UNITED STATES SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549
FORM 10-Q
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the quarterly period ended	June 30, 2008
Commission File Number	Name of Registrant as Specified in its Charter, Address and Telephone Number	State of Incorporation	I.R.S. Employer Identification No.
1-40	PACIFIC ENTERPRISES 101 Ash Street San Diego, California 92101 (619) 696-2020	California	94-0743670
1-1402	SOUTHERN CALIFORNIA GAS COMPANY 555 West Fifth Street Los Angeles, California 90013 (213) 244-1200	California	95-1240705

No Change

(Former name, former address and former fiscal year, if changed since last report)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes

X

No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of "accelerated filer and large accelerated filer" in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer

[ ]

Accelerated filer

[ ]

Non-accelerated filer

[ X ]

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes

No

X

Indicate the number of shares outstanding of each of the issuer's classes of common stock, as of the latest practicable date.

Common stock outstanding:

Pacific Enterprises

Wholly owned by Sempra Energy

Southern California Gas Company

Wholly owned by Pacific Enterprises

1

INFORMATION REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report contains statements that are not historical fact and constitute forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. The words "estimates," "believes," "expects," "anticipates," "plans," "intends," "may," "could," "would" and "should" or similar expressions, or discussions of strategy or of plans are intended to identify forward-looking statements. Forward-looking statements are not guarantees of performance. They involve risks, uncertainties and assumptions. Future results may differ materially from those expressed in these forward-looking statements.

Forward-looking statements are necessarily based upon various assumptions involving judgments with respect to the future and other risks, including, among others, local, regional and national economic, competitive, political, legislative and regulatory conditions and developments; actions by the California Public Utilities Commission, the California State Legislature, the Federal Energy Regulatory Commission and other regulatory bodies in the United States; capital markets conditions, inflation rates, interest rates and exchange rates; energy and trading markets, including the timing and extent of changes in commodity prices; the availability of natural gas and liquefied natural gas; weather conditions and conservation efforts; war and terrorist attacks; business, regulatory, environmental and legal decisions and requirements; the status of deregulation of retail natural gas and electricity delivery; the timing and success of business development efforts; the resolution of litigation; and other uncertainties, all of which are difficult to predict and many of which are beyond the control of the companies. Readers are cautioned not to rely unduly on any forward-looking statements and are urged to review and consider carefully the risks, uncertainties and other factors which affect the companies' business described in this report and other reports filed by the companies from time to time with the Securities and Exchange Commission.

2

PART I. FINANCIAL INFORMATION
ITEM 1. CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
PACIFIC ENTERPRISES AND SUBSIDIARIES
STATEMENTS OF CONSOLIDATED INCOME
	Three months ended June 30,						Six months ended June 30,
(Dollars in millions)	2008			2007			2008			2007
	(unaudited)
Operating revenues	$	1,143		$	981		$	2,699		$	2,349
Operating expenses
Cost of natural gas		673			529			1,760			1,441
Other operating expenses		265			249			515			492
Depreciation		71			70			142			139
Franchise fees and other taxes		32			29			71			65
Total operating expenses		1,041			877			2,488			2,137
Operating income		102			104			211			212
Other expense, net		--			(1	)		--			(3	)
Interest income		6			13			13			25
Interest expense		(15	)		(19	)		(32	)		(38	)
Income before income taxes		93			97			192			196
Income tax expense		36			41			77			82
Net income		57			56			115			114
Preferred dividend requirements		1			1			2			2
Earnings applicable to common shares	$	56		$	55		$	113		$	112
See Notes to Condensed Consolidated Financial Statements.

3

PACIFIC ENTERPRISES AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
				June 30,				December 31,
(Dollars in millions)				2008				2007
				(unaudited)
ASSETS
Current assets:
	Cash and cash equivalents			$	135			$	59
	Accounts receivable - trade				510				671
	Accounts receivable - other				68				22
	Due from unconsolidated affiliates				204				5
	Income taxes receivable				86				37
	Deferred income taxes				29				33
	Inventories				45				98
	Other regulatory assets				27				40
	Other				49				23
		Total current assets			1,153				988
Other assets:
	Due from unconsolidated affiliates				459				457
	Other regulatory assets				114				100
	Pension plan assets in excess of benefit obligations				45				62
	Sundry				38				39
		Total other assets			656				658
Property, plant and equipment:
	Property, plant and equipment				8,624				8,448
	Less accumulated depreciation and amortization				(3,379	)			(3,292	)
		Property, plant and equipment, net			5,245				5,156
Total assets				$	7,054			$	6,802
See Notes to Condensed Consolidated Financial Statements.

4

PACIFIC ENTERPRISES AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
				June 30,				December 31,
(Dollars in millions)				2008				2007
				(unaudited)
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities:
	Accounts payable - trade			$	389			$	300
	Accounts payable - other				83				130
	Due to unconsolidated affiliates				83				125
	Regulatory balancing accounts, net				321				183
	Customer deposits				102				90
	Accrued compensation and benefits				77				87
	Other				242				223
		Total current liabilities			1,297				1,138
Long-term debt					1,113				1,113
Deferred credits and other liabilities:
	Customer advances for construction				125				123
	Pension and other postretirement benefit obligations, net of plan assets				58				58
	Deferred income taxes				121				102
	Deferred investment tax credits				32				33
	Regulatory liabilities arising from removal obligations				1,194				1,187
	Regulatory liabilities arising from pension and other postretirement benefit obligations				18				34
	Asset retirement obligations				579				562
	Deferred taxes refundable in rates				231				231
	Preferred stock of subsidiary				20				20
	Deferred credits and other				287				285
		Total deferred credits and other liabilities			2,665				2,635
Commitments and contingencies (Note 6)
Shareholders’ equity:
	Preferred stock				80				80
	Common stock (600 million shares authorized; 84 million shares outstanding; no par value)				1,462				1,462
	Retained earnings				441				378
	Accumulated other comprehensive income (loss)				(4	)			(4	)
		Total shareholders' equity			1,979				1,916
Total liabilities and shareholders' equity				$	7,054			$	6,802
See Notes to Condensed Consolidated Financial Statements.

5

PACIFIC ENTERPRISES AND SUBSIDIARIES
CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS
				Six months ended June 30,
(Dollars in millions)				2008				2007
				(unaudited)
CASH FLOWS FROM OPERATING ACTIVITIES
	Net income			$	115			$	114
	Adjustments to reconcile net income to net cash provided by operating activities:
			Depreciation		142				139
			Deferred income taxes and investment tax credits		21				10
			Other		1				1
	Net change in other working capital components				315				408
	Changes in other assets				5				6
	Changes in other liabilities				(20	)			(13	)
			Net cash provided by operating activities		579				665
CASH FLOWS FROM INVESTING ACTIVITIES
	Expenditures for property, plant and equipment				(242	)			(191	)
	Increase in loans to affiliates, net				(59	)			(105	)
	Other				--				(4	)
			Net cash used in investing activities		(301	)			(300	)
CASH FLOWS FROM FINANCING ACTIVITIES
	Common dividends paid				(200	)			(100	)
	Preferred dividends paid				(2	)			(2	)
			Net cash used in financing activities		(202	)			(102	)
Increase in cash and cash equivalents					76				263
Cash and cash equivalents, January 1					59				211
Cash and cash equivalents, June 30				$	135			$	474
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
	Interest payments, net of amounts capitalized			$	31			$	36
	Income tax payments, net of refunds			$	104			$	26
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING ACTIVITY
		Decrease in accounts payable from investments in property, plant and equipment		$	(31	)		$	(12	)
See Notes to Condensed Consolidated Financial Statements.

6

SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES
STATEMENTS OF CONSOLIDATED INCOME
	Three months ended June 30,						Six months ended June 30,
(Dollars in millions)	2008			2007			2008			2007
	(unaudited)
Operating revenues	$	1,143		$	981		$	2,699		$	2,349
Operating expenses
Cost of natural gas		673			529			1,760			1,441
Other operating expenses		266			248			515			491
Depreciation		71			70			142			139
Franchise fees and other taxes		32			29			71			65
Total operating expenses		1,042			876			2,488			2,136
Operating income		101			105			211			213
Other income (expense), net		2			(2	)		2			(4	)
Interest income		4			8			7			14
Interest expense		(14	)		(17	)		(30	)		(35	)
Income before income taxes		93			94			190			188
Income tax expense		36			39			76			78
Net income		57			55			114			110
Preferred dividend requirements		1			1			1			1
Earnings applicable to common shares	$	56		$	54		$	113		$	109
See Notes to Condensed Consolidated Financial Statements.

7

SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
				June 30,				December 31,
(Dollars in millions)				2008				2007
				(unaudited)
ASSETS
Current assets:
	Cash and cash equivalents			$	135			$	59
	Accounts receivable - trade				510				671
	Accounts receivable - other				68				22
	Due from unconsolidated affiliates				198				129
	Income taxes receivable				24				--
	Deferred income taxes				29				33
	Inventories				45				98
	Other regulatory assets				27				40
	Other				49				22
		Total current assets			1,085				1,074
Other assets:
	Other regulatory assets				114				100
	Pension plan assets in excess of benefit obligations				45				62
	Sundry				15				16
		Total other assets			174				178
Property, plant and equipment:
	Property, plant and equipment				8,622				8,446
	Less accumulated depreciation and amortization				(3,379	)			(3,292	)
		Property, plant and equipment, net			5,243				5,154
Total assets				$	6,502			$	6,406
See Notes to Condensed Consolidated Financial Statements.

8

SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
				June 30,				December 31,
(Dollars in millions)				2008				2007
				(unaudited)
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities:
	Accounts payable - trade			$	389			$	300
	Accounts payable - other				83				130
	Due to unconsolidated affiliates				--				171
	Income taxes payable				--				26
	Regulatory balancing accounts, net				321				183
	Customer deposits				102				90
	Accrued compensation and benefits				77				87
	Other				241				223
		Total current liabilities			1,213				1,210
Long-term debt					1,113				1,113
Deferred credits and other liabilities:
	Customer advances for construction				125				123
	Pension and other postretirement benefit obligations, net of plan assets				58				58
	Deferred income taxes				135				117
	Deferred investment tax credits				32				33
	Regulatory liabilities arising from removal obligations				1,194				1,187
	Regulatory liabilities arising from pension and other postretirement benefit obligations				18				34
	Asset retirement obligations				579				562
	Deferred taxes refundable in rates				231				231
	Deferred credits and other				271				268
		Total deferred credits and other liabilities			2,643				2,613
Commitments and contingencies (Note 6)
Shareholders’ equity:
	Preferred stock				22				22
	Common stock (100 million shares authorized; 91 million shares outstanding; no par value)				866				866
	Retained earnings				649				586
	Accumulated other comprehensive income (loss)				(4	)			(4	)
		Total shareholders' equity			1,533				1,470
Total liabilities and shareholders' equity				$	6,502			$	6,406
See Notes to Condensed Consolidated Financial Statements.

9

SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES
CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS
				Six months ended June 30,
(Dollars in millions)				2008				2007
				(unaudited)
CASH FLOWS FROM OPERATING ACTIVITIES
	Net income			$	114			$	110
	Adjustments to reconcile net income to net cash provided by operating activities:
			Depreciation		142				139
			Deferred income taxes and investment tax credits		21				11
			Other		1				1
	Net change in other working capital components				313				401
	Changes in other assets				5				6
	Changes in other liabilities				(20	)			(10	)
			Net cash provided by operating activities		576				658
CASH FLOWS FROM INVESTING ACTIVITIES
	Expenditures for property, plant and equipment				(242	)			(191	)
	Increase in loans to affiliates, net				(57	)			(105	)
	Other				--				2
			Net cash used in investing activities		(299	)			(294	)
CASH FLOWS FROM FINANCING ACTIVITIES
	Common dividends paid				(200	)			(100	)
	Preferred dividends paid				(1	)			(1	)
			Net cash used in financing activities		(201	)			(101	)
Increase in cash and cash equivalents					76				263
Cash and cash equivalents, January 1					59				211
Cash and cash equivalents, June 30				$	135			$	474
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
	Interest payments, net of amounts capitalized			$	29			$	33
	Income tax payments, net of refunds			$	104			$	26
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING ACTIVITY
		Decrease in accounts payable from investments in property, plant and equipment		$	(31	)		$	(12)
See Notes to Condensed Consolidated Financial Statements.

10

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

NOTE 1. GENERAL

Principles of Consolidation

This Quarterly Report on Form 10-Q is that of Pacific Enterprises (PE) and Southern California Gas Company (SoCalGas) (collectively referred to as the company or the companies). PE’s common stock is wholly owned by Sempra Energy, a California-based Fortune 500 holding company, and PE owns all of the common stock of SoCalGas. The accompanying financial statements are, in one case, the Condensed Consolidated Financial Statements of PE and its subsidiary, SoCalGas, and, in the other case, the Condensed Consolidated Financial Statements of SoCalGas and its subsidiaries, which comprise less than one percent of SoCalGas' consolidated financial position and results of operations.

Sempra Energy also indirectly owns all of the common stock of San Diego Gas & Electric Company (SDG&E). SoCalGas and SDG&E are collectively referred to as the Sempra Utilities.

Basis of Presentation

The Condensed Consolidated Financial Statements have been prepared in conformity with accounting principles generally accepted in the United States of America (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. 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.

Information in this Quarterly Report should be read in conjunction with the company’s Annual Report on Form 10-K for the year ended December 31, 2007 (the Annual Report) and its Quarterly Report on Form 10-Q for the quarter ended March 31, 2008.

The companies' significant accounting policies are described in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. The same accounting policies are followed for interim reporting purposes, except for the adoption of new accounting standards as discussed in Note 2.

SoCalGas accounts for the economic effects of regulation on utility operations in accordance with Statement of Financial Accounting Standards (SFAS) 71, Accounting for the Effects of Certain Types of Regulation.

As discussed in Note 5, beginning April 1, 2008, the SDG&E and SoCalGas core natural gas supply portfolios were combined and are managed by SoCalGas. SoCalGas will procure natural gas for SDG&E’s core customers. This core gas procurement function is considered a shared service, therefore amounts related to SDG&E are not included in the income statement.

NOTE 2. NEW ACCOUNTING STANDARDS

Recently issued pronouncements that have had or may have a significant effect on the company's financial statements are described below.

SFAS 161, "Disclosures about Derivative Instruments and Hedging Activities – an amendment of FASB Statement No. 133" (SFAS 161): SFAS 161 expands the disclosure requirements in Financial

11

Accounting Standards Board (FASB) Statement No. 133, Accounting for Derivative Instruments and Hedging Activities (SFAS 133). SFAS 161 requires qualitative disclosures about objectives and strategies for using derivatives, quantitative disclosures about fair value amounts of and gains and losses on derivative instruments, and disclosures about credit-risk-related contingent features in derivative agreements. SFAS 161 is effective for financial statements issued for fiscal years and interim periods beginning after November 15, 2008. The company is in the process of evaluating the effect of this statement on its financial statement disclosures.

FASB Staff Position (FSP) FIN 39-1, "Amendment of FASB Interpretation No. 39" (FSP FIN 39-1): FSP FIN 39-1 amends certain paragraphs of FASB Interpretation No. 39, Offsetting of Amounts Related to Certain Contracts, to permit a reporting entity to offset fair value amounts recognized for the right to reclaim or the obligation to return cash collateral against fair value amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. FSP FIN 39-1 is effective for fiscal years beginning after November 15, 2007. The company adopted FSP FIN 39-1 effective January 1, 2008. The company applied FSP FIN 39-1 as a change in accounting principle through retrospective application. Each consolidated balance sheet herein reflects the offsetting of net derivative positions with fair value amounts for cash collateral with the same counterparty when management believes a legal right of setoff exists. The adoption of FSP FIN 39-1 did not have a material impact on the company's financial statements. Additional disclosure is provided in Note 4.

NOTE 3. OTHER FINANCIAL DATA

Pension and Other Postretirement Benefits

The following tables provide the components of benefit costs:

		Pension Benefits						Other Postretirement Benefits
		Three months ended						Three months ended
		June 30,						June 30,
(Dollars in millions)			2008			2007			2008			2007
Service cost		$	10		$	9		$	5		$	6
Interest cost			24			24			10			12
Expected return on assets			(25	)		(25	)		(11	)		(10	)
Amortization of:
	Prior service credit		--			--			(1	)		(1	)
	Actuarial loss		--			1			--			1
Regulatory adjustment			(9	)		(8	)		1			--
Total net periodic benefit cost		$	--		$	1		$	4		$	8

		Pension Benefits						Other Postretirement Benefits
		Six months ended						Six months ended
		June 30,						June 30,
(Dollars in millions)			2008			2007			2008			2007
Service cost		$	20		$	20		$	9		$	11
Interest cost			49			48			21			23
Expected return on assets			(51	)		(51	)		(22	)		(20	)
Amortization of:
	Prior service cost (credit)		1			1			(2	)		(3	)
	Actuarial loss		--			1			--			3
Regulatory adjustment			(18	)		(18	)		3			2
Total net periodic benefit cost		$	1		$	1		$	9		$	16

12

The company expects to contribute $2 million to its pension plan and $19 million to its other postretirement benefit plans in 2008. For the three and six months ended June 30, 2008, the company made contributions of $4 million and $9 million to its other postretirement benefit plans, respectively, and a negligible amount of contributions to the pension plan.

Capitalized Interest

The company recorded $1 million and $2 million of capitalized interest for the three months and six months ended June 30, 2008, respectively, including primarily the debt-related portion of allowance for funds used during construction. The company recorded a negligible amount and $1 million of capitalized interest for the three months and six months ended June 30, 2007, respectively, including primarily the debt-related portion of allowance for funds used during construction.

Comprehensive Income

The following is a reconciliation of net income to comprehensive income for PE:

		Three months ended								Six months ended
		June 30,								June 30,
(Dollars in millions)		2008				2007				2008				2007
Net income		$	57			$	56			$	115			$	114
Financial instruments*			5				--				--				--
Comprehensive income		$	62			$	56			$	115			$	114
*	Net of tax expense of $4 million for the three months ended June 30, 2008.

The following is a reconciliation of net income to comprehensive income for SoCalGas:

		Three months ended								Six months ended
		June 30,								June 30,
(Dollars in millions)		2008				2007				2008				2007
Net income		$	57			$	55			$	114			$	110
Financial instruments*			5				--				--				--
Comprehensive income		$	62			$	55			$	114			$	110
*	Net of tax expense of $4 million for the three months ended June 30, 2008.

Other Expense, Net

Other Expense, Net consists of the following:

	Three months ended								Six months ended
	June 30,								June 30,
(Dollars in millions)	2008				2007				2008				2007
Regulatory interest, net	$	(1	)		$	(3	)		$	(2	)		$	(5	)
Allowance for equity funds used during construction		2				1				4				2
Sundry, net		1				--				--				(1	)
Total at SoCalGas		2				(2	)			2				(4	)
Additional at Pacific Enterprises:
Preferred dividends of subsidiary		(1	)			(1	)			(1	)			(1	)
Sundry, net		(1	)			2				(1	)			2
Total	$	--			$	(1	)		$	--			$	(3	)

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NOTE 4. FINANCIAL INSTRUMENTS

The company periodically uses commodity derivative instruments and interest-rate swap agreements to moderate its exposure to commodity price changes and interest-rate changes and to lower its overall cost of borrowing.

Fair Value Hedges

As of June 30, 2008 and December 31, 2007, the company has a fair value hedge for a notional amount of debt totaling $150 million. The fair value hedge balance was an asset of $2 million at June 30, 2008 and December 31, 2007, respectively. The hedge expires in 2011.

Market value adjustments since inception of the hedge were recorded as an increase in fixed-price contracts and other derivatives (in noncurrent assets as Sundry or in Deferred Credits and Other) and as a corresponding increase or decrease in Long-Term Debt without affecting net income or other comprehensive income. There has been no hedge ineffectiveness on this swap.

Cash Flow Hedges

As of June 30, 2008 and December 31, 2007, the company had established a cash flow interest-rate swap hedge for a notional amount of debt totaling $183 million. The swap expires in 2038. There has been no hedge ineffectiveness on this swap.

Natural Gas Contracts

The use of derivative instruments is subject to certain limitations imposed by company policy and regulatory requirements. These instruments enable the company to estimate with greater certainty the effective prices to be received by the company and the prices to be charged to its customers. The company records realized gains or losses on derivative instruments associated with transactions for natural gas contracts in Cost of Natural Gas on the Statements of Consolidated Income. On the Consolidated Balance Sheets, the company records corresponding regulatory assets and liabilities related to unrealized gains and losses from these derivative instruments to the extent derivative gains and losses associated with these derivative instruments will be payable or recoverable in future rates.

Adoption of FSP FIN 39-1

The company adopted FSP FIN 39-1 effective January 1, 2008, which requires retrospective application. Each Consolidated Balance Sheet herein reflects the offsetting of net derivative positions with fair value amounts for cash collateral with the same counterparty when management believes a legal right of setoff exists. As of June 30, 2008 and December 31, 2007, the application of FSP FIN 39-1 had no impact on the Consolidated Balance Sheets. The fair value of cash collateral that was not offset in the Consolidated Balance Sheets as of June 30, 2008 and December 31, 2007 was $6 million and $7 million, respectively. The fair value of commodity derivative assets and liabilities as of June 30, 2008 and December 31, 2007, determined in accordance with the company's netting policy, is presented below.

Fair Value Hierarchy

The company’s valuation techniques used to measure fair value and the definition of the three levels of the fair value hierarchy, as defined in SFAS 157, Fair Value Measurements (SFAS 157), are discussed in Note 7 of the Notes to Consolidated Financial Statements in the Annual Report.

14

The following tables set forth by level within the fair value hierarchy the company's financial assets and liabilities that were accounted for at fair value on a recurring basis as of June 30, 2008 and December 31, 2007. As required by SFAS 157, financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The company's 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.

Recurring Fair Value Measures		At fair value as of June 30, 2008
(Dollars in millions)		Level 1		Level 2		Level 3		Total
Assets:
Commodity derivatives	$	10	$	5	$	--	$	15
Other derivatives		--		4		--		4
Total	$	10	$	9	$	--	$	19
Liabilities:
Other derivatives	$	--	$	1	$	--	$	1

Recurring Fair Value Measures		At fair value as of December 31, 2007
(Dollars in millions)		Level 1		Level 2		Level 3		Total
Assets:
Commodity derivatives	$	7	$	1	$	--	$	8
Other derivatives		--		5		--		5
Total	$	7	$	6	$	--	$	13

NOTE 5. REGULATORY MATTERS

General Rate Case (GRC)

In July 2008, the California Public Utilities Commission (CPUC) issued a final decision in regard to the company’s 2008 general rate case (2008 GRC). The decision adopted the test-year 2008 revenue requirements, effective retroactive to January 1, 2008, and the post-test year revenue requirements that were included in the settlement agreement filed with the CPUC in December 2007. The settlement represents an increase in the annual revenue requirement in 2008 of $59 million as compared to the 2007 revenue requirement and provides average annual increases of approximately $52 million, or three percent, in each of the post-test years' (2009 – 2011) revenue requirements. The decision does not impose a cap on the company’s earnings.

Since the final decision was not issued by June 30, 2008, the company's reported net income for the first six months of 2008 is based on the 2007 authorized revenue requirement as established by the CPUC’s 2004 Cost of Service decision. As the 2008 GRC decision is retroactive, the company will recognize additional net income for the period January 1 through June 30, 2008 of approximately $6 million in the third quarter of 2008.

Utility Ratemaking Incentive Awards

 

Performance-Based Regulation (PBR) consists of a series of measures of utility performance. Generally, if performance is outside of a band around specified benchmarks, the utility is subject to financial rewards or penalties. The three areas that are eligible for incentive awards or penalties are operational incentives, which measure safety and customer service; energy efficiency (sometimes referred to as demand-side management, or DSM or EE) awards based on the effectiveness of the energy efficiency programs; and natural gas procurement awards or penalties.

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The operational PBR incentives and the associated benchmarks are determined as a component of a general rate case or cost of service decision. The operational PBR incentives to be in effect for fiscal year 2008 through the end of the 2008 GRC period were established as part of the CPUC's final decision in the 2008 GRC, which adopted modified PBR measures for customer satisfaction and employee safety. The company is currently reviewing the modified PBR measures and plans on filing its response in regard to these measures in early September 2008.

Incentive awards are not included in the company's earnings until CPUC approval of the award is received.

Operations

During the second quarter of 2008, the company received CPUC approval for its 2007 Operational PBR incentive award of $2 million (pretax).

Energy Efficiency

In January 2008, the CPUC issued a decision modifying the measurement and verification process of this incentive mechanism. The company submitted its initial report on its 2006 and 2007 energy efficiency results, as compared to the company's goals, with the CPUC in the first quarter of 2008. The CPUC is currently reviewing these results and is expected to issue a verification report later this year. Once the report is issued, the company plans to submit its incentive award claims to the CPUC. Settlement discussions have begun with the goal of reaching resolution regarding the 2006-2007 incentive award by year-end.

Natural Gas Procurement

In January 2008, the CPUC approved a SoCalGas natural gas cost incentive mechanism (GCIM) award of $9 million (pretax) for its core natural gas procurement activities for the 12-month period ended March 31, 2007 (Year 13). The award was recorded in the first quarter of 2008. In June 2008, SoCalGas filed its GCIM application for core natural gas procurement activities in the 12-month period ended March 31, 2008 (Year 14), seeking a $6.5 million (pretax) award. A final decision is expected in the first quarter of 2009.

As of April 1, 2008, the SDG&E and SoCalGas core natural gas supply portfolios were combined, and SoCalGas will procure natural gas for SDG&E's requirements in an agency relationship. SoCalGas' GCIM award mechanism will be based on the natural gas procured on a combined portfolio basis.

2009 Biennial Cost Allocation Proceeding (BCAP)

In August 2006, SoCalGas, SDG&E and Southern California Edison jointly filed an application with the CPUC seeking its approval of a series of revisions to the natural gas operations and service offerings of the Sempra Utilities. The CPUC issued a final decision in December 2007 approving some, but not all, of the proposals and deferring a number of issues, including SoCalGas' natural gas storage program, to the Sempra Utilities’ next BCAP, which began in February 2008. Evidentiary hearings on this issue were held in July 2008, with a draft decision expected by year-end 2008. Effective January 1, 2008, and until such time as a resolution is achieved in the BCAP, the storage revenues and costs that were previously shared between ratepayers and shareholders are being deferred pending a regulatory decision on this matter.

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NOTE 6. COMMITMENTS AND CONTINGENCIES

Legal Proceedings

At June 30, 2008, the company’s reserves for litigation matters were $1 million. In addition, the company has accrued liabilities for settled matters of $89 million, including $75 million for settlements related to certain litigation arising out of the 2000 – 2001 California energy crisis. The uncertainties inherent in complex legal proceedings make it difficult to estimate with reasonable certainty the costs and effects of resolving legal matters. Accordingly, costs ultimately incurred may differ materially from estimated costs and could materially adversely affect the company's business, cash flows, results of operations and financial condition.

Continental Forge Settlement

The litigation that is the subject of the settlements and $75 million of accrued liabilities is frequently referred to as the Continental Forge litigation, although the settlements also include other cases. The terms of these settlements were reported previously. On July 24, 2008, the California Attorney General and the Department of Water Resources (DWR) dismissed their appeal of the final order, and the settlements are expected to become final shortly. The reserves recorded for the settlements by Sempra Energy, including SoCalGas, in 2005 fully provide for the present value of both the cash amounts to be paid in the settlements and the price discount to be provided on electricity to be delivered under the DWR contract by Sempra Generation, a business unit of Sempra Energy.

Other Natural Gas Cases

In April 2003, Sierra Pacific Resources and its utility subsidiary Nevada Power filed a lawsuit in the U.S. District Court in Nevada against major natural gas suppliers, including Sempra Energy, the Sempra Utilities and Sempra Commodities, a business unit of Sempra Energy, seeking recovery of damages alleged to aggregate in excess of $150 million (before trebling). The lawsuit alleges a conspiracy to manipulate and inflate the prices that Nevada Power had to pay for its natural gas by preventing the construction of natural gas pipelines to serve Nevada and other Western states, and reporting artificially inflated prices to trade publications. The U.S. District Court dismissed the case in November 2004, determining that the Federal Energy Regulatory Commission (FERC) had exclusive jurisdiction to resolve the claims. In September 2007, the U.S. Court of Appeals for the Ninth Circuit (Ninth Circuit Court of Appeals) reversed the dismissal and returned the case to the District Court for further proceedings.

Pending in the U.S. District Court in Nevada are five cases against Sempra Energy, Sempra Commodities, the Sempra Utilities and various other companies, alleging that energy prices were unlawfully manipulated by the reporting of artificially inflated natural gas prices to trade publications and by entering into wash trades and churning transactions, four of which also include conspiracy allegations similar to those made in the Continental Forge litigation. The court dismissed four of these actions in 2005, determining that the FERC had exclusive jurisdiction to resolve the claims. The remaining case, which includes conspiracy allegations, was stayed. In September 2007, the Ninth Circuit Court of Appeals reversed the dismissal and returned the cases to the District Court for further proceedings.

Other Litigation

In 1998, SoCalGas converted its traditional pension plan for non-union employees to a cash balance plan. In July 2005, a lawsuit was filed against the company in the U.S. District Court for the Central District of

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California alleging that the conversion unlawfully discriminated against older employees and failed to provide required disclosure of a reduction in benefits. In October 2005, the court dismissed three of the four causes of action and, in March 2006, dismissed the remaining cause of action. The Ninth Circuit Court of Appeals heard oral argument on plaintiffs' appeal of the dismissals in February 2008 and took the matter under submission.

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ITEM 2.

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion should be read in conjunction with the financial statements contained in this Form 10-Q and "Management's Discussion and Analysis of Financial Condition and Results of Operations" and "Risk Factors" contained in the company's 2007 Annual Report on Form 10-K (Annual Report).

RESULTS OF OPERATIONS

Revenues and Cost of Sales

During the three months and six months ended June 30, 2008, natural gas revenues and the cost of natural gas increased compared to the corresponding periods in 2007, primarily as a result of higher natural gas prices and volumes.

As a final decision in the 2008 General Rate Case (GRC) was not issued by the California Public Utilities Commission (CPUC) by June 30, 2008, revenues for the first six months of 2008 associated with CPUC-regulated operations were consistent with the 2007 CPUC-authorized revenue established by the 2004 Cost of Service decision. Further discussion is provided in Note 5 of the Notes to Condensed Consolidated Financial Statements herein.

Although the current regulatory framework provides that the cost of natural gas purchased for core customers be passed through to the customers on a substantially concurrent basis, SoCalGas' Gas Cost Incentive Mechanism (GCIM) allows SoCalGas to share in the savings or costs from buying natural gas for its customers below or above market-based monthly benchmarks. The mechanism permits full recovery of all costs within a tolerance band around the benchmark price. The costs or savings outside the tolerance band are shared between customers and shareholders. Further discussion is provided in Notes 1 and 9 of the Notes to Consolidated Financial Statements in the Annual Report.

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The table below summarizes natural gas volumes and revenues by customer class for the six-month periods ended June 30.

Natural Gas Sales, Transportation and Exchange

(Volumes in billion cubic feet, dollars in millions)

		Natural Gas Sales							Transportation and Exchange							Total
		Volumes			Revenue				Volumes			Revenue				Volumes			Revenue
2008:
Residential		140			$	1,810			1			$	2			141			$	1,812
Commercial and industrial		56				664			136				78			192				742
Electric generation plants		--				--			90				32			90				32
Wholesale		--				--			75				11			75				11
		196			$	2,474			302			$	123			498				2,597
Balancing accounts and other																				102
Total																			$	2,699
2007:
Residential		138			$	1,524			1			$	2			139			$	1,526
Commercial and industrial		58				546			133				100			191				646
Electric generation plants		--				--			70				24			70				24
Wholesale		--				--			69				27			69				27
		196			$	2,070			273			$	153			469				2,223
Balancing accounts and other																				126
Total																			$	2,349

Income Taxes

Income tax expense was $77 million and $82 million ($76 million and $78 million for SoCalGas) for the six months ended June 30, 2008 and 2007, respectively, and the effective income tax rates for the company were 40 percent and 42 percent (40 percent and 41 percent at SoCalGas), respectively. Income tax expense was $36 million and $41 million ($36 million and $39 million for SoCalGas) for the three months ended June 30, 2008 and 2007, respectively, and the effective income tax rates for the company were 39 percent and 42 percent (39 percent and 41 percent at SoCalGas), respectively.

The decrease in income tax expense for the three months and six months ended June 30, 2008 was due primarily to larger tax deductions in 2008 allowed for regulatory purposes.

Net Income

Net income for SoCalGas increased by $4 million (4%) in the six months ended June 30, 2008 to $114 million, and by $2 million (4%) in the three months ended June 30, 2008 to $57 million. The increase in the six months was primarily attributable to $7 million in regulatory awards in 2008 and $3 million as a result of a lower effective tax rate, partially offset by $8 million lower earnings from non-core natural gas storage in accordance with the Omnibus Gas Settlements, as discussed in Note 9 of the Notes to Consolidated Financial Statements in the Annual Report.

The increase in the three months ended June 30, 2008 was primarily due to $3 million as a result of a lower effective tax rate and $2 million in higher natural gas margins due to the elimination of revenue-sharing in 2008, net of higher operating expenses, offset by $5 million in lower earnings from non-core natural gas storage.

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CAPITAL RESOURCES AND LIQUIDITY

SoCalGas’ utility operations generally are the major source of liquidity. In addition, cash requirements may be met through the issuance of short-term and long-term debt. Cash requirements primarily consist of capital expenditures for utility plant.

At June 30, 2008, the company had $135 million in unrestricted cash and cash equivalents, and $500 million in available unused credit on its committed line at SoCalGas, which is shared with SDG&E and is discussed more fully in Note 3 of the Notes to Consolidated Financial Statements in the Annual Report. Management believes that these amounts and cash flows from operations and security issuances, combined with current cash balances, will be adequate to finance capital expenditures and meet liquidity requirements and to fund shareholder dividends and other commitments. Management continues to regularly monitor SoCalGas' ability to finance the needs of its operating, investing and financing activities in a manner consistent with its intention to maintain strong, investment-quality credit ratings.

CASH FLOWS FROM OPERATING ACTIVITIES

Net cash provided by PE's operating activities decreased by $86 million (13%) to $579 million for 2008 due to the decrease in net cash provided by SoCalGas’ operating activities, which decreased by $82 million (12%) to $576 million for 2008. The changes were primarily due to a $126 million lower decrease in accounts receivable, higher net tax payments of $78 million, a $34 million increase in net amounts due from affiliates in 2008 compared to an $18 million decrease in 2007 and a higher increase in other current assets of $17 million, offset by an $86 million higher increase in overcollected regulatory balancing accounts and a $73 million increase in accounts payable in 2008 compared to a $21 million decrease in 2007.

For the six months ended June 30, 2008, the company made contributions of a negligible amount and $9 million to the pension plan and other postretirement benefit plans, respectively.

CASH FLOWS FROM INVESTING ACTIVITIES

Net cash used in PE's investing activities increased by $1 million to $301 million for 2008. Net cash used in SoCalGas' investing activities increased by $5 million (2%) to $299 million for 2008. The changes were primarily due to an increase of $51 million in capital expenditures, offset by a $48 million lower increase in loans to affiliates.

Significant capital expenditures in 2008 are expected to include $400 million for improvements to distribution and transmission systems. These expenditures are expected to be financed by cash flows from operations and security issuances.

CASH FLOWS FROM FINANCING ACTIVITIES

Net cash used in PE's financing activities increased by $100 million (98%) to $202 million for 2008. Net cash used in SoCalGas' financing activities increased by $100 million (99%) to $201 million for 2008. The changes were due to a $100 million increase in common dividends paid in 2008 compared to 2007.

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COMMITMENTS

At June 30, 2008, there were no significant changes to the commitments that were disclosed in the Annual Report, except for an increase of $1.4 billion related to natural gas contracts at SoCalGas, of which $190 million related to the transfer of SDG&E’s natural gas supply portfolio to SoCalGas as part of the Omnibus Gas Settlements discussed in Note 9 of the Notes to Consolidated Financial Statements in the Annual Report. The future payments under these contractual commitments are expected to be $687 million for 2008, $401 million for 2009, $42 million for 2010, $30 million for 2011, $31 million for 2012 and $186 million thereafter.

FACTORS INFLUENCING FUTURE PERFORMANCE

Performance of the company will depend primarily on the ratemaking and regulatory process, natural gas industry restructuring, and the changing energy marketplace. Performance will also depend on the successful completion of capital projects that are discussed in various places in this report and in the Annual Report. As the 2008 GRC provides for fixed annual increases rather than for adjustments based on inflation indices as in the past, performance will depend on the company's ability to manage or recover in rates the effects of rising costs. Additional information is provided in Note 5 of the Notes to Condensed Consolidated Financial Statements herein and in Note 9 of the Notes to Consolidated Financial Statements in the Annual Report.

Litigation

Note 6 of the Notes to Condensed Consolidated Financial Statements herein and Note 10 of the Notes to Consolidated Financial Statements in the Annual Report describe litigation, the ultimate resolution of which could have a material adverse effect on future performance.

Industry Developments

Note 5 of the Notes to Condensed Consolidated Financial Statements herein and Note 9 of the Notes to Consolidated Financial Statements in the Annual Report describe natural gas regulation and rates, and other pending proceedings and investigations.

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

Certain accounting policies are viewed by management as critical because their application is the most relevant, judgmental and/or material to the company's financial position and results of operations, and/or because they require the use of material judgments and estimates. These accounting policies are discussed in "Management's Discussion and Analysis of Financial Condition and Results of Operations" in the Annual Report.

The company's significant accounting policies are described in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

NEW ACCOUNTING STANDARDS

Recently issued pronouncements that have had or may have a significant effect on the company's financial statements are described in Note 2 of the Notes to Condensed Consolidated Financial Statements herein.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

As of June 30, 2008, the total Value at Risk of SoCalGas' positions was not material.

ITEM 4. CONTROLS AND PROCEDURES

Company management is responsible for establishing and maintaining adequate internal control over financial reporting, as defined in Exchange Act Rules 13a-15(f). The company has designed and maintains disclosure controls and procedures to ensure that information required to be disclosed in the company's reports is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the Securities and Exchange Commission and is accumulated and communicated to the company's management, including its Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure. In designing and evaluating these controls and procedures, management recognizes that any system of controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired objectives and necessarily applies judgment in evaluating the cost-benefit relationship of other possible controls and procedures. There have been no changes in the company's internal control over financial reporting during the company's most recent fiscal quarter that have materially affected, or are reasonably likely to materially affect, the company's internal control over financial reporting.

The company evaluates the effectiveness of its internal control over financial reporting based on the framework in Internal Control--Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Under the supervision and with the participation of management, including the Chief Executive Officer and the Chief Financial Officer, the company evaluated the effectiveness of the design and operation of the company's disclosure controls and procedures as of June 30, 2008, the end of the period covered by this report. Based on that evaluation, the company's Chief Executive Officer and Chief Financial Officer concluded that the company's disclosure controls and procedures were effective at the reasonable assurance level.

PART II - OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

The Los Angeles Regional Water Quality Control Board has asserted violations of the California Water Code by SoCalGas in connection with certain maintenance activities in Los Angeles County's Sullivan Canyon. In June 2008, the board dismissed without prejudice a related lawsuit to provide an opportunity for the parties to resolve this matter without litigation. SoCalGas believes that the resolution will impose upon it fines and penalties of no more than $750,000.

Except for the matters described in Notes 5 and 6 of the Notes to Condensed Consolidated Financial Statements herein, neither the company nor its subsidiaries are party to, nor is their property the subject of, any material pending legal proceedings other than routine litigation incidental to their businesses.

ITEM 1A. RISK FACTORS

There have been no material changes from risk factors as previously disclosed in the company's 2007 Annual Report on Form 10-K.

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ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

Proposal 1: Election of directors:

At the annual meeting of shareholders on June 6, 2008, shareholders elected three directors for a one-year term expiring in 2009. The name of each nominee and the number of shares voted for and withheld from the election of each director were as follows. There were no abstentions or broker non-votes.

Nominees	Votes For	Votes Withheld
Michael R. Niggli	91,350,970	--
Debra L. Reed	91,350,970	--
Mark A. Snell	91,350,970	--

ITEM 6. EXHIBITS
Exhibit 10 - Material Contracts
10.1	Sempra Energy 2008 Long Term Incentive Plan (incorporated by reference from Appendix A to the 2008 Sempra Energy Definitive Proxy Statement, filed on April 15, 2008).
10.2	Form of Indemnification Agreement with Directors and Executive Officers (June 30, 2008 Sempra Energy Form 10-Q, Exhibit 10.2).
10.3	Form of Sempra Energy 2008 Long Term Incentive Plan, 2008 Performance-Based Restricted Stock Unit Award (June 30, 2008 Sempra Energy Form 10-Q, Exhibit 10.3).
10.4	Form of Sempra Energy 2008 Long Term Incentive Plan, 2008 Nonqualified Stock Option Agreement (June 30, 2008 Sempra Energy Form 10-Q, Exhibit 10.4).
10.5	Sempra Energy Amended and Restated Executive Life Insurance Plan (June 30, 2008 Sempra Energy Form 10-Q, Exhibit 10.6).
10.6	Sempra Energy Amendment and Restatement of the Cash Balance Restoration Plan (June 30, 2008 Sempra Energy Form 10-Q, Exhibit 10.8).
Exhibit 12 - Computation of ratios
12.1	Computation of Ratio of Earnings to Combined Fixed Charges of PE.
12.2	Computation of Ratio of Earnings to Combined Fixed Charges and Preferred Stock Dividends of SoCalGas.

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Exhibit 31 -- Section 302 Certifications
31.1	Statement of PE's Chief Executive Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.
31.2	Statement of PE's Chief Financial Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.
31.3	Statement of SoCalGas' Chief Executive Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.
31.4	Statement of SoCalGas' Chief Financial Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.
Exhibit 32 -- Section 906 Certifications
32.1	Statement of PE's Chief Executive Officer pursuant to 18 U.S.C. Sec. 1350.
32.2	Statement of PE's Chief Financial Officer pursuant to 18 U.S.C. Sec. 1350.
32.3	Statement of SoCalGas' Chief Executive Officer pursuant to 18 U.S.C. Sec. 1350.
32.4	Statement of SoCalGas' Chief Financial Officer pursuant to 18 U.S.C. Sec. 1350.

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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
	PACIFIC ENTERPRISES, (Registrant)
Date: August 7, 2008	By: /s/ Dennis V. Arriola
	Dennis V. Arriola Senior Vice President and Chief Financial Officer
	SOUTHERN CALIFORNIA GAS COMPANY, (Registrant)
Date: August 7, 2008	By: /s/ Dennis V. Arriola
	Dennis V. Arriola Senior Vice President and Chief Financial Officer

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