Effective
		Income tax	income			Income tax	income
		expense	tax rate			expense	tax rate
		Three months ended March 31,
		2016				2015
Sempra Energy Consolidated	$	142	31	%	$	163	27	%
SDG&E		72	36			88	37
SoCalGas		87	31			95	31

Variable Interest Entity Table

AMOUNTS ASSOCIATED WITH OTAY MESA VIE
(Dollars in millions)
	Three months ended March 31,
	2016		2015
Operating expenses
Cost of electric fuel and purchased power	$	(17)	$	(18)
Operation and maintenance		4		4
Depreciation and amortization		7		6
Total operating expenses		(6)		(8)
Operating income		6		8
Interest expense		(5)		(4)
Income before income taxes/Net income		1		4
Earnings attributable to noncontrolling interest		(1)		(4)
Earnings attributable to common shares	$	―	$	―

Ownership Interests Held By Others Table

OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
		Percent ownership held by others
		March 31,		December 31,			March 31,		December 31,
		2016		2015			2016		2015
SDG&E:
Otay Mesa VIE		100	%	100	%	$	51	$	53
Sempra South American Utilities:
Chilquinta Energía subsidiaries(1)		23.5 – 43.4		23.5 – 43.4			22		21
Luz del Sur		16.4		16.4			171		164
Tecsur		9.8		9.8			4		4
Sempra Mexico:
IEnova		18.9		18.9			470		468
Sempra Natural Gas:
Bay Gas Storage Company, Ltd.		9.1		9.1			25		25
Liberty Gas Storage, LLC		23.2		23.2			14		14
Southern Gas Transmission Company		49.0		49.0			1		1
Total Sempra Energy						$	758	$	750
(1)	Chilquinta Energía has four subsidiaries with noncontrolling interests held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.

Inventory Table

INVENTORY BALANCES
(Dollars in millions)
		Natural gas				Liquefied natural gas				Materials and supplies				Total
		March 31, 2016		December 31, 2015		March 31, 2016		December 31, 2015		March 31, 2016		December 31, 2015		March 31, 2016		December 31, 2015
SDG&E		$	3	$	6	$	―	$	―	$	69	$	69	$	72	$	75
SoCalGas(1)			―		49		―		―		33		30		33		79
Sempra South American
Utilities			―		―		―		―		37		30		37		30
Sempra Mexico			―		―		6		3		2		10		8		13
Sempra Renewables			―		―		―		―		3		3		3		3
Sempra Natural Gas			74		94		3		3		1		1		78		98
Sempra Energy
Consolidated		$	77	$	149	$	9	$	6	$	145	$	143	$	231	$	298
(1)	At both March 31, 2016 and December 31, 2015, SoCalGas' natural gas inventory for core customers is net of the estimated inventory loss related to the Aliso Canyon natural gas leak, which we discuss in Note 11.

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)

3 Months Ended

Mar. 31, 2016

Derivative Instruments And Hedging Activities Disclosure [Abstract]

Commodity Derivative Volumes Table

NET ENERGY DERIVATIVE VOLUMES
(Quantities in millions)
			March 31,	December 31,
Segment and Commodity		Unit of measure	2016	2015
California Utilities:
SDG&E:
Natural gas		MMBtu(1)	60	70
Electricity		MWh(2)	―	1
Congestion revenue rights		MWh	33	36
SoCalGas – natural gas		MMBtu	―	1

Energy-Related Businesses:
Sempra Natural Gas – natural gas		MMBtu	39	43
(1)	Million British thermal units
(2)	Megawatt hours

Notional Amounts of Interest Rate Derivatives Table

INTEREST RATE DERIVATIVES
(Dollars in millions)
		March 31, 2016			December 31, 2015
		Notional debt		Maturities	Notional debt		Maturities
Sempra Energy Consolidated:
Cash flow hedges(1)		$	381	2016-2028	$	384	2016-2028
Fair value hedges			300	2016		300	2016
SDG&E:
Cash flow hedge(1)			312	2016-2019		315	2016-2019
(1)	Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE.

FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	March 31, 2016			December 31, 2015
	Notional debt		Maturities	Notional debt		Maturities
Sempra Mexico:
Cross-currency swaps	$	408	2018-2023	$	408	2018-2023
Other foreign currency derivatives		550	2016		―	―

Derivative Instruments on the Condensed Consolidated Balance Sheets Table

DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
		March 31, 2016
									Deferred
									credits
			Current				Current		and other
			assets:				liabilities:		liabilities:
			Fixed-price				Fixed-price		Fixed-price
			contracts		Other		contracts		contracts
			and other		assets:		and other		and other
			derivatives(1)		Sundry		derivatives(2)		derivatives
Sempra Energy Consolidated:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments(3)		$	5	$	―	$	(15)	$	(166)
Derivatives not designated as hedging instruments:
Interest rate and foreign exchange instruments			3		―		―		―
Commodity contracts not subject to rate recovery			144		20		(144)		(9)
Associated offsetting commodity contracts			(135)		(9)		135		9
Associated offsetting cash collateral			―		―		7		―
Commodity contracts subject to rate recovery			23		51		(68)		(61)
Associated offsetting commodity contracts			(4)		(1)		4		1
Associated offsetting cash collateral			―		―		31		24
Net amounts presented on the balance sheet			36		61		(50)		(202)
Additional cash collateral for commodity contracts
not subject to rate recovery			20		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			32		―		―		―
Total(4)		$	88	$	61	$	(50)	$	(202)
SDG&E:
Derivatives designated as hedging instruments:
Interest rate instruments(3)		$	―	$	―	$	(14)	$	(25)
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery			―		―		(1)		―
Associated offsetting cash collateral			―		―		1		―
Commodity contracts subject to rate recovery			20		51		(65)		(61)
Associated offsetting commodity contracts			(2)		(1)		2		1
Associated offsetting cash collateral			―		―		31		24
Net amounts presented on the balance sheet			18		50		(46)		(61)
Additional cash collateral for commodity contracts
not subject to rate recovery			2		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			30		―		―		―
Total(4)		$	50	$	50	$	(46)	$	(61)
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery		$	―	$	―	$	(1)	$	―
Associated offsetting cash collateral			―		―		1		―
Commodity contracts subject to rate recovery			3		―		(3)		―
Associated offsetting commodity contracts			(2)		―		2		―
Net amounts presented on the balance sheet			1		―		(1)		―
Additional cash collateral for commodity contracts
not subject to rate recovery			1		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			2		―		―		―
Total		$	4	$	―	$	(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.
(4)	Normal purchase contracts previously measured at fair value are excluded.

DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
		December 31, 2015
									Deferred
									credits
			Current				Current		and other
			assets:				liabilities:		liabilities:
			Fixed-price				Fixed-price		Fixed-price
			contracts		Other		contracts		contracts
			and other		assets:		and other		and other
			derivatives(1)		Sundry		derivatives(2)		derivatives
Sempra Energy Consolidated:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments(3)		$	4	$	1	$	(15)	$	(156)
Commodity contracts not subject to rate recovery			13		―		―		―
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery			245		32		(239)		(21)
Associated offsetting commodity contracts			(232)		(20)		232		20
Associated offsetting cash collateral			(6)		―		4		―
Commodity contracts subject to rate recovery			28		49		(61)		(64)
Associated offsetting commodity contracts			(2)		(2)		2		2
Associated offsetting cash collateral			―		―		28		26
Net amounts presented on the balance sheet			50		60		(49)		(193)
Additional cash collateral for commodity contracts
not subject to rate recovery			2		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			28		―		―		―
Total(4)		$	80	$	60	$	(49)	$	(193)
SDG&E:
Derivatives designated as hedging instruments:
Interest rate instruments(3)		$	―	$	―	$	(14)	$	(23)
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery			―		―		(1)		―
Associated offsetting cash collateral			―		―		1		―
Commodity contracts subject to rate recovery			27		49		(60)		(64)
Associated offsetting commodity contracts			(2)		(2)		2		2
Associated offsetting cash collateral			―		―		28		26
Net amounts presented on the balance sheet			25		47		(44)		(59)
Additional cash collateral for commodity contracts
not subject to rate recovery			1		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			27		―		―		―
Total(4)		$	53	$	47	$	(44)	$	(59)
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery		$	―	$	―	$	(1)	$	―
Associated offsetting cash collateral			―		―		1		―
Commodity contracts subject to rate recovery			1		―		(1)		―
Net amounts presented on the balance sheet			1		―		(1)		―
Additional cash collateral for commodity contracts
subject to rate recovery			1		―		―		―
Total		$	2	$	―	$	(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.
(4)	Normal purchase contracts previously measured at fair value are excluded.

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

FAIR VALUE HEDGE IMPACTS
(Dollars in millions)
			Pretax gain on derivatives
			recognized in earnings
			Three months ended March 31,
		Location	2016		2015
Sempra Energy Consolidated:
Interest rate instruments		Interest Expense	$	2	$	2
Interest rate instruments		Other Income, Net		―		1
Total(1)			$	2	$	3
(1)	There was no hedge ineffectiveness in either the three months ended March 31, 2016 or 2015. All other 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 and recorded in Other Income, Net.

Cash Flow Hedge Impact on the Condensed Consolidated Statements of Operations Table

CASH FLOW HEDGE IMPACTS
(Dollars in millions)
		Pretax (loss) gain					Pretax (loss) gain reclassified
		recognized in OCI					from AOCI into earnings
		(effective portion)					(effective portion)
		Three months ended March 31,					Three months ended March 31,
		2016		2015		Location	2016		2015
Sempra Energy Consolidated:
Interest rate and foreign
exchange instruments(1)		$	(11)	$	(18)	Interest Expense	$	(4)	$	(6)
						Equity (Losses) Earnings,
Interest rate instruments			(137)		(78)	Before Income Tax		(3)		(3)
Interest rate and foreign						Equity Earnings,
exchange instruments			(18)		―	Net of Income Tax		(1)		―
Commodity contracts not						Revenues: Energy-Related
subject to rate recovery			1		(1)	Businesses		7		7
Total(2)		$	(165)	$	(97)		$	(1)	$	(2)
SDG&E:
Interest rate instruments(1)(2)		$	(5)	$	(5)	Interest Expense	$	(3)	$	(3)
(1)	Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.
(2)	Amounts include negligible hedge ineffectiveness in the three months ended March 31, 2016 and 2015.

Undesignated Derivative Impact on the Condensed Consolidated Statements of Operations Table

UNDESIGNATED DERIVATIVE IMPACTS
(Dollars in millions)
		Pretax gain (loss) on derivatives
		recognized in earnings
		Three months ended March 31,
	Location	2016		2015
Sempra Energy Consolidated:
Foreign exchange instruments	Other Income, Net	$	3	$	―
Foreign exchange instruments	Equity Earnings,
	Net of Income Tax		2		(1)
Commodity contracts not subject	Revenues: Energy-Related
to rate recovery	Businesses		(1)		3
Commodity contracts subject	Cost of Electric Fuel
to rate recovery	and Purchased Power		(12)		(20)
Commodity contracts subject
to rate recovery	Cost of Natural Gas		(1)		1
Total		$	(9)	$	(17)
SDG&E:
Commodity contracts subject	Cost of Electric Fuel
to rate recovery	and Purchased Power	$	(12)	$	(20)
SoCalGas:
Commodity contracts subject
to rate recovery	Cost of Natural Gas	$	(1)	$	1

Tabular disclosure of pertinent information about a derivative or group of derivatives on a disaggregated basis, such as for individual instruments, or small groups of similar instruments. May include a combination of the type of instrument, risks being hedged, notional amount, hedge designation, related hedged item, inception date, maturity date, or other relevant item.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=56946850&loc=d3e41641-113959

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
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-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5624163-113959

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
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Reference 5: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
-Topic 815
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Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
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Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4C
-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5624171-113959

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
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-URI http://asc.fasb.org/extlink&oid=6886632&loc=d3e76258-113986

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
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-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5579240-113959

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
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-URI http://asc.fasb.org/extlink&oid=56946850&loc=d3e41620-113959

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
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-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

Recurring Fair Value Measures Table

FAIR VALUE MEASUREMENTS (Tables)

3 Months Ended

Mar. 31, 2016

Fair Value Disclosures [Abstract]

RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
		Fair value at March 31, 2016
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Nuclear decommissioning trusts:
Equity securities		$	623	$	―	$	―	$	―	$	623
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			62		43		―		―		105
Municipal bonds			―		156		―		―		156
Other securities			―		190		―		―		190
Total debt securities			62		389		―		―		451
Total nuclear decommissioning trusts(2)			685		389		―		―		1,074
Interest rate and foreign exchange instruments			―		8		―		―		8
Commodity contracts not subject to rate recovery			1		19		―		20		40
Commodity contracts subject to rate recovery			―		1		68		32		101
Total		$	686	$	417	$	68	$	52	$	1,223

Liabilities:
Interest rate and foreign exchange instruments		$	―	$	181	$	―	$	―	$	181
Commodity contracts not subject to rate recovery			3		6		―		(7)		2
Commodity contracts subject to rate recovery			―		67		57		(55)		69
Total		$	3	$	254	$	57	$	(62)	$	252

		Fair value at December 31, 2015
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Nuclear decommissioning trusts:
Equity securities		$	619	$	―	$	―	$	―	$	619
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			47		44		―		―		91
Municipal bonds			―		156		―		―		156
Other securities			―		182		―		―		182
Total debt securities			47		382		―		―		429
Total nuclear decommissioning trusts(2)			666		382		―		―		1,048
Interest rate and foreign exchange instruments			―		5		―		―		5
Commodity contracts not subject to rate recovery			22		16		―		(4)		34
Commodity contracts subject to rate recovery			―		1		72		28		101
Total		$	688	$	404	$	72	$	24	$	1,188

Liabilities:
Interest rate and foreign exchange instruments		$	―	$	171	$	―	$	―	$	171
Commodity contracts not subject to rate recovery			5		3		―		(4)		4
Commodity contracts subject to rate recovery			―		68		53		(54)		67
Total		$	5	$	242	$	53	$	(58)	$	242
(1)	Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.
(2)	Excludes cash balances and cash equivalents.

RECURRING FAIR VALUE MEASURES – SDG&E
(Dollars in millions)
		Fair value at March 31, 2016
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Nuclear decommissioning trusts:
Equity securities		$	623	$	―	$	―	$	―	$	623
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			62		43		―		―		105
Municipal bonds			―		156		―		―		156
Other securities			―		190		―		―		190
Total debt securities			62		389		―		―		451
Total nuclear decommissioning trusts(2)			685		389		―		―		1,074
Commodity contracts not subject to rate recovery			―		―		―		2		2
Commodity contracts subject to rate recovery			―		―		68		30		98
Total		$	685	$	389	$	68	$	32	$	1,174

Liabilities:
Interest rate instruments		$	―	$	39	$	―	$	―	$	39
Commodity contracts not subject to rate recovery			1		―		―		(1)		―
Commodity contracts subject to rate recovery			―		66		57		(55)		68
Total		$	1	$	105	$	57	$	(56)	$	107

		Fair value at December 31, 2015
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Nuclear decommissioning trusts:
Equity securities		$	619	$	―	$	―	$	―	$	619
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			47		44		―		―		91
Municipal bonds			―		156		―		―		156
Other securities			―		182		―		―		182
Total debt securities			47		382		―		―		429
Total nuclear decommissioning trusts(2)			666		382		―		―		1,048
Commodity contracts not subject to rate recovery			―		―		―		1		1
Commodity contracts subject to rate recovery			―		―		72		27		99
Total		$	666	$	382	$	72	$	28	$	1,148

Liabilities:
Interest rate instruments		$	―	$	37	$	―	$	―	$	37
Commodity contracts not subject to rate recovery			1		―		―		(1)		―
Commodity contracts subject to rate recovery			―		67		53		(54)		66
Total		$	1	$	104	$	53	$	(55)	$	103
(1)	Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.
(2)	Excludes cash balances and cash equivalents.

RECURRING FAIR VALUE MEASURES – SOCALGAS
(Dollars in millions)
		Fair value at March 31, 2016
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Commodity contracts not subject to rate recovery		$	―	$	―	$	―	$	1	$	1
Commodity contracts subject to rate recovery			―		1		―		2		3
Total		$	―	$	1	$	―	$	3	$	4

Liabilities:
Commodity contracts not subject to rate recovery		$	1	$	―	$	―	$	(1)	$	―
Commodity contracts subject to rate recovery			―		1		―		―		1
Total		$	1	$	1	$	―	$	(1)	$	1

		Fair value at December 31, 2015
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Commodity contracts subject to rate recovery		$	―	$	1	$	―	$	1	$	2
Total		$	―	$	1	$	―	$	1	$	2

Liabilities:
Commodity contracts not subject to rate recovery		$	1	$	―	$	―	$	(1)	$	―
Commodity contracts subject to rate recovery			―		1		―		―		1
Total		$	1	$	1	$	―	$	(1)	$	1
(1)	Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.

Recurring Fair Value Measures Level 3 Rollforward Table

LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Three months ended March 31,
	2016		2015
Balance as of January 1	$	19	$	107
Realized and unrealized (losses) gains		(1)		6
Settlements		(7)		(11)
Balance as of March 31	$	11	$	102
Change in unrealized (losses) gains relating to
instruments still held at March 31	$	(1)	$	1

Fair Value of Financial Instruments Table

FAIR VALUE OF FINANCIAL INSTRUMENTS
(Dollars in millions)
		March 31, 2016
		Carrying		Fair value
		amount		Level 1		Level 2		Level 3		Total
Sempra Energy Consolidated:
Noncurrent due from unconsolidated affiliates(1)		$	173	$	―	$	92	$	72	$	164
Total long-term debt(2)(3)			13,761		―		14,363		652		15,015
Preferred stock of subsidiary			20		―		23		―		23
SDG&E:
Total long-term debt(3)(4)		$	4,285	$	―	$	4,517	$	312	$	4,829
SoCalGas:
Total long-term debt(5)		$	2,513	$	―	$	2,731	$	―	$	2,731
Preferred stock			22		―		25		―		25

		December 31, 2015
		Carrying		Fair value
		amount		Level 1		Level 2		Level 3		Total
Sempra Energy Consolidated:
Noncurrent due from unconsolidated affiliates(1)		$	175	$	―	$	97	$	69	$	166
Total long-term debt(2)(3)			13,761		―		13,985		648		14,633
Preferred stock of subsidiary			20		―		23		―		23
SDG&E:
Total long-term debt(3)(4)		$	4,304	$	―	$	4,355	$	315	$	4,670
SoCalGas:
Total long-term debt(5)		$	2,513	$	―	$	2,621	$	―	$	2,621
Preferred stock			22		―		25		―		25
(1)	Excluding accumulated interest outstanding of $13 million and $11 million at March 31, 2016 and December 31, 2015, respectively.
(2)	Before reductions for unamortized discount (net of premium) and debt issuance costs of $106 million and $107 million at March 31, 2016 and December 31, 2015, respectively, and excluding build-to-suit and capital lease obligations of $386 million and $387 million at March 31, 2016 and December 31, 2015, respectively. We discuss our long-term debt in Note 6 above and in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report.
(3)	Level 3 instruments include $312 million and $315 million at March 31, 2016 and December 31, 2015, respectively, related to Otay Mesa VIE.
(4)	Before reductions for unamortized discount and debt issuance costs of $43 million at March 31, 2016 and December 31, 2015, and excluding capital lease obligations of $243 million and $244 million at March 31, 2016 and December 31, 2015, respectively.
(5)	Before reductions for unamortized discount and debt issuance costs of $24 million at March 31, 2016 and December 31, 2015, and excluding capital lease obligations of $1 million at March 31, 2016 and December 31, 2015.

Fair Value Measurements, Nonrecurring Table

NON-RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
		Estimated				Fair	% of	Inputs used to
		fair				value	fair value	develop	Range of
		value			Valuation technique	hierarchy	measurement	measurement	inputs
Investment in
Rockies Express		$	440	(1)	Market approach	Level 2	100%	Equity sale price	100%
(1)	At measurement date of March 29, 2016. At March 31, 2016, our investment in Rockies Express had a carrying value of $436 million, reflecting subsequent equity method activity to record a distribution.

NUCLEAR PLANT (Tables)

3 Months Ended

Mar. 31, 2016

Public Utilities General Disclosures [Abstract]

Schedule of Nuclear Decommissioning Trusts Investments

NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
					Gross		Gross		Estimated
					unrealized		unrealized		fair
			Cost		gains		losses		value
At March 31, 2016:
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies(1)		$	101	$	4	$	―	$	105
Municipal bonds(2)			146		10		―		156
Other securities(2)			192		6		(8)		190
Total debt securities			439		20		(8)		451
Equity securities			214		413		(4)		623
Cash and cash equivalents			9		―		(1)		8
Total		$	662	$	433	$	(13)	$	1,082
At December 31, 2015:
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies		$	89	$	2	$	―	$	91
Municipal bonds			148		8		―		156
Other securities			194		1		(13)		182
Total debt securities			431		11		(13)		429
Equity securities			214		412		(7)		619
Cash and cash equivalents			15		―		―		15
Total		$	660	$	423	$	(20)	$	1,063
(1)	Maturity dates are 2016-2065.
(2)	Maturity dates are 2016-2115.

Schedule of Sales of Securities By Nuclear Decommissioning Trusts

SALES OF SECURITIES
(Dollars in millions)
		Three months ended March 31,
		2016		2015
Proceeds from sales(1)		$	93	$	94
Gross realized gains			3		2
Gross realized losses			(8)		(4)
(1)	Excludes securities that are held to maturity.

Public Utilities General Disclosures [Abstract]

Tabular disclosure of available-for-sale securities which includes, but is not limited to, changes in the cost basis and fair value, fair value and gross unrealized gain (loss), fair values by type of security, contractual maturity and classification, amortized cost basis, contracts to acquire securities to be accounted for as available-for-sale, debt maturities, transfers to trading, change in net unrealized holding gain (loss) net of tax, continuous unrealized loss position fair value, aggregate losses qualitative disclosures, other than temporary impairment (OTTI) losses or other disclosures related to available for sale securities.

+ References + Details

CALIFORNIA UTILITIES' REGULATORY MATTERS (Tables)

3 Months Ended

Mar. 31, 2016

Schedule Of California Utilities Major Projects

MAJOR PROJECTS – UPDATES

Joint Utilities Projects
Southern Gas System Reliability Project
§	In April 2016, the CPUC issued a proposed decision finding that there is a need for enhanced system reliability for the southern portion of the SoCalGas and SDG&E gas system, but concluding that the utilities have failed to demonstrate that there is a need for their proposed pipeline project. Instead, the proposed decision determines that certain non-physical alternatives will provide enhanced supply reliability, without the need to construct pipeline facilities.
§	At March 31, 2016, SoCalGas has approximately $23 million of development costs invested in the project, classified as Property, Plant and Equipment on Sempra Energy's and SoCalGas' Condensed Consolidated Balance Sheets. Some or all of these assets could become impaired if the project and potential alternative uses for these assets were ultimately rejected by the CPUC. SoCalGas and SDG&E filed comments with the CPUC in April 2016.
Pipeline Safety & Reliability Project
§	SDG&E and SoCalGas filed an amended application with the CPUC in March 2016 providing detailed analysis and testimony supporting the proposed project. The revised request also presents additional information on the costs and benefits of project alternatives, safety evaluation and compliance analysis, and statutory and procedural requirements. SDG&E and SoCalGas seek approval to construct the proposed project, estimated at a cost of $633 million, and authority to recover the associated revenue requirement in rates.

SDG&E Projects
Cleveland National Forest (CNF) Transmission Projects
§	In March 2016, the U.S. Forest Service issued a final decision authorizing issuance of the CNF Master Special Use Permit renewing SDG&E's land rights and authorizing the construction, operation and maintenance of facilities located on national forest lands for the next 50 years, as well as approving the majority of the fire-hardening activities proposed by SDG&E.
§	Proposed decision issued by the CPUC in April 2016, which granted SDG&E a permit to construct. Final CPUC decision expected in the second quarter of 2016.
Sycamore-Peñasquitos Transmission Project
§	March 2016 final environmental impact report (EIR) recommended an alternative that undergrounds more of the project than originally proposed, and is viewed as environmentally superior. The CPUC may consider this alternative.
§	CPUC's recommended alternative has an estimated cost of $250 million to $300 million, compared to the original project cost estimate of $120 million to $150 million, and would also delay the project schedule by approximately 10 months.
§	CPUC decision expected in the second half of 2016.
South Orange County Reliability Enhancement
§	CPUC issued its final EIR for the project in April 2016. The EIR concluded that an alternative project is considered environmentally superior to SDG&E's proposal. The final EIR states that the CPUC is not required to adopt the environmentally superior alternative if there are overriding considerations in favor of another alternative. The CPUC will consider the findings in determining whether to approve SDG&E's proposed project or an alternative to it.
§	Final CPUC decision expected in the second half of 2016.

SEGMENT INFORMATION (Tables)

3 Months Ended

Mar. 31, 2016

Segment [Abstract]

Segment Information Table

SEGMENT INFORMATION
(Dollars in millions)
	Three months ended March 31,
	2016				2015
REVENUES
SDG&E	$	991	38	%	$	966	36	%
SoCalGas		1,033	40			1,048	39
Sempra South American Utilities		400	15			389	15
Sempra Mexico		138	5			163	6
Sempra Renewables		7	―			8	―
Sempra Natural Gas		130	5			197	7
Intersegment revenues(1)		(77)	(3)			(89)	(3)
Total	$	2,622	100	%	$	2,682	100	%
INTEREST EXPENSE
SDG&E	$	48			$	52
SoCalGas		22				19
Sempra South American Utilities		9				5
Sempra Mexico		4				5
Sempra Renewables		―				1
Sempra Natural Gas		12				21
All other		72				63
Intercompany eliminations		(24)				(32)
Total	$	143			$	134
INTEREST INCOME
Sempra South American Utilities	$	5			$	4
Sempra Mexico		2				2
Sempra Renewables		1				―
Sempra Natural Gas		16				19
Intercompany eliminations		(18)				(18)
Total	$	6			$	7
DEPRECIATION AND AMORTIZATION
SDG&E	$	159	49	%	$	145	48	%
SoCalGas		122	37			113	37
Sempra South American Utilities		13	4			13	4
Sempra Mexico		17	5			17	6
Sempra Renewables		1	―			2	1
Sempra Natural Gas		13	4			12	4
All other		3	1			1	―
Total	$	328	100	%	$	303	100	%
INCOME TAX EXPENSE (BENEFIT)
SDG&E	$	72			$	88
SoCalGas		87				95
Sempra South American Utilities		14				16
Sempra Mexico		41				8
Sempra Renewables		(12)				(17)
Sempra Natural Gas		(25)				2
All other		(35)				(29)
Total	$	142			$	163

SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
		Three months ended March 31,
		2016				2015
EQUITY EARNINGS (LOSSES)
Earnings (losses) recorded before tax:
Sempra Renewables		$	7			$	2
Sempra Natural Gas			(29)				17
Total		$	(22)			$	19
Earnings (losses) recorded net of tax:
Sempra South American Utilities		$	2			$	(1)
Sempra Mexico			15				16
Total		$	17			$	15
EARNINGS (LOSSES)
SDG&E		$	129	40	%	$	147	34	%
SoCalGas(2)			195	61			214	49
Sempra South American Utilities			38	12			41	9
Sempra Mexico			17	5			47	11
Sempra Renewables			13	4			13	3
Sempra Natural Gas			(36)	(11)			2	―
All other			(37)	(11)			(27)	(6)
Total		$	319	100	%	$	437	100	%
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E		$	329	34	%	$	355	46	%
SoCalGas			340	35			315	40
Sempra South American Utilities			43	4			31	4
Sempra Mexico			40	4			55	7
Sempra Renewables			181	19			3	1
Sempra Natural Gas			35	4			10	1
All other			3	―			11	1
Total		$	971	100	%	$	780	100	%
		March 31, 2016				December 31, 2015
ASSETS
SDG&E		$	16,625	40	%	$	16,515	40	%
SoCalGas			12,427	30			12,104	29
Sempra South American Utilities			3,434	8			3,235	8
Sempra Mexico			3,843	9			3,783	9
Sempra Renewables			1,454	3			1,441	4
Sempra Natural Gas			5,395	13			5,566	13
All other			741	2			734	2
Intersegment receivables			(2,084)	(5)			(2,228)	(5)
Total		$	41,835	100	%	$	41,150	100	%
EQUITY METHOD AND OTHER INVESTMENTS
Sempra South American Utilities		$	(2)			$	(4)
Sempra Mexico			522				519
Sempra Renewables			823				855
Sempra Natural Gas			1,308				1,460
All other			76				75
Total		$	2,727			$	2,905
(1)	Revenues for reportable segments include intersegment revenues of $3 million, $17 million, $27 million and $30 million for the three months ended March 31, 2016 and $2 million, $19 million, $25 million and $43 million for the three months ended March 31, 2015 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively.
(2)	After preferred dividends.

NEW ACCOUNTING POLICY (details) - USD ($) $ in Millions	3 Months Ended
NEW ACCOUNTING POLICY (details) - USD ($) $ in Millions	Mar. 31, 2016	Mar. 31, 2015
New Accounting Policies
Tax benefit related to share-based compensation	$ 34	$ 52
Cumulative Effect On Retained Earnings Tax1	$ 107

RECENT BUSINESS ACQUISITIONS (Details) - USD ($) $ in Millions	3 Months Ended
	Sep. 30, 2015	Mar. 31, 2015	Jul. 31, 2015
Black Oak Getty Wind [Member]
Business Acquisition [Line Items]
Cash consideration (fair value of total consideration)		$ 8
Equity Method Investment Ownership Percentage		100.00%
PEMEX [Member]
Business Acquisition [Line Items]
Ownership Percentage in consolidated entity	50.00%
IEnova [Member]
Business Acquisition [Line Items]
Ownership percentage before acquisition			50.00%
Acquired percentage interest in joint venture			100.00%
Net Debt Not Assumed By Investee	$ 170
Business Acquisition Purchase Price Allocation Equity Method Investment	$ 1,325
Ownership Percentage in consolidated entity	25.00%
Equity Method Investment Ownership Percentage			50.00%

ASSETS HELD FOR SALE (Details) - Termoelectrica de Mexicali [Member] $ in Millions	3 Months Ended
	Mar. 31, 2016 USD ($)
Assets Held for Sale, Assets [Abstract]
Assets Held for Sale, Cash and Cash Equivalent	$ 1
Assets Held for Sale, Inventories	8
Assets Held for Sale, Other Current Assets	29
Assets Held for Sale, Other Assets	15
Assets Held for Sale, Property, Plant and Equipment, Net	250
Total Assets Held for Sale	303
Assets Held for Sale, Liabilities [Abstract]
Assets Held for Sale, Accounts Payable	1
Assets Held for Sale, Other Current Liabilities	7
Assets Held for Sale, Deferred Income Taxes	16
Assets Held for Sale, Asset Retirement Obligations	4
Assets Held for Sale, Other Liabilities	15
Total Liabilities Held for Sale	43
Disposal Group Including Discontinued Operation Additional Disclosures [Abstract]
Deferred Tax Expense From The Outside Basis Difference	29
Deferred Tax Expense From The Outside Basis Difference After NoncontrollingInterest	$ 24

DIVESTITURES (Details) - USD ($) $ in Millions	3 Months Ended
DIVESTITURES (Details) - USD ($) $ in Millions	Mar. 31, 2016	Mar. 29, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity Method Investments	$ 2,727		$ 2,905
Rockies Express [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment Ownership Percentage		25.00%
Equity Method Investment, Other than Temporary Impairment	44
Equity Method Investment Other Than Temporary Impairment Net Of Tax Benefit	27
Equity Method Investments	436	$ 484
Proceeds From Sale Of Equity Method Investments	$ 440

INVESTMENTS IN UNCONSOLIDATED ENTITIES (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity Method Investments in Joint Ventures, capitalized interest	$ 18	$ 17
Guarantee Obligations Maximum Exposure	4,500
Guarantee Obligations Current Carrying Value	67
Sempra Renewables [Member]
Schedule of Equity Method Investments [Line Items]
Payments To Acquire Equity Method Investments	15	17
Cameron LNG [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investments in Joint Ventures, capitalized interest	12	$ 12
Payments To Acquire Equity Method Investments	$ 3

OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITIES (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Variable Interest Entities [Line Items]
Cost Of Electric Fuel And Purchased Power From Utilities	$ 515	$ 481
Other operation and maintenance	701	658
Depreciation and amortization	328	303
Other income (expense), net	49	39
Interest expense	(143)	(134)
Net income	330	458
Earnings attributable to noncontrolling interest	(11)	(21)
Earnings attributable to common shares	319	437
Schedule of Equity Method Investments [Line Items]
Equity Method Investments	2,727		$ 2,905
Otay Mesa VIE [Member]
Variable Interest Entities [Line Items]
Cost Of Electric Fuel And Purchased Power From Utilities	(17)	(18)
Other operation and maintenance	4	4
Depreciation and amortization	7	6
Operating Expenses	(6)	(8)
Utility operating income	6	8
Interest expense	(5)	(4)
Net income	1	4
Earnings attributable to noncontrolling interest	(1)	(4)
Earnings attributable to common shares	0	$ 0
Equity of variable interest entity	51		53
Secured debt of variable interest entity	312
Cameron LNG Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investments	$ 872		$ 983

OTHER FINANCIAL DATA - GOODWILL (Details) - USD ($)
$ in Millions

Mar. 31, 2016

Dec. 31, 2015

Goodwill And Intangible Assets Disclosure [Abstract]

Goodwill

$ 849

$ 819

^[1]

[1]	Derived from audited financial statements.

OTHER FINANCIAL DATA - PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 28	$ 30
Interest cost	40	39
Expected return on assets	(42)	(44)
Amortization of prior service cost	3	3
Amortization of actuarial loss	6	8
Regulatory adjustment	(28)	(29)
Total net periodic benefit cost	7	7
Defined benefit plan, contributions by employer	15
Defined benefit plan, expected contributions in current fiscal year	123
Pension Benefits \| San Diego Gas and Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	7	8
Interest cost	10	10
Expected return on assets	(12)	(14)
Amortization of prior service cost	0	0
Amortization of actuarial loss	3	2
Regulatory adjustment	(7)	(5)
Total net periodic benefit cost	1	1
Defined benefit plan, contributions by employer	2
Defined benefit plan, expected contributions in current fiscal year	4
Pension Benefits \| Southern California Gas Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	17	19
Interest cost	25	25
Expected return on assets	(25)	(27)
Amortization of prior service cost	2	2
Amortization of actuarial loss	3	5
Regulatory adjustment	(21)	(24)
Total net periodic benefit cost	1	0
Defined benefit plan, contributions by employer	0
Defined benefit plan, expected contributions in current fiscal year	77
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	5	7
Interest cost	11	12
Expected return on assets	(17)	(17)
Amortization of prior service cost	0	(1)
Amortization of actuarial loss	0	0
Regulatory adjustment	2	0
Total net periodic benefit cost	1	1
Defined benefit plan, contributions by employer	1
Defined benefit plan, expected contributions in current fiscal year	6
Other Postretirement Benefits \| San Diego Gas and Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	1	2
Interest cost	2	2
Expected return on assets	(3)	(3)
Amortization of prior service cost	1	1
Amortization of actuarial loss	0	0
Regulatory adjustment	(1)	(2)
Total net periodic benefit cost	0	0
Defined benefit plan, contributions by employer	0
Defined benefit plan, expected contributions in current fiscal year	2
Other Postretirement Benefits \| Southern California Gas Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	4	5
Interest cost	8	9
Expected return on assets	(14)	(14)
Amortization of prior service cost	(1)	(2)
Amortization of actuarial loss	0	0
Regulatory adjustment	3	2
Total net periodic benefit cost	0	$ 0
Defined benefit plan, contributions by employer	0
Defined benefit plan, expected contributions in current fiscal year	$ 1

OTHER FINANCIAL DATA - RABBI TRUST (Details) - USD ($)
$ in Millions

Mar. 31, 2016

Dec. 31, 2015

Assets Noncurrent [Abstract]

Rabbi Trust

$ 432

$ 464

^[1]

[1]	Derived from audited financial statements.

OTHER FINANCIAL DATA - EARNINGS PER SHARE (Details) - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

Mar. 31, 2016

Mar. 31, 2015

Earnings Per Share [Abstract]

Basic earnings per common share

$ 1.28

$ 1.76

Weighted-average common shares outstanding for basic EPS

^[1]

249,734,000

247,722,000

Diluted earnings per common share

$ 1.27

$ 1.74

Weighted-average common shares outstanding for diluted EPS

251,412,000

251,206,000

Vested RSUs included in basic WASO

555,000

452,000

Dilutive effect of stock options, restricted stock awards and restricted stock units

1,678,000

3,484,000

Shares excluded from potential dilutive shares

2,616,084

1,285,193

Earnings

$ 319

$ 437

Out Of The Money Stock Options [Member]

Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items]

Antidilutive securities excluded from computation of earnings per share

Employee Stock Option [Member]

Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items]

Antidilutive securities excluded from computation of earnings per share

Restricted Stock [Member]

Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items]

Antidilutive securities excluded from computation of earnings per share

Restricted Stock Units [Member]

Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items]

Antidilutive securities excluded from computation of earnings per share

614

[1]

OTHER FINANCIAL DATA - EARNINGS PER SHARE - SHARE BASED COMPENSATION (Details)	3 Months Ended
	Mar. 31, 2016
Performance RSU minimum [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Sharebased Compensation Arrangement By Sharebased Payment Award Award Vesting Rights Percentage	0.00%
Performance RSU max prior to 2014 [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Sharebased Compensation Arrangement By Sharebased Payment Award Award Vesting Rights Percentage	150.00%
Performance RSU max in 2014 and after [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Sharebased Compensation Arrangement By Sharebased Payment Award Award Vesting Rights Percentage	200.00%
Service and Other Awards max [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Sharebased Compensation Arrangement By Sharebased Payment Award Award Vesting Rights Percentage	100.00%

OTHER FINANCIAL DATA - SHARE-BASED COMPENSATION (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Allocated Share Based Compensation Expense Net Of Tax	$ 7	$ 8
IENova Plans [Member] [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Restricted stock units granted	183,970
Service-Based [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Restricted stock units granted	93,256
Performance-Based, Total Shareholder Return [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Restricted stock units granted	372,270
Performance-Based, Earnings Per Share [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Restricted stock units granted	94,550

OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Capitalized Financing Costs Disclosure [Line Items]
AFUDC related to debt	$ 7	$ 6
AFUDC related to equity	27	27
Other capitalized financing costs	18	17
Total capitalized financing costs	52	50
San Diego Gas and Electric Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
AFUDC related to debt	4	3
AFUDC related to equity	11	8
Total capitalized financing costs	15	11
Southern California Gas Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
AFUDC related to debt	3	3
AFUDC related to equity	10	9
Total capitalized financing costs	$ 13	$ 12

OTHER FINANCIAL DATA - SHAREHOLDER'S EQUITY AND NONCONTROLLING INTEREST (Details) - USD ($)
$ in Millions

3 Months Ended

Mar. 31, 2016

Mar. 31, 2015

$ 12,579

^[1]

$ 12,100

Share-based compensation expense

315

329

Common stock dividends declared

(188)

(173)

Issuance of common stock

(54)

(65)

(3)

(5)

12,724

12,281

5,276

^[1]

4,992

128

149

(1)

(3)

5,403

5,138

^[1]

3,149

Total Shareholders' Equity [Member]

3,344

11,809

11,326

Share-based compensation expense

304

321

Common stock dividends declared

(188)

(173)

Issuance of common stock

(54)

(65)

Total Shareholders' Equity [Member] | San Diego Gas and Electric Company [Member]

11,946

11,504

5,223

4,932

129

147

Noncontrolling Interests [Member]

5,352

5,079

^[2]

770

774

Share-based compensation expense

^[2]

^[2]

Common stock dividends declared

^[2]

Issuance of common stock

^[2]

^[2]

^[2]

(3)

(5)

Noncontrolling Interests [Member] | San Diego Gas and Electric Company [Member]

^[2]

778

777

(1)

(1)

(3)

Accumulated Other Comprehensive Income Loss [Line Items]

$ 51

$ 59

[1]	Derived from audited financial statements.
[2]	Noncontrolling interests include the preferred stock of SoCalGas and other noncontrolling interests as listed in the table below under "Other Noncontrolling Interests."

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

3 Months Ended

Mar. 31, 2016

Mar. 31, 2015

Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance

^[1]

$ (806)

^[2]

$ (497)

Other Comprehensive Income Loss Before Reclassifications Net Of Tax

^[1]

(14)

(116)

Amounts Reclassified From Accumulated Other Comprehensive Income

^[1]

(1)

Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance

^[1]

(15)

(116)

^[1]

(821)

(613)

Accumulated Other Comprehensive Income Loss [Line Items]

Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance

^[2]

(8)

Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance

(8)

Accumulated Other Comprehensive Income Loss [Line Items]

Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance

^[2]

(19)

Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance

(19)

Accumulated Translation Adjustment [Member]

Accumulated Other Comprehensive Income Loss [Line Items]

Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance

^[1]

(582)

(322)

Other Comprehensive Income Loss Before Reclassifications Net Of Tax

^[1]

(62)

Amounts Reclassified From Accumulated Other Comprehensive Income

^[1]

Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance

^[1]

(62)

^[1]

(514)

(384)

Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member]

Accumulated Other Comprehensive Income Loss [Line Items]

Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance

^[1]

(137)

(90)

Other Comprehensive Income Loss Before Reclassifications Net Of Tax

^[1]

(82)

(54)

Amounts Reclassified From Accumulated Other Comprehensive Income

^[1]

(2)

(1)

Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance

^[1]

(84)

(55)

^[1]

(221)

(145)

Accumulated Defined Benefit Plans Adjustment [Member]

Accumulated Other Comprehensive Income Loss [Line Items]

Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance

^[1]

(87)

(85)

Other Comprehensive Income Loss Before Reclassifications Net Of Tax

^[1]

Amounts Reclassified From Accumulated Other Comprehensive Income

^[1]

Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance

^[1]

^[1]

$ (86)

$ (84)

[1]	All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests.
[2]	Derived from audited financial statements.

OTHER FINANCIAL DATA - RECLASSIFICATION FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($)
$ in Millions

3 Months Ended

Mar. 31, 2016

Mar. 31, 2015

Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]

Equity earnings, net of income tax.

$ 17

$ 15

(143)

(134)

Revenues - energy related businesses

(22)

180

260

455

606

(142)

(163)

Grand total reclassifications for the period, net of tax

(11)

(21)

(1)

Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]

(48)

(52)

202

239

(72)

(88)

(1)

(4)

Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]

(22)

(19)

282

309

Accumulated Defined Benefit Plans Adjustment [Member]

(87)

(95)

Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]

Total reclassifications for the period, net of tax

(1)

Accumulated Defined Benefit Plans Adjustment [Member] | Amortization of Actuarial Loss [Member]

Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]

Pension and other postretirement benefit expense

^[1]

Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member]

Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]

Net of Income Tax

Total reclassifications for the period, net of tax

(3)

(4)

(2)

(1)

Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | San Diego Gas and Electric Company [Member]

Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]

Total reclassifications for the period, net of tax

(3)

Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | Interest Rate And Foreign Exchange Instruments [Member]

Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]

Equity earnings, net of income tax.

Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | Interest Rate Instruments [Member]

Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]

Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | Interest Rate Instruments [Member] | San Diego Gas and Electric Company [Member]

Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]

Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | Commodity Contracts Not Subject To Rate Recovery [Member]

Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]

Revenues - energy related businesses

$ (7)

[1]	Amounts are included in the computation of net periodic benefit cost (see "Pension and Other Postretirement Benefits" above).

OTHER FINANCIAL DATA - OTHER NONCONTROLLING INTERESTS (Details) - USD ($)
$ in Millions

Mar. 31, 2016

Dec. 31, 2015

Ownership Interests Held By Others, Bay Gas Storage Company [Member]

Noncontrolling interests

$ 758

$ 750

^[1]

Minority Interest Ownership Percentage By Noncontrolling Owners

9.10%

Ownership Interests Held By Others, Southern Gas Transmission [Member]

$ 25

Minority Interest Ownership Percentage By Noncontrolling Owners

49.00%

Ownership Interests Held By Others, Liberty Gas Storage [Member]

$ 1

Minority Interest Ownership Percentage By Noncontrolling Owners

23.20%

Ownership Interests Held By Others, Tecsur [Member]

$ 14

Minority Interest Ownership Percentage By Noncontrolling Owners

9.80%

Ownership Interests Held By Others, Luz Del Sur [Member]

$ 4

Minority Interest Ownership Percentage By Noncontrolling Owners

16.40%

Ownership Interests Held By Others, Chilquinta Energia [Member]

$ 171

$ 164

Percent Of Ownership Held By Others Minimum

^[2]

23.50%

Percent Of Ownership Held By Others Maximum

^[2]

43.40%

Ownership Interests Held By Others, Otay Mesa VIE [Member]

^[2]

$ 22

$ 21

Minority Interest Ownership Percentage By Noncontrolling Owners

100.00%

Ownership Interests Held By Others IEnova [Member]

$ 51

$ 53

Minority Interest Ownership Percentage By Noncontrolling Owners

18.90%

Transactions With Affiliates Disclosure [Line Items]

$ 470

$ 468

[1]	Derived from audited financial statements.
[2]	Chilquinta Energía has four subsidiaries with noncontrolling interests held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.

OTHER FINANCIAL DATA - DUE TO DUE FROM AFFILIATES (Details) - USD ($)
$ in Millions

3 Months Ended

12 Months Ended

Mar. 31, 2016

Dec. 31, 2015

$ 7

$ 6

^[1]

(13)

(14)

^[1]

186

^[1]

Transactions With Affiliates Disclosure [Line Items]

^[1]

(49)

(55)

^[1]

Transactions With Affiliates Disclosure [Line Items]

^[1]

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

(34)

^[1]

Transactions With Affiliates Disclosure [Line Items]

Income taxes due to Sempra Energy

(35)

(34)

^[2]

(32)

Income taxes due from Sempra Energy

^[2]

Due to/from Sempra Energy | Southern California Gas Company [Member]

Transactions With Affiliates Disclosure [Line Items]

^[3]

Income taxes due to Sempra Energy

(34)

^[2]

(23)

Income taxes due from Sempra Energy

^[2]

$ 1

Loan to unconsolidated affiliate, principal

0.11%

$ 50

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

Transactions With Affiliates Disclosure [Line Items]

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

Transactions With Affiliates Disclosure [Line Items]

Joint venture with PEMEX [Member]

$ (8)

(13)

Transactions With Affiliates Disclosure [Line Items]

PEMEX Four year loan C [Member]

4.94%

Transactions With Affiliates Disclosure [Line Items]

PEMEX Three year loan A [Member]

^[4],[5]

$ 8

Transactions With Affiliates Disclosure [Line Items]

PEMEX Four year loan B [Member]

^[4],[5]

Transactions With Affiliates Disclosure [Line Items]

PEMEX Four year loan A [Member]

^[4],[5]

Transactions With Affiliates Disclosure [Line Items]

ESJ joint venture [Member]

^[4],[5]

Transactions With Affiliates Disclosure [Line Items]

^[4],[6]

$ 17

Transactions With Affiliates Disclosure [Line Items]

6.81%

Eletrans [Member]

^[4],[7]

$ 76

Sempra South American Utilities [Member]

4.00%

Transactions With Affiliates Disclosure [Line Items]

$ 1

Transactions With Affiliates Disclosure [Line Items]

Affiliate Of Investee [Member] | San Diego Gas and Electric Company [Member]

Transactions With Affiliates Disclosure [Line Items]

Component of Other Income, Nonoperating [Line Items]

$ (6)

$ (8)

[1]	Derived from audited financial statements.
[2]	SDG&E and SoCalGas are included in the consolidated income tax return of Sempra Energy and are allocated income tax expense from Sempra Energy in an amount equal to that which would result from each company having always filed a separate return.
[3]	At December 31, 2015, net receivable included outstanding advances to Sempra Energy of $50 million at an interest rate of 0.11 percent.
[4]	Amounts include principal balances plus accumulated interest outstanding.
[5]	U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 450 basis points (4.94 percent at March 31, 2016), to finance the Los Ramones Norte pipeline project.
[6]	U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 637.5 basis points (6.81 percent at March 31, 2016), to finance the first phase of the Energía Sierra Juárez wind project.
[7]	U.S. dollar-denominated loan, at a fixed interest rate with no stated maturity date, to provide project financing for the construction of transmission lines at Eletrans S.A. and Eletrans II S.A., both of which are joint ventures at Chilquinta Energía.

OTHER FINANCIAL DATA - AFFILIATES REVENUE AND COST OF SALES (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Transactions With Affiliates Disclosure [Line Items]
Revenue from related parties	$ 5	$ 8
Costs and Expenses Related Party	30	19
S D G E Segment [Member]
Transactions With Affiliates Disclosure [Line Items]
Revenue from related parties	3	3
Costs and Expenses Related Party	14	5
So Cal Gas Segment [Member]
Transactions With Affiliates Disclosure [Line Items]
Revenue from related parties	$ 17	$ 19

OTHER FINANCIAL DATA - OTHER INCOME (Details) - USD ($)
$ in Millions

3 Months Ended

Mar. 31, 2016

Mar. 31, 2015

AFUDC related to equity

$ 27

Investment gains (losses)

^[1]

Electrical infrastructure relocation income

^[2]

Gains (losses) on interest rate and foreign exchange instruments, net

Sale of other investments

Foreign currency gain (losses)

(2)

(1)

Regulatory Interest, net

^[3]

Sundry, net

Component of Other Income, Nonoperating [Line Items]

AFUDC related to equity

Regulatory Interest, net

^[3]

Sundry, net

Component of Other Income, Nonoperating [Line Items]

AFUDC related to equity

Sundry, net

(1)

$ 10

$ 8

[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]	Income at Luz del Sur associated with the relocation of electrical infrastructure.
[3]	Interest on regulatory balancing accounts.

OTHER FINANCIAL DATA - INCOME TAXES (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ 142	$ 163
Effective income tax rate	31.00%	27.00%
San Diego Gas and Electric Company [Member]
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ 72	$ 88
Effective income tax rate	36.00%	37.00%
Southern California Gas Company [Member]
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ 87	$ 95
Effective income tax rate	31.00%	31.00%

OTHER FINANCIAL DATA - INVENTORY (Details) - USD ($)
$ in Millions

Mar. 31, 2016

Dec. 31, 2015

$ 77

$ 149

145

143

231

298

^[1]

S D G E Segment [Member]

So Cal Gas Segment [Member]

^[2]

Sempra South American Utilities Segment [Member]

^[2]

Sempra Mexico Segment [Member]

Sempra Renewables Segment [Member]

$ 3

[1]	Derived from audited financial statements.
[2]	At both March 31, 2016 and December 31, 2015, SoCalGas' natural gas inventory for core customers is net of the estimated inventory loss related to the Aliso Canyon natural gas leak, which we discuss in Note 11.

DEBT AND CREDIT FACILITIES - LINES OF CREDIT (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Line Of Credit Facility, Sempra Energy Consolidated [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 4,200
Committed lines of credit, remaining borrowing capacity	$ 3,100
Weighted average interest rate on total short-term debt outstanding	1.12%	1.09%
Line Of Credit Facility, Sempra Energy [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 1,000
Committed lines of credit, maximum ratio of indebtedness to total capitalization	65.00%
Committed lines of credit, capacity for issuance of letters of credit	$ 400
Committed lines of credit, outstanding borrowings	0
Line Of Credit Facility, Sempra Global [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 2,210
Committed lines of credit, maximum ratio of indebtedness to total capitalization	65.00%
Committed lines of credit, remaining borrowing capacity	$ 1,330
Outstanding commercial paper supported by committed lines of credit	879
Line Of Credit Facility, S D G E [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 750
Committed lines of credit, maximum ratio of indebtedness to total capitalization	65.00%
Committed lines of credit, remaining borrowing capacity	$ 584
Outstanding commercial paper supported by committed lines of credit	$ 166
Weighted average interest rate on total short-term debt outstanding	1.02%	1.01%
Line Of Credit Facility, So Cal Gas [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 750
Committed lines of credit, maximum ratio of indebtedness to total capitalization	65.00%
Committed lines of credit, remaining borrowing capacity	$ 745
Outstanding commercial paper supported by committed lines of credit	$ 5
Weighted average interest rate on total short-term debt outstanding	0.40%
Line Of Credit Facility, California Utilities Combined [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 1,000
Committed lines of credit, capacity for issuance of letters of credit	250
Line Of Credit Facility, South American Utilities And Mexico [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	1,100
Committed lines of credit, remaining borrowing capacity	876
Line Of Credit Facility Sempra Mexico [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	600
Committed lines of credit, remaining borrowing capacity	509
Committed lines of credit, outstanding borrowings	91
Line Of Credit Facility, Peruvian Facility [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, remaining borrowing capacity	255
Committed lines of credit, outstanding borrowings	165
Bank Guarantee	15
Line Of Credit Facility, Chilean Facility [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, remaining borrowing capacity	112
Committed lines of credit, outstanding borrowings	0
Line Of Credit Facility Sempra South America [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 547
Committed lines of credit, maximum ratio of debt to equity	170.00%

DEBT AND CREDIT FACILITIES - LONG TERM DEBT (Details) - Other Long Term Debt, Variable Rate Due 2027 [Member] - San Diego Gas and Electric Company [Member] $ in Millions	Mar. 31, 2016 USD ($)
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.00%
Planned Early Redemption Of Long Term Debt Instruments	$ 105

DERIVATIVE COMMODITY VOLUMES (Details)

Mar. 31, 2016

Dec. 31, 2015

S D G E Segment [Member]

Commodity Derivative Volumes Natural Gas

^[1]

Commodity Derivative Volumes Congestion Revenue Rights

^[2]

Commodity Derivative Volumes Electric Power

^[2]

So Cal Gas Segment [Member]

Commodity Derivative Volumes Natural Gas

^[1]

Commodity Derivative Volumes Natural Gas

^[1]

[1]	Million British thermal units
[2]	Megawatt hours

DERIVATIVE NOTIONALS (Details) - USD ($)
$ in Millions

3 Months Ended

12 Months Ended

Mar. 31, 2016

Dec. 31, 2015

Cash Flow Hedges

Cash Flow Hedges | Cross Currency Interest Rate Contract [Member]

^[1]

$ 381

$ 384

Cash Flow Hedges | Minimum [Member]

$ 408

Cash Flow Hedges | Minimum [Member] | Cross Currency Interest Rate Contract [Member]

2016

Cash Flow Hedges | Maximum [Member]

2018

Cash Flow Hedges | Maximum [Member] | Cross Currency Interest Rate Contract [Member]

2028

2023

Fair Value Hedges

Fair Value Hedges | Maximum [Member]

$ 300

Undesignated Derivatives | Foreign Exchange Instrument

2016

Undesignated Derivatives | Maximum [Member] | Foreign Exchange Instrument

$ 550

$ 0

San Diego Gas and Electric Company [Member] | Cash Flow Hedges

2016

San Diego Gas and Electric Company [Member] | Cash Flow Hedges | Minimum [Member]

^[1]

$ 312

$ 315

San Diego Gas and Electric Company [Member] | Cash Flow Hedges | Maximum [Member]

2016

Other Current Assets [Member]

2019

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

DERIVATIVE INSTRUMENTS ON THE CONDENSED BALANCE SHEET (Details) - USD ($)
$ in Millions

Mar. 31, 2016

Dec. 31, 2015

Derivative Instruments in Hedges, at Fair Value, Net [Abstract]

^[1],[2]

$ 5

$ 4

Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]

^[1]

^[1]

Associated offsetting commodity contracts not subject to rate recovery

^[1]

144

245

^[1]

(135)

(232)

Associated cash collateral commodity contracts not subject to rate recovery

^[1]

(6)

Associated cash collateral commodity contracts subject to rate recovery

^[1]

^[1]

Associated offsetting commodity contracts subject to rate recovery

^[1]

(4)

(2)

Additional margin posted for commodity contracts not subject to rate recovery

^[1]

^[1]

Additional margin posted for commodity contracts subject to rate recovery

^[1]

Other Current Assets [Member] | San Diego Gas and Electric Company [Member]

^[1],[3]

Derivative Instruments in Hedges, at Fair Value, Net [Abstract]

Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]

^[1],[2]

Associated cash collateral commodity contracts not subject to rate recovery

^[1]

^[1]

Associated cash collateral commodity contracts subject to rate recovery

^[1]

^[1]

Associated offsetting commodity contracts subject to rate recovery

^[1]

(2)

Additional margin posted for commodity contracts not subject to rate recovery

^[1]

^[1]

Additional margin posted for commodity contracts subject to rate recovery

^[1]

Other Current Assets [Member] | Southern California Gas Company [Member]

^[1],[3]

Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]

Associated cash collateral commodity contracts not subject to rate recovery

^[1]

^[1]

Associated offsetting commodity contracts subject to rate recovery

^[1]

^[1]

(2)

Additional margin posted for commodity contracts not subject to rate recovery

^[1]

^[1]

Additional margin posted for commodity contracts subject to rate recovery

^[1]

Other Noncurrent Assets [Member]

^[1]

Derivative Instruments in Hedges, at Fair Value, Net [Abstract]

^[2]

Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]

Associated offsetting commodity contracts not subject to rate recovery

(9)

(20)

Associated cash collateral commodity contracts not subject to rate recovery

Associated cash collateral commodity contracts subject to rate recovery

Associated offsetting commodity contracts subject to rate recovery

(1)

(2)

Additional margin posted for commodity contracts not subject to rate recovery

Additional margin posted for commodity contracts subject to rate recovery

Other Noncurrent Assets [Member] | San Diego Gas and Electric Company [Member]

^[3]

Derivative Instruments in Hedges, at Fair Value, Net [Abstract]

Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]

^[2]

Associated cash collateral commodity contracts not subject to rate recovery

Associated cash collateral commodity contracts subject to rate recovery

Associated offsetting commodity contracts subject to rate recovery

(1)

(2)

Additional margin posted for commodity contracts not subject to rate recovery

Additional margin posted for commodity contracts subject to rate recovery

Other Noncurrent Assets [Member] | Southern California Gas Company [Member]

^[3]

Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]

Associated cash collateral commodity contracts not subject to rate recovery

Associated offsetting commodity contracts subject to rate recovery

Additional margin posted for commodity contracts not subject to rate recovery

Additional margin posted for commodity contracts subject to rate recovery

Other Current Liabilities [Member]

Derivative Instruments in Hedges, at Fair Value, Net [Abstract]

^[2],[4]

(15)

Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]

^[4]

^[4]

Associated offsetting commodity contracts not subject to rate recovery

^[4]

(144)

(239)

^[4]

135

232

Associated cash collateral commodity contracts not subject to rate recovery

^[4]

Associated cash collateral commodity contracts subject to rate recovery

^[4]

(68)

(61)

^[4]

Associated offsetting commodity contracts subject to rate recovery

^[4]

Additional margin posted for commodity contracts not subject to rate recovery

^[4]

(50)

(49)

^[4]

Additional margin posted for commodity contracts subject to rate recovery

^[4]

Other Current Liabilities [Member] | San Diego Gas and Electric Company [Member]

^[3],[4]

(50)

(49)

Derivative Instruments in Hedges, at Fair Value, Net [Abstract]

Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]

^[2],[4]

(14)

Associated cash collateral commodity contracts not subject to rate recovery

^[4]

(1)

^[4]

Associated cash collateral commodity contracts subject to rate recovery

^[4]

(65)

(60)

^[4]

Associated offsetting commodity contracts subject to rate recovery

^[4]

Additional margin posted for commodity contracts not subject to rate recovery

^[4]

(46)

(44)

^[4]

Additional margin posted for commodity contracts subject to rate recovery

^[4]

Other Current Liabilities [Member] | Southern California Gas Company [Member]

^[3],[4]

(46)

(44)

Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]

Associated cash collateral commodity contracts not subject to rate recovery

^[4]

(1)

^[4]

Associated offsetting commodity contracts subject to rate recovery

^[4]

(3)

(1)

^[4]

Additional margin posted for commodity contracts not subject to rate recovery

^[4]

(1)

^[4]

Additional margin posted for commodity contracts subject to rate recovery

^[4]

Other Noncurrent Liabilities [Member]

^[4]

(1)

Derivative Instruments in Hedges, at Fair Value, Net [Abstract]

^[2]

(166)

(156)

Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]

Associated offsetting commodity contracts not subject to rate recovery

(9)

(21)

Associated cash collateral commodity contracts not subject to rate recovery

Associated cash collateral commodity contracts subject to rate recovery

(61)

(64)

Associated offsetting commodity contracts subject to rate recovery

Additional margin posted for commodity contracts not subject to rate recovery

(202)

(193)

Additional margin posted for commodity contracts subject to rate recovery

Other Noncurrent Liabilities [Member] | San Diego Gas and Electric Company [Member]

^[3]

(202)

(193)

Derivative Instruments in Hedges, at Fair Value, Net [Abstract]

Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]

^[2]

(25)

(23)

Associated cash collateral commodity contracts not subject to rate recovery

Associated cash collateral commodity contracts subject to rate recovery

(61)

(64)

Associated offsetting commodity contracts subject to rate recovery

Additional margin posted for commodity contracts not subject to rate recovery

(61)

(59)

Additional margin posted for commodity contracts subject to rate recovery

Other Noncurrent Liabilities [Member] | Southern California Gas Company [Member]

^[3]

(61)

(59)

Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]

Associated cash collateral commodity contracts not subject to rate recovery

Associated offsetting commodity contracts subject to rate recovery

Additional margin posted for commodity contracts not subject to rate recovery

Additional margin posted for commodity contracts subject to rate recovery

Derivative Instruments, Gain (Loss) [Line Items]

$ 0

[1]	Included in Current Assets: Other for SoCalGas.
[2]	Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE.
[3]	Normal purchase contracts previously measured at fair value are excluded.
[4]	Included in Current Liabilities: Other for SoCalGas.

DERIVATIVE IMPACT ON THE INCOME STATEMENT (Details) - USD ($)
$ in Millions

3 Months Ended

Mar. 31, 2016

Mar. 31, 2015

$ (4)

$ (11)

Derivative Instruments, Gain (Loss) [Line Items]

Derivative Instruments, Gain (Loss) [Line Items]

Cash Flow Hedges

Gain (loss) reclassified from AOCI into earnings (effective portion)

^[1]

(1)

(2)

Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)

^[1]

(165)

(97)

Cash Flow Hedge Ineffectiveness

Cash Flow Hedges | Interest Expense | Interest Rate Instruments | San Diego Gas and Electric Company [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Gain (loss) reclassified from AOCI into earnings (effective portion)

^[1]

(3)

^[2]

Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)

^[1],[2]

(5)

Cash Flow Hedges | Interest Expense | Interest Rate And Foreign Exchange Instruments [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Gain (loss) reclassified from AOCI into earnings (effective portion)

^[2]

(4)

(6)

Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)

^[2]

(11)

(18)

Cash Flow Hedges | Equity Earnings Before Income Tax [Member] | Interest Rate Instruments

Derivative Instruments, Gain (Loss) [Line Items]

Gain (loss) reclassified from AOCI into earnings (effective portion)

(3)

Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)

(137)

(78)

Cash Flow Hedges | Equity Earnings Net Of Income Tax [Member] | Interest Rate And Foreign Exchange Instruments [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Gain (loss) reclassified from AOCI into earnings (effective portion)

(1)

Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)

(18)

Cash Flow Hedges | Revenues: Energy-Related Business [Member] | Commodity Contracts Not Subject To Rate Recovery

Derivative Instruments, Gain (Loss) [Line Items]

Gain (loss) reclassified from AOCI into earnings (effective portion)

Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)

(1)

Fair Value Hedges | Interest Rate Instruments

Derivative Instruments, Gain (Loss) [Line Items]

Fair Value Hedges | Interest Expense | Interest Rate Instruments

^[3]

Derivative Instruments, Gain (Loss) [Line Items]

Fair Value Hedge Ineffectiveness

Fair Value Hedges | Other Income, Net | Interest Rate Instruments

Derivative Instruments, Gain (Loss) [Line Items]

Derivative Instruments, Gain (Loss) [Line Items]

Undesignated Derivatives

Undesignated Derivatives | Other Income, Net | Foreign Exchange Instrument

(9)

(17)

Derivative Instruments, Gain (Loss) [Line Items]

Undesignated Derivatives | Equity Earnings Net Of Income Tax [Member] | Foreign Exchange Instrument

Derivative Instruments, Gain (Loss) [Line Items]

Undesignated Derivatives | Revenues: Energy-Related Business [Member] | Commodity Contracts Not Subject To Rate Recovery

(1)

Derivative Instruments, Gain (Loss) [Line Items]

Undesignated Derivatives | Cost of Electric Fuel and Purchased Power [Member] | Commodity Contracts Subject To Rate Recovery [Member]

(1)

Derivative Instruments, Gain (Loss) [Line Items]

Undesignated Derivatives | Cost of Electric Fuel and Purchased Power [Member] | Commodity Contracts Subject To Rate Recovery [Member] | San Diego Gas and Electric Company [Member]

(12)

(20)

Derivative Instruments, Gain (Loss) [Line Items]

Undesignated Derivatives | Cost of Natural Gas [Member] | Commodity Contracts Subject To Rate Recovery [Member]

(12)

(20)

Derivative Instruments, Gain (Loss) [Line Items]

Undesignated Derivatives | Cost of Natural Gas [Member] | Commodity Contracts Subject To Rate Recovery [Member] | Southern California Gas Company [Member]

(1)

Derivative Instruments, Gain (Loss) [Line Items]

Nuclear Decommisioning Trusts [Member]

$ (1)

$ 1

[1]	Amounts include negligible hedge ineffectiveness in the three months ended March 31, 2016 and 2015.
[2]	Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.
[3]	There was no hedge ineffectiveness in either the three months ended March 31, 2016 or 2015. All other 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 and recorded in Other Income, Net.

DERIVATIVE INSTRUMENTS - CASH FLOW HEDGES (Details) $ in Millions	3 Months Ended
	Mar. 31, 2016 USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ 21
Maximum Length Of Time Hedged In Interest Rate Cash Flow Hedge 1	13 years
Joint Venture Maximum Length Of Time Hedged In Cash Flow Hedge	19 years
Cash Flow Hedge Gain (Loss) To Be Reclassified Within Twelve Months For Noncontrolling Interest	$ 12
San Diego Gas and Electric Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Maximum Length Of Time Hedged In Interest Rate Cash Flow Hedge 1	3 years
Cash Flow Hedge Gain (Loss) To Be Reclassified Within Twelve Months For Noncontrolling Interest	$ 12
Southern California Gas Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ 0

DERIVATIVE INSTRUMENTS WITH CONTINGENT FEATURES (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 6	$ 6
Additional Collateral Aggregate Fair Value	7
San Diego Gas and Electric Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	5	$ 5
Additional Collateral Aggregate Fair Value	$ 6

FAIR VALUE MEASUREMENTS - RECURRING FAIR VALUE MEASURES (Details) - USD ($)
$ in Millions

Mar. 31, 2016

Dec. 31, 2015

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies

$ 623

$ 619

105

156

Nuclear decommissioning trusts - Total debt securities

190

182

451

429

Derivative Financial Instruments Assets [Member]

^[1]

1,074

1,048

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, assets

Commodity contracts subject to rate recovery, assets

101

Derivative Financial Instruments Liabilities [Member]

1,223

1,188

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, liabilities

181

171

Commodity contracts subject to rate recovery, liabilities

San Diego Gas and Electric Company [Member] | Nuclear Decommisioning Trusts [Member]

252

242

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies

623

619

105

156

Nuclear decommissioning trusts - Total debt securities

190

182

451

429

San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Assets [Member]

^[1]

1,074

1,048

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, assets

Commodity contracts subject to rate recovery, assets

San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Liabilities [Member]

1,174

1,148

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, liabilities

Commodity contracts subject to rate recovery, liabilities

Southern California Gas Company [Member] | Derivative Financial Instruments Assets [Member]

107

103

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, assets

Commodity contracts subject to rate recovery, assets

Southern California Gas Company [Member] | Derivative Financial Instruments Liabilities [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, liabilities

Commodity contracts subject to rate recovery, liabilities

Level 1 | Nuclear Decommisioning Trusts [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies

623

619

Nuclear decommissioning trusts - Total debt securities

Level 1 | Derivative Financial Instruments Assets [Member]

^[1]

685

666

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, assets

Commodity contracts subject to rate recovery, assets

Level 1 | Derivative Financial Instruments Liabilities [Member]

686

688

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, liabilities

Commodity contracts subject to rate recovery, liabilities

Level 1 | San Diego Gas and Electric Company [Member] | Nuclear Decommisioning Trusts [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies

623

619

Nuclear decommissioning trusts - Total debt securities

Level 1 | San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Assets [Member]

^[1]

685

666

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, assets

Commodity contracts subject to rate recovery, assets

Level 1 | San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Liabilities [Member]

685

666

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, liabilities

Commodity contracts subject to rate recovery, liabilities

Level 1 | Southern California Gas Company [Member] | Derivative Financial Instruments Assets [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, assets

Commodity contracts subject to rate recovery, assets

Level 1 | Southern California Gas Company [Member] | Derivative Financial Instruments Liabilities [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, liabilities

Commodity contracts subject to rate recovery, liabilities

Level 2 | Nuclear Decommisioning Trusts [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies

156

Nuclear decommissioning trusts - Total debt securities

190

182

389

382

Level 2 | Derivative Financial Instruments Assets [Member]

^[1]

389

382

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, assets

Commodity contracts subject to rate recovery, assets

Level 2 | Derivative Financial Instruments Liabilities [Member]

417

404

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, liabilities

181

171

Commodity contracts subject to rate recovery, liabilities

Level 2 | San Diego Gas and Electric Company [Member] | Nuclear Decommisioning Trusts [Member]

254

242

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies

156

Nuclear decommissioning trusts - Total debt securities

190

182

389

382

Level 2 | San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Assets [Member]

^[1]

389

382

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, assets

Commodity contracts subject to rate recovery, assets

Level 2 | San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Liabilities [Member]

389

382

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, liabilities

Commodity contracts subject to rate recovery, liabilities

Level 2 | Southern California Gas Company [Member] | Derivative Financial Instruments Assets [Member]

105

104

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, assets

Commodity contracts subject to rate recovery, assets

Level 2 | Southern California Gas Company [Member] | Derivative Financial Instruments Liabilities [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, liabilities

Commodity contracts subject to rate recovery, liabilities

Level 3 | Nuclear Decommisioning Trusts [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies

Nuclear decommissioning trusts - Total debt securities

Level 3 | Derivative Financial Instruments Assets [Member]

^[1]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, assets

Commodity contracts subject to rate recovery, assets

Level 3 | Derivative Financial Instruments Liabilities [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, liabilities

Commodity contracts subject to rate recovery, liabilities

Level 3 | San Diego Gas and Electric Company [Member] | Nuclear Decommisioning Trusts [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies

Nuclear decommissioning trusts - Total debt securities

Level 3 | San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Assets [Member]

^[1]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, assets

Commodity contracts subject to rate recovery, assets

Level 3 | San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Liabilities [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, liabilities

Commodity contracts subject to rate recovery, liabilities

Level 3 | Southern California Gas Company [Member] | Derivative Financial Instruments Assets [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, assets

Commodity contracts subject to rate recovery, assets

Level 3 | Southern California Gas Company [Member] | Derivative Financial Instruments Liabilities [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, liabilities

Commodity contracts subject to rate recovery, liabilities

Netting | Nuclear Decommisioning Trusts [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies

^[2]

^[2]

^[2]

Nuclear decommissioning trusts - Total debt securities

^[2]

^[2]

Netting | Derivative Financial Instruments Assets [Member]

^[1],[2]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, assets

^[2]

^[2]

(4)

Commodity contracts subject to rate recovery, assets

^[2]

Netting | Derivative Financial Instruments Liabilities [Member]

^[2]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, liabilities

^[2]

^[2]

(7)

(4)

Commodity contracts subject to rate recovery, liabilities

^[2]

(55)

(54)

Netting | San Diego Gas and Electric Company [Member] | Nuclear Decommisioning Trusts [Member]

^[2]

(62)

(58)

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies

^[2]

^[2]

^[2]

Nuclear decommissioning trusts - Total debt securities

^[2]

^[2]

Netting | San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Assets [Member]

^[1],[2]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, assets

^[2]

Commodity contracts subject to rate recovery, assets

^[2]

Netting | San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Liabilities [Member]

^[2]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, liabilities

^[2]

^[2]

(1)

Commodity contracts subject to rate recovery, liabilities

^[2]

(55)

(54)

Netting | Southern California Gas Company [Member] | Derivative Financial Instruments Assets [Member]

^[2]

(56)

(55)

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, assets

^[2]

Commodity contracts subject to rate recovery, assets

^[2]

Netting | Southern California Gas Company [Member] | Derivative Financial Instruments Liabilities [Member]

^[2]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Commodity contracts not subject to rate recovery, liabilities

^[2]

(1)

Commodity contracts subject to rate recovery, liabilities

^[2]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

^[2]

$ (1)

[1]	Excludes cash balances and cash equivalents.
[2]	Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.

FAIR VALUE MEASUREMENTS - RECON OF LEVEL 3 ASSETS (Details) - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance at beginning of period	$ 19,000,000	$ 107,000,000
Realized and unrealized gains (losses)	(1,000,000)	6,000,000
Settlements	(7,000,000)	(11,000,000)
Balance at end of period	11,000,000	102,000,000
Change in unrealized gains relating to instruments still held at the end of the period	(1,000,000)	$ 1,000,000
Maximum [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Congestion Revenue Rights			$ 10	$ 8
Market Electricity Forward Price Inputs	57.43
Minimum [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Congestion Revenue Rights			$ (24)	$ (16)
Market Electricity Forward Price Inputs	$ 15.85

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($)
$ in Millions

3 Months Ended

12 Months Ended

Mar. 31, 2016

Dec. 31, 2015

Carrying Amount

Fair value of financial instruments, Total long-term debt

^[1],[2]

$ 13,761

Preferred Stock Of Subsidiaries Fair Value Disclosure

Due from affiliate, noncurrent, Fair Value Disclosure

^[3]

173

175

Debt Instrument Increase Accrued Interest

Unamortized Discount and Debt Issuance Costs

106

107

Build-To-Suit and Capital Lease Obligations

386

387

Carrying Amount | Otay Mesa Energy Center Loan Payable Currently Through April 2019 Member [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Debt Instrument Carrying Amount

312

315

Carrying Amount | San Diego Gas and Electric Company [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments, Total long-term debt

^[2],[4]

4,285

4,304

Capital Lease Obligations

243

244

Unamortized Discount and Debt Issuance Costs

Carrying Amount | Southern California Gas Company [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments, Total long-term debt

^[5]

2,513

Preferred Stock Of Subsidiaries Fair Value Disclosure

Capital Lease Obligations

Unamortized Discount and Debt Issuance Costs

Fair Value

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments, Total long-term debt

^[1],[2]

15,015

14,633

Preferred Stock Of Subsidiaries Fair Value Disclosure

Due from affiliate, noncurrent, Fair Value Disclosure

^[3]

164

166

Fair Value | Fair Value, Inputs, Level 1 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments, Total long-term debt

^[1],[2]

Preferred Stock Of Subsidiaries Fair Value Disclosure

Due from affiliate, noncurrent, Fair Value Disclosure

^[3]

Fair Value | Fair Value, Inputs, Level 2 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments, Total long-term debt

^[1],[2]

14,363

13,985

Preferred Stock Of Subsidiaries Fair Value Disclosure

Due from affiliate, noncurrent, Fair Value Disclosure

^[3]

Fair Value | Fair Value, Inputs, Level 3 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments, Total long-term debt

^[1],[2]

652

648

Preferred Stock Of Subsidiaries Fair Value Disclosure

Due from affiliate, noncurrent, Fair Value Disclosure

^[3]

Fair Value | San Diego Gas and Electric Company [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments, Total long-term debt

^[2],[4]

4,829

4,670

Fair Value | San Diego Gas and Electric Company [Member] | Fair Value, Inputs, Level 1 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments, Total long-term debt

^[2],[4]

Fair Value | San Diego Gas and Electric Company [Member] | Fair Value, Inputs, Level 2 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments, Total long-term debt

^[2],[4]

4,517

4,355

Fair Value | San Diego Gas and Electric Company [Member] | Fair Value, Inputs, Level 3 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments, Total long-term debt

^[2],[4]

312

315

Fair Value | Southern California Gas Company [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments, Total long-term debt

^[5]

2,731

2,621

Preferred Stock Of Subsidiaries Fair Value Disclosure

Fair Value | Southern California Gas Company [Member] | Fair Value, Inputs, Level 1 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments, Total long-term debt

^[5]

Preferred Stock Of Subsidiaries Fair Value Disclosure

Fair Value | Southern California Gas Company [Member] | Fair Value, Inputs, Level 2 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments, Total long-term debt

^[5]

2,731

2,621

Preferred Stock Of Subsidiaries Fair Value Disclosure

Fair Value | Southern California Gas Company [Member] | Fair Value, Inputs, Level 3 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments, Total long-term debt

^[5]

Preferred Stock Of Subsidiaries Fair Value Disclosure

$ 0

[1]	Before reductions for unamortized discount (net of premium) and debt issuance costs of $106 million and $107 million at March 31, 2016 and December 31, 2015, respectively, and excluding build-to-suit and capital lease obligations of $386 million and $387 million at March 31, 2016 and December 31, 2015, respectively. We discuss our long-term debt in Note 6 above and in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report.
[2]	Level 3 instruments include $312 million and $315 million at March 31, 2016 and December 31, 2015, respectively, related to Otay Mesa VIE.
[3]	Excluding accumulated interest outstanding of $13 million and $11 million at March 31, 2016 and December 31, 2015, respectively.
[4]	Before reductions for unamortized discount and debt issuance costs of $43 million at March 31, 2016 and December 31, 2015, and excluding capital lease obligations of $243 million and $244 million at March 31, 2016 and December 31, 2015, respectively.
[5]	Before reductions for unamortized discount and debt issuance costs of $24 million at March 31, 2016 and December 31, 2015, and excluding capital lease obligations of $1 million at March 31, 2016 and December 31, 2015.

FAIR VALUE MEASUREMENTS - NONRECURRING INPUTS (Details) - USD ($)
$ in Millions

3 Months Ended

Mar. 31, 2016

Mar. 29, 2016

Dec. 31, 2015

Fair Value Inputs Assets Quantitative Information [Line Items]

Equity Method Investments

$ 2,727

$ 2,905

Rockies Express [Member]

Fair Value Inputs Assets Quantitative Information [Line Items]

Equity Method Investment Ownership Percentage

25.00%

Proceeds From Sale Of Equity Method Investments

440

Equity Method Investment, Other than Temporary Impairment

Equity Method Investment Other Than Temporary Impairment Net Of Tax Benefit

Equity Method Investments

$ 436

$ 484

Market Approach Valuation Technique [Member] | Fair Value, Inputs, Level 2 [Member] | One Hundred Percent [Member] | Rockies Express [Member]

Fair Value Inputs Assets Quantitative Information [Line Items]

Investments In Affiliates Subsidiaries Associates And Joint Ventures Fair Value Disclosure

^[1]

$ 440

[1]	At measurement date of March 29, 2016. At March 31, 2016, our investment in Rockies Express had a carrying value of $436 million, reflecting subsequent equity method activity to record a distribution.

NUCLEAR PLANT - INVESTMENT (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Nuclear Plant Investment [Line Items]
Loss From Plant Closure, Pretax	$ 0	$ (21)
Loss (Adjustment) From Plant Closure, After Tax		(13)
Loss from plant closure, after-tax (cumulative)	$ 125
Nuclear Plant, Ownership Percentage	20.00%
San Diego Gas and Electric Company [Member]
Nuclear Plant Investment [Line Items]
Utility plant closure (adjustment) loss	$ 0	(21)
Loss (Adjustment) From Plant Closure, After Tax		$ (13)
Loss from plant closure, after-tax (cumulative)	$ 125
Nuclear Plant, Ownership Percentage	20.00%

NUCLEAR PLANT - DECOMMISSIONING AND FUNDING (Details) - USD ($)
$ in Millions

3 Months Ended

Dec. 31, 2015

Sep. 30, 2015

Mar. 31, 2016

Nuclear Plant Decommissioning And Funding [Line Items]

$ 1,063

^[1]

$ 1,082

Nuclear Plant Decommissioning And Funding [Line Items]

Nuclear Plant Decommissioning And Funding [Line Items]

1,063

^[1]

$ 1,082

Year 2013 [Member]

Authorized Annuial Recovery Amount, Nuclear Decommissioning Trust Funding

$ 55

Year 2013 [Member] | San Diego Gas and Electric Company [Member]

Nuclear Plant Decommissioning And Funding [Line Items]

Authorized Annuial Recovery Amount, Nuclear Decommissioning Trust Funding

Nuclear Plant Decommissioning And Funding [Line Items]

$ 18

Year 2014 [Member]

Authorized Annuial Recovery Amount, Nuclear Decommissioning Trust Funding

Year 2014 [Member] | San Diego Gas and Electric Company [Member]

Nuclear Plant Decommissioning And Funding [Line Items]

Authorized Annuial Recovery Amount, Nuclear Decommissioning Trust Funding

$ 13

[1]	Derived from audited financial statements.

NUCLEAR PLANT - REGULATORY ASSET (Details) - USD ($)
$ in Millions

Mar. 31, 2016

Dec. 31, 2015

^[1]

$ 3,336

$ 3,273

119

107

968

977

Nuclear Plant Closure [Member]

686

$ 636

Regulatory Asset, Nuclear Plant Closure

243

Nuclear Plant Closure [Member] | San Diego Gas and Electric Company [Member]

200

Regulatory Asset, Nuclear Plant Closure

243

Schedule of Available-for-sale Securities [Line Items]

$ 200

[1]	Derived from audited financial statements.

NUCLEAR PLANT - COST STUDY (Details) $ in Millions	3 Months Ended
NUCLEAR PLANT - COST STUDY (Details) $ in Millions	Mar. 31, 2016 USD ($)
SDG&E Ownership [Member]
Environmental Exit Cost [Line Items]
Total Estimated Nuclear Decommissioning Costs, Latest Cost Study	$ 899
SDG&E Ownership [Member] \| San Diego Gas and Electric Company [Member]
Environmental Exit Cost [Line Items]
Total Estimated Nuclear Decommissioning Costs, Latest Cost Study	899
Total Ownership [Member]
Environmental Exit Cost [Line Items]
Total Estimated Nuclear Decommissioning Costs, Latest Cost Study	4,411
Total Ownership [Member] \| San Diego Gas and Electric Company [Member]
Environmental Exit Cost [Line Items]
Total Estimated Nuclear Decommissioning Costs, Latest Cost Study	$ 4,411

NUCLEAR PLANT - SETTLEMENT (Details) $ in Millions	3 Months Ended
NUCLEAR PLANT - SETTLEMENT (Details) $ in Millions	Dec. 31, 2015 USD ($)
To SDGE [Member]
Nuclear Plant Insurance Settlement [Line Items]
Nuclear Plant Insurance Recoveries	$ 80
Nuclear Plant Insurance Recovery Allocation Percentage	5.00%
To SDGE [Member] \| San Diego Gas and Electric Company [Member]
Nuclear Plant Insurance Settlement [Line Items]
Nuclear Plant Insurance Recoveries	$ 80
Nuclear Plant Insurance Recovery Allocation Percentage	5.00%
Total Ownership [Member]
Nuclear Plant Insurance Settlement [Line Items]
Nuclear Plant Insurance Recoveries	$ 400
Total Ownership [Member] \| San Diego Gas and Electric Company [Member]
Nuclear Plant Insurance Settlement [Line Items]
Nuclear Plant Insurance Recoveries	400
To Ratepayers [Member]
Nuclear Plant Insurance Settlement [Line Items]
Nuclear Plant Insurance Recoveries	75
To Ratepayers [Member] \| San Diego Gas and Electric Company [Member]
Nuclear Plant Insurance Settlement [Line Items]
Nuclear Plant Insurance Recoveries	$ 75

SONGS NDT 1 (Details) - USD ($)
$ in Millions

3 Months Ended

12 Months Ended

Mar. 31, 2016

Mar. 31, 2015

Dec. 31, 2015

$ 662

$ 660

433

423

(13)

(20)

Schedule of Available-for-sale Securities [Line Items]

1,082

1,063

Proceeds from sales

^[1]

$ 94

Gross realized gains

Gross realized losses

(8)

$ (4)

Total Debt Securities

439

431

(8)

(13)

Debt Securities Issued By The U.S. Treasury And Other U.S. Government Corporations And Agencies

451

429

Schedule of Available-for-sale Securities [Line Items]

101

^[2]

^[2]

^[2]

Schedule of Available-for-sale Securities [Line Items]

105

^[2]

Municipal Bonds

146

^[3]

148

^[3]

^[3]

Schedule of Available-for-sale Securities [Line Items]

156

^[3]

156

Other Debt Securities

192

^[3]

194

^[3]

(8)

^[3]

(13)

Schedule of Available-for-sale Securities [Line Items]

190

^[3]

182

Equity Securities

214

413

412

(4)

(7)

Cash And Cash Equivalents

623

619

Schedule of Available-for-sale Securities [Line Items]

(1)

$ 8

$ 15

[1]	Excludes securities that are held to maturity.
[2]	Maturity dates are 2016-2065.
[3]	Maturity dates are 2016-2115.

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF GENERAL RATE CASE (Details) - Year 2016 [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Mar. 31, 2016
San Diego Gas and Electric Company [Member]
Public Utilities General Disclosures [Line Items]
General Rate Case, Revenue Requirement, Revised Request				$ 1,811
General Rate Case, Revenue Requirement Increase, Original Request				133
General Rate Case, Revenue Requirement Increase, Revised Request				$ 17
General Rate Case, Revenue Requirement Percentage Increase, Revised Request	4.30%	3.50%	3.50%	1.00%
General Rate Case, Revised Request Decrease Compared To Original				$ (100)
General Rate Case, Adjustment To Decrease Estimated Revenue Requirement				16
General Rate Case, Proposed Rate Base Adjustment				93
General Rate Case, Tax Memorandum Accounts Balance					$ 39
Southern California Gas Company [Member]
Public Utilities General Disclosures [Line Items]
General Rate Case, Revenue Requirement, Revised Request				2,219
General Rate Case, Revenue Requirement Increase, Original Request				256
General Rate Case, Revenue Requirement Increase, Revised Request				$ 122
General Rate Case, Revenue Requirement Percentage Increase, Revised Request	4.30%	3.50%	3.50%	6.00%
General Rate Case, Revised Request Decrease Compared To Original				$ (133)
General Rate Case, Proposed Rate Base Adjustment				$ 92
General Rate Case, Tax Memorandum Accounts Balance					$ 74

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF UTILITY PROJECTS (Details) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2014	Jun. 11, 2014
Southern Gas System Member [Member] \| Total Estimated Cost [Member]
Schedule of Utility Projects [Line Items]
Development In Process	$ 23,000
Pipeline Safety And Reliability Project [Member] \| Total Estimated Cost [Member]
Schedule of Utility Projects [Line Items]
Revised Estimated Project Cost	633,000
San Diego Gas and Electric Company [Member] \| Pipeline Safety Enhancement Plan [Member]
Schedule of Utility Projects [Line Items]
Pipeline Safety Plan Regulatory Account	12,000
Recovery Requested, PSEP Costs	100		$ 100
San Diego Gas and Electric Company [Member] \| Sycamore Penasquitos Transmission Project [Member] \| Minimum Range [Member]
Schedule of Utility Projects [Line Items]
Estimated Project Cost	120,000
Revised Estimated Project Cost	250,000
San Diego Gas and Electric Company [Member] \| Sycamore Penasquitos Transmission Project [Member] \| Maximum Range [Member]
Schedule of Utility Projects [Line Items]
Estimated Project Cost	150,000
Revised Estimated Project Cost	300,000
San Diego Gas and Electric Company [Member] \| Pipeline Testing/Replacing 1956 to 1961 [Member]
Schedule of Utility Projects [Line Items]
Disallowed Costs Impact On Earnings After Tax	500
Southern California Gas Company [Member] \| Pipeline Safety Enhancement Plan [Member]
Schedule of Utility Projects [Line Items]
Disallowed Costs Impact On Earnings After Tax		$ 5,000
Pipeline Safety Plan Regulatory Account	177,000
Recovery Requested, PSEP Costs	26,800		$ 46,000
Southern California Gas Company [Member] \| Pipeline Testing/Replacing 1956 to 1961 [Member]
Schedule of Utility Projects [Line Items]
Disallowed Costs Impact On Earnings After Tax	$ 2,600

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF WILDFIRE COST RECOVERY (Details) - San Diego Gas and Electric Company [Member]	3 Months Ended
	Sep. 30, 2015 USD ($)
Public Utilities General Disclosures [Line Items]
Incurred Costs	$ 2,400,000,000
Requested Recovery	379,000,000
Insurance Reimbursement	1,100,000,000
Third Party Settlement Recoveries	824,000,000
FERC Jurisdictional Rates	$ 80,000,000
Voluntary Shareholder Contribution, Percentage	10.00%
WEMA Balance	$ 42,000,000
FERC-Approved Wildfire Damage Expenses	$ 23,100,000

COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details)
$ in Thousands

3 Months Ended

Apr. 28, 2016

Mar. 31, 2016

USD ($)

Dec. 31, 2015

USD ($)

^[1]

$ 37,000

302,000

$ 274,000

660,000

325,000

29,000

6,000

302,000

274,000

Wildfire [Member] | San Diego Gas and Electric Company [Member]

660,000

$ 325,000

Regulatory Assets Arising From Wildfire Litigation Costs

363,000

Potential After-Tax Charge for Nonrecovery of CPUC Regulatory Assets

213,000

Portion of Regulatory Assets Arising From Wildfire Litigation Related To CPUC Operations

360,000

Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Southern California Gas Company [Member]

Liability Insurance Coverage, Maximum

665,000

1,000,000

Loss Contingency, Number Of Lawsuits

138

Number Of Lawsuits Filed In Los Angeles County

134

Number Of Lawsuits Filed In San Diego County

Number Of Lawsuits Filed In US District Court Of Southern District Of California

Maximum Occupational Safety And Health Penalties

280

Civil Penalties Per Day

$ 250

Proportion Of Total Gas Storage Capacity, Percentage

63.00%

Net Book Value Of Aliso Canyon Facility

$ 415,000

Construction Work In Progress Of New Compressor Station

$ 180,000

Estimated Costs Related To Temporary Relocation Percentage

70.00%

Estimated Costs Related To Controlling Well And Stopping Leak And Emissions Percentage

15.00%

[1]	Derived from audited financial statements.

COMMITMENTS AND CONTINGENCIES - OTHER LITIGATION (Details) £ in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2016 USD ($)	Oct. 01, 2015 GBP (£)	Oct. 01, 2014 GBP (£)
Wind Farm [Member] \| San Diego Gas and Electric Company [Member]
Loss Contingencies [Line Items]
Estimated Tax Equity Investment	$ 285
So Cal Gas PCB Litigation [Member] \| Southern California Gas Company [Member]
Loss Contingencies [Line Items]
Loss Contingency, Number Of Lawsuits	7
Number of Lawsuits Settled	6
Mobile Gas Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Number Of Lawsuits	14
Number of Lawsuits Settled	11
Loss Contingency Number Of Plaintiffs	250
HMRC VAT Claim [Member]
Loss Contingencies [Line Items]
VAT Tax Claim Paid Upon Appeal \| £		£ 156	£ 86
Investment in RBS Sempra Commodities LLP	$ 67

COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS (Details) - Sempra Natural Gas [Member] $ in Millions	3 Months Ended
	Mar. 31, 2016 USD ($)
Natural Gas Contracts [Member]
Payments Under Contractual Commitments [Line Items]
Increase (Decrease) In Commitment Amount	$ (46)
Increase (Decrease) In Commitment Amount, Payments Due, Current	(60)
Increase (Decrease) In Commitment Amount, Payments Due, In Two Years	10
Increase (Decrease) In Commitment Amount, Payments Due, In Three Years	$ 4
Liquefied Natural Gas Contracts [Member]
Payments Under Contractual Commitments [Line Items]
Escalation Percentage Beyond Year 2028	1.00%
Increase (Decrease) In Commitment Amount, Payments Due, Current	$ (146)
Increase (Decrease) In Commitment Amount, Payments Due, In Two Years	(3)
Increase (Decrease) In Commitment Amount, Payments Due, In Three Years	(7)
Increase (Decrease) In Commitment Amount, Payments Due, In Four Years	(18)
Increase (Decrease) In Commitment Amount, Payments Due, In Five Years	(30)
Increase (Decrease) In Commitment Amount, Payments Due, In Thereafter	$ 20

COMMITMENTS AND CONTINGENCIES - NUCLEAR INSURANCE (Details) - San Diego Gas and Electric Company [Member] $ in Thousands	Mar. 31, 2016 USD ($)
Schedule Of Nuclear Insurance [Line Items]
Nuclear Liability Insurance Coverage, Maximum	$ 375,000
Secondary Financial Protection, Maximum	13,200,000
Secondary Financial Protection, Company Contribution, Maximum	50,930
Secondary Financial Protection, Company Contribution, Annual Maximum	7,600
Nuclear Property Insurance Coverage, Maximum	2,750,000
Nuclear Property Damage Insurance, Premium Assessment	9,700
Nuclear Property Insurance Terrorism Coverage, Maximum	3,240,000
Nuclear Property Insurance, Deductible Per Event	$ 2,500

COMMITMENTS AND CONTINGENCIES - NUCLEAR FUEL DISPOSAL (Details) - San Diego Gas and Electric Company [Member] $ in Millions	12 Months Ended
	Dec. 31, 2013 USD ($)
SDG&E Ownership [Member]
Jointly Owned Utility Plant Interests [Line Items]
Spent Nuclear Fuel Damages Awarded, Value	$ 32
Total Ownership [Member]
Jointly Owned Utility Plant Interests [Line Items]
Spent Nuclear Fuel Damages Awarded, Value	$ 162

SEGMENT INFORMATION (Details) - USD ($)

3 Months Ended

Mar. 31, 2016

Mar. 31, 2015

Dec. 31, 2015

Segment Reporting Information, Profit (Loss) [Abstract]

Segment reporting information, Percentage of Total Consolidated Revenues

$ 2,622,000,000

$ 2,682,000,000

100.00%

$ 143,000,000

$ 134,000,000

Segment reporting information, Depreciation and Amortization

6,000,000

7,000,000

$ 328,000,000

$ 303,000,000

Segment reporting information, Percentage of Consolidated Depreciation and Amortization

100.00%

Segment reporting information, Income Tax Expense (Benefit)

$ 142,000,000

$ 163,000,000

Segment reporting information, Equity Earnings (Losses) Recorded Net of Tax

(22,000,000)

19,000,000

17,000,000

15,000,000

Segment reporting information, Percentage of Consolidated Earnings (Losses)

$ 319,000,000

$ 437,000,000

100.00%

Segment Reporting Information, Additional Information [Abstract]

Segment reporting information, Expenditures for property plant and equipment

$ 971,000,000

$ 780,000,000

Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment

100.00%

Segment reporting information, Percentage of Consolidated Assets

$ 41,835,000,000

$ 41,150,000,000

^[1]

100.00%

Segment Reporting Information, Profit (Loss) [Abstract]

$ 2,727,000,000

$ 2,905,000,000

S D G E Segment [Member]

Segment reporting information, Percentage of Total Consolidated Revenues

$ 991,000,000

$ 966,000,000

38.00%

36.00%

Segment reporting information, Depreciation

$ 48,000,000

$ 52,000,000

$ 159,000,000

$ 145,000,000

Segment reporting information, Percentage of Consolidated Depreciation

49.00%

48.00%

Segment reporting information, Income Tax Expense (Benefit)

$ 72,000,000

$ 88,000,000

Segment reporting information, Percentage of Consolidated Earnings (Losses)

$ 129,000,000

$ 147,000,000

40.00%

34.00%

Segment Reporting Information, Additional Information [Abstract]

Segment reporting information, Expenditures for property plant and equipment

$ 329,000,000

$ 355,000,000

Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment

34.00%

46.00%

Segment reporting information, Percentage of Consolidated Assets

$ 16,625,000,000

$ 16,515,000,000

40.00%

Segment Reporting Information, Intersegment Revenues

$ 3,000,000

$ 2,000,000

So Cal Gas Segment [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Segment reporting information, Percentage of Total Consolidated Revenues

$ 1,033,000,000

$ 1,048,000,000

40.00%

39.00%

Segment reporting information, Depreciation

$ 22,000,000

$ 19,000,000

$ 122,000,000

$ 113,000,000

Segment reporting information, Percentage of Consolidated Depreciation

37.00%

Segment reporting information, Income Tax Expense (Benefit)

$ 87,000,000

$ 95,000,000

Segment reporting information, Percentage of Consolidated Earnings (Losses)

^[2]

$ 195,000,000

$ 214,000,000

61.00%

49.00%

Segment Reporting Information, Additional Information [Abstract]

Segment reporting information, Expenditures for property plant and equipment

$ 340,000,000

$ 315,000,000

Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment

35.00%

40.00%

Segment reporting information, Percentage of Consolidated Assets

$ 12,427,000,000

$ 12,104,000,000

30.00%

29.00%

Segment Reporting Information, Intersegment Revenues

$ 17,000,000

$ 19,000,000

Sempra South American Utilities Segment [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Segment reporting information, Percentage of Total Consolidated Revenues

$ 400,000,000

$ 389,000,000

15.00%

$ 9,000,000

$ 5,000,000

Segment reporting information, Depreciation and Amortization

5,000,000

4,000,000

$ 13,000,000

Segment reporting information, Percentage of Consolidated Depreciation and Amortization

4.00%

Segment reporting information, Income Tax Expense (Benefit)

$ 14,000,000

$ 16,000,000

Segment reporting information, Equity Earnings (Losses) Recorded Net of Tax

2,000,000

(1,000,000)

Segment reporting information, Percentage of Consolidated Earnings (Losses)

$ 38,000,000

$ 41,000,000

12.00%

9.00%

Segment Reporting Information, Additional Information [Abstract]

Segment reporting information, Expenditures for property plant and equipment

$ 43,000,000

$ 31,000,000

Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment

4.00%

Segment reporting information, Percentage of Consolidated Assets

$ 3,434,000,000

$ 3,235,000,000

8.00%

Sempra Mexico Segment [Member]

$ (2,000,000)

$ (4,000,000)

Segment Reporting Information, Profit (Loss) [Abstract]

Segment reporting information, Percentage of Total Consolidated Revenues

$ 138,000,000

$ 163,000,000

5.00%

6.00%

$ 4,000,000

$ 5,000,000

Segment reporting information, Depreciation and Amortization

2,000,000

$ 17,000,000

Segment reporting information, Percentage of Consolidated Depreciation and Amortization

5.00%

6.00%

Segment reporting information, Income Tax Expense (Benefit)

$ 41,000,000

$ 8,000,000

Segment reporting information, Equity Earnings (Losses) Recorded Net of Tax

15,000,000

16,000,000

Segment reporting information, Percentage of Consolidated Earnings (Losses)

$ 17,000,000

$ 47,000,000

5.00%

11.00%

Segment Reporting Information, Additional Information [Abstract]

Segment reporting information, Expenditures for property plant and equipment

$ 40,000,000

$ 55,000,000

Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment

4.00%

7.00%

Segment reporting information, Percentage of Consolidated Assets

$ 3,843,000,000

$ 3,783,000,000

9.00%

Segment Reporting Information, Intersegment Revenues

$ 522,000,000

$ 519,000,000

27,000,000

$ 25,000,000

Sempra Renewables Segment [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Segment reporting information, Percentage of Total Consolidated Revenues

$ 7,000,000

$ 8,000,000

0.00%

$ 0

$ 1,000,000

Segment reporting information, Depreciation and Amortization

1,000,000

$ 1,000,000

$ 2,000,000

Segment reporting information, Percentage of Consolidated Depreciation and Amortization

0.00%

1.00%

Segment reporting information, Income Tax Expense (Benefit)

$ (12,000,000)

$ (17,000,000)

7,000,000

2,000,000

Segment reporting information, Percentage of Consolidated Earnings (Losses)

$ 13,000,000

4.00%

3.00%

Segment Reporting Information, Additional Information [Abstract]

Segment reporting information, Expenditures for property plant and equipment

$ 181,000,000

$ 3,000,000

Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment

19.00%

1.00%

Segment reporting information, Percentage of Consolidated Assets

$ 1,454,000,000

$ 1,441,000,000

3.00%

4.00%

$ 823,000,000

$ 855,000,000

Segment Reporting Information, Profit (Loss) [Abstract]

Segment reporting information, Percentage of Total Consolidated Revenues

$ 130,000,000

$ 197,000,000

5.00%

7.00%

$ 12,000,000

$ 21,000,000

Segment reporting information, Depreciation and Amortization

16,000,000

19,000,000

$ 13,000,000

$ 12,000,000

Segment reporting information, Percentage of Consolidated Depreciation and Amortization

4.00%

Segment reporting information, Income Tax Expense (Benefit)

$ (25,000,000)

$ 2,000,000

(29,000,000)

17,000,000

Segment reporting information, Percentage of Consolidated Earnings (Losses)

$ (36,000,000)

$ 2,000,000

(11.00%)

0.00%

Segment Reporting Information, Additional Information [Abstract]

Segment reporting information, Expenditures for property plant and equipment

$ 35,000,000

$ 10,000,000

Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment

4.00%

1.00%

Segment reporting information, Percentage of Consolidated Assets

$ 5,395,000,000

$ 5,566,000,000

13.00%

Segment Reporting Information, Intersegment Revenues

$ 1,308,000,000

$ 1,460,000,000

30,000,000

$ 43,000,000

Intercompany Eliminations Segment [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

(24,000,000)

(32,000,000)

Intersegment Revenues Segment [Member]

(18,000,000)

Segment Reporting Information, Profit (Loss) [Abstract]

Segment reporting information, Percentage of Total Consolidated Revenues

^[3]

$ (77,000,000)

$ (89,000,000)

(3.00%)

Intersegment Receivables Segment [Member]

Segment Reporting Information, Additional Information [Abstract]

Segment reporting information, Percentage of Consolidated Assets

$ (2,084,000,000)

$ (2,228,000,000)

(5.00%)

All Other Segments [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Segment reporting information, Depreciation and Amortization

$ 72,000,000

$ 63,000,000

$ 3,000,000

$ 1,000,000

Segment reporting information, Percentage of Consolidated Depreciation and Amortization

1.00%

0.00%

Segment reporting information, Income Tax Expense (Benefit)

$ (35,000,000)

$ (29,000,000)

Segment reporting information, Percentage of Consolidated Earnings (Losses)

$ (37,000,000)

$ (27,000,000)

(11.00%)

(6.00%)

Segment Reporting Information, Additional Information [Abstract]

Segment reporting information, Expenditures for property plant and equipment

$ 3,000,000

$ 11,000,000

Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment

0.00%

1.00%

Segment reporting information, Percentage of Consolidated Assets

$ 741,000,000

$ 734,000,000

2.00%