Unassociated Document



  
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C.  20549
 
FORM 10-K
 
(Mark One)
[X]
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
For the fiscal year ended
December 31, 2011
   
 
OR
   
[   ]
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
For the transition period from
   
to
 
     
 
Commission File No.
Exact Name of Registrants as Specified in their Charters, Address and Telephone Number
State of Incorporation
I.R.S. Employer
Identification Nos.
1-14201
SEMPRA ENERGY
California
33-0732627
 
101 Ash Street
   
 
San Diego, California 92101
   
 
(619)696-2000
   
       
1-3779
SAN DIEGO GAS & ELECTRIC COMPANY
California
95-1184800
 
8326 Century Park Court
   
 
San Diego, California 92123
   
 
(619)696-2000
   
       
1-1402
SOUTHERN CALIFORNIA GAS COMPANY
California
95-1240705
 
555 West Fifth Street
   
 
Los Angeles, California 90013
   
 
(213)244-1200
   
       
 
SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:
 
 
Title of Each Class
 
Name of Each Exchange on Which Registered
 
Sempra Energy Common Stock, without par value
 
NYSE
 
 
SDG&E Preference Stock (Cumulative)
         Without Par Value – $1.82 Series
 
SDG&E Cumulative Preferred Stock, $20 Par Value
         4.50% Series, 4.40% Series
         5.00% Series
 
 
NYSE Amex
 
 
NYSE Amex
   
SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT:
                   None



   
 
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
           
Sempra Energy
Yes
X
 
No
 
San Diego Gas & Electric Company
Yes
   
No
X
Southern California Gas Company
Yes
   
No
X
 
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.
           
Sempra Energy
Yes
   
No
X
San Diego Gas & Electric Company
Yes
   
No
X
Southern California Gas Company
Yes
   
No
X
 
Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.
           
 
Yes
X
 
No
 
 
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).
           
Sempra Energy
Yes
X
 
No
 
San Diego Gas & Electric Company
Yes
X
 
No
 
Southern California Gas Company
Yes
X
 
No
 
 
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrants’ knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.
           
 
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.
 
 
Large
accelerated filer
Accelerated filer
Non-accelerated filer
Smaller reporting company
Sempra Energy
[  X  ]
[      ]
[       ]
[      ]
San Diego Gas & Electric Company
[       ]
[      ]
[  X  ]
[      ]
Southern California Gas Company
[       ]
[      ]
[  X  ]
[      ]
 
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
           
Sempra Energy
Yes
   
No
X
San Diego Gas & Electric Company
Yes
   
No
X
Southern California Gas Company
Yes
   
No
X
           
Exhibit Index on page 50. Glossary on page 60.


 
Aggregate market value of the voting and non-voting common equity held by non-affiliates of the registrant as of June 30, 2011:
   
Sempra Energy
$12.6 billion (based on the price at which the common equity was last sold as of the last business day of the most recently completed second fiscal quarter)
San Diego Gas & Electric Company
$0
Southern California Gas Company
$0
 
Common Stock outstanding, without par value, as of February 24, 2012:
   
Sempra Energy
240,590,672 shares
San Diego Gas & Electric Company
Wholly owned by Enova Corporation, which is wholly owned by Sempra Energy
Southern California Gas Company
Wholly owned by Pacific Enterprises, which is wholly owned by Sempra Energy
 
DOCUMENTS INCORPORATED BY REFERENCE:
           
Portions of the 2011 Annual Report to Shareholders of Sempra Energy, San Diego Gas & Electric Company and Southern California Gas Company are incorporated by reference into Parts I, II and IV.
           
Portions of the Sempra Energy Proxy Statement prepared for the May 2012 annual meeting of shareholders are incorporated by reference into Part III.
 
Portions of the San Diego Gas & Electric Company and Southern California Gas Company Information Statements prepared for their June 2012 annual meetings of shareholders are incorporated by reference into Part III.
           
  



 
 
 
 


SEMPRA ENERGY FORM 10-K
SAN DIEGO GAS & ELECTRIC COMPANY FORM 10-K
SOUTHERN CALIFORNIA GAS COMPANY FORM 10-K
TABLE OF CONTENTS
 
 
Page
Information Regarding Forward-Looking Statements
6
   
PART I
   
Item 1.
Business
7
 
Description of Business
7
 
Company Websites
8
 
Government Regulation
8
 
California Natural Gas Utility Operations
11
 
Electric Utility Operations
13
 
Rates and Regulation – Utilities
19
 
Sempra Global
19
 
Environmental Matters
21
 
Executive Officers of the Registrants
22
 
Other Matters
22
Item 1A.
Risk Factors
24
Item 1B.
Unresolved Staff Comments
34
Item 2.
Properties
34
Item 3.
Legal Proceedings
35
Item 4.
Mine Safety Disclosures
35
     
PART II
   
Item 5.
Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
36
Item 6.
Selected Financial Data
37
Item 7.
Management’s Discussion and Analysis of Financial Condition and Results of Operations
37
Item 7A.
Quantitative and Qualitative Disclosures About Market Risk
37
Item 8.
Financial Statements and Supplementary Data
37
Item 9.
Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
37
Item 9A.
Controls and Procedures
37
Item 9B.
Other Information
37
     
PART III
   
Item 10.
Directors, Executive Officers and Corporate Governance
38
Item 11.
Executive Compensation
38
Item 12.
Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
38
Item 13.
Certain Relationships and Related Transactions, and Director Independence
38
Item 14.
Principal Accountant Fees and Services
38
     
     



SEMPRA ENERGY FORM 10-K
SAN DIEGO GAS & ELECTRIC COMPANY FORM 10-K
SOUTHERN CALIFORNIA GAS COMPANY FORM 10-K
TABLE OF CONTENTS (CONTINUED)
 



 
 
Page
PART IV
   
Item 15.
Exhibits and Financial Statement Schedules
39
     
Sempra Energy: Consent of Independent Registered Public Accounting Firm and Report on Schedule
40
San Diego Gas & Electric Company: Consent of Independent Registered Public Accounting Firm
41
Southern California Gas Company: Consent of Independent Registered Public Accounting Firm
42
     
Schedule I – Sempra Energy Condensed Financial Information of Parent
43
     
Signatures
 
47
Exhibit Index
50
Glossary
60
   
 

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

You should read this report in its entirety as it pertains to each respective reporting company. No one section of the report deals with all aspects of the subject matter. Separate Item 6 and 8 sections are provided for each reporting company, except for the Notes to Consolidated Financial Statements in Item 8. The Notes to Consolidated Financial Statements for all of the reporting companies are combined. All Items other than 6 and 8 are combined for the reporting companies.

 

 

INFORMATION REGARDING FORWARD-LOOKING STATEMENTS
 

We make statements in this report that are not historical fact and constitute forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Forward-looking statements are necessarily based upon assumptions with respect to the future, involve risks and uncertainties, and are not guarantees of performance. These forward-looking statements represent our estimates and assumptions only as of the filing date of this report. We assume no obligation to update or revise any forward-looking statement as a result of new information, future events or other factors.
 
In this report, when we use words such as “believes,” “expects,” “anticipates,” “plans,” “estimates,” “projects,” “contemplates,” “intends,” “depends,” “should,” “could,” “would,” “will,” “may,” “potential,” “target,” “goals,” or similar expressions, or when we discuss our guidance, strategy, plans or intentions, we are making forward-looking statements.
 
Factors, among others, that could cause our actual results and future actions to differ materially from those described in forward-looking statements include
 
§  
local, regional, national and international economic, competitive, political, legislative and regulatory conditions and developments;
 
§  
actions by the California Public Utilities Commission, California State Legislature, Federal Energy Regulatory Commission, Nuclear Regulatory Commission, California Energy Commission, California Air Resources Board, and other regulatory, governmental and environmental bodies in the United States and other countries in which we operate;
 
§  
capital markets conditions, including the availability of credit and the liquidity of our investments;
 
§  
inflation, interest and exchange rates;
 
§  
the impact of benchmark interest rates, generally U.S. Treasury bond and Moody’s A-rated utility bond yields, on our Sempra Utilities’ cost of capital;
 
§  
energy markets, including the timing and extent of changes and volatility in commodity prices;
 
§  
the availability of electric power, natural gas and liquefied natural gas, including disruptions caused by failures in the North American transmission grid, pipeline explosions and equipment failures;
 
§  
weather conditions, natural disasters, catastrophic accidents, and conservation efforts;
 
§  
risks inherent in nuclear power generation and radioactive materials storage, including the catastrophic release of such materials;
 
§  
wars, terrorist attacks and cybersecurity threats;
 
§  
business, regulatory, environmental and legal decisions and requirements;
 
§  
expropriation of assets by foreign governments and title and other property disputes;
 
§  
the status of deregulation of retail natural gas and electricity delivery;
 
§  
the timing and success of business development efforts and construction, maintenance and capital projects;
 
§  
the inability or determination not to enter into long-term supply and sales agreements or long-term firm capacity agreements;
 
§  
the resolution of litigation; and
 
§  
other uncertainties, all of which are difficult to predict and many of which are beyond our control.
 
We caution you not to rely unduly on any forward-looking statements. You should review and consider carefully the risks, uncertainties and other factors that affect our business as described in this report and other reports that we file with the Securities and Exchange Commission.
 


 
 
 
 

PART I
 

 

ITEM 1. BUSINESS
 

 
DESCRIPTION OF BUSINESS
 
We provide a description of Sempra Energy and its subsidiaries in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in the 2011 Annual Report to Shareholders (Annual Report), which is attached as Exhibit 13.1 to this report and is incorporated by reference.
 
This report includes information for the following separate registrants:
 
§  
Sempra Energy and its consolidated entities
 
§  
San Diego Gas & Electric Company (SDG&E)
 
§  
Southern California Gas Company (SoCalGas)
 
References in this report to “we,” “our,” “us,” “our company” and “Sempra Energy Consolidated” are to Sempra Energy and its consolidated entities, collectively, unless otherwise indicated by the context.  SDG&E and SoCalGas are collectively referred to as the Sempra Utilities. They are subsidiaries of Sempra Energy, and Sempra Energy indirectly owns all of the common stock and substantially all of the voting stock of each of the two companies.
 
Through December 31, 2011, Sempra Energy’s business was organized in five separately managed reportable segments consisting of SDG&E, SoCalGas, Sempra Generation, Sempra Pipelines & Storage and Sempra LNG (liquefied natural gas). Our disclosures and financial information in this Form 10-K and Annual Report reflect these five segments. Sempra Generation, Sempra Pipelines & Storage and Sempra LNG are subsidiaries of Sempra Global. Sempra Global is a holding company for most of our subsidiaries that are not subject to California utility regulation. Sempra Pipelines & Storage also owns utilities which are not included in our references to the Sempra Utilities. We provide financial information about each of these segments and about the geographic areas in which we do business in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report.
 
All references in this report to “Sempra Generation,” “Sempra Pipelines & Storage” and “Sempra LNG,” are to the respective principal business units of Sempra Global and are not intended to refer to any legal entity with the same or similar name.
 
Effective January 1, 2012, in connection with several key executive appointments made in September 2011, management realigned some of the company’s major subsidiaries to better fit its strategic direction and to enhance the management and integration of our assets. This realignment will result in a change in reportable segments in 2012, primarily to regroup the Sempra Global business units under two new operating units, Sempra U.S. Gas & Power and Sempra International. These operating units will include the following reportable segments:
 
Sempra U.S. Gas & Power
 
§  
Sempra Natural Gas
 
§  
Sempra Renewables
 
Sempra International
 
§  
Sempra Mexico
 
§  
Sempra South American Utilities
 
 
SDG&E and SoCalGas will continue to be separate reportable segments.
 
 
RBS Sempra Commodities LLP
 
Prior to 2011, our Sempra Commodities segment contained our investment in RBS Sempra Commodities LLP (RBS Sempra Commodities), which held commodities-marketing businesses previously owned by us.  Our investment in the partnership is reported on the equity method. We and The Royal Bank of Scotland plc (RBS), our partner in the joint venture, sold substantially all of the partnership’s businesses and assets in four separate transactions completed in July, November and December of 2010 and February of 2011. We discuss these transactions and other matters concerning the partnership in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report.
 
The activity in the partnership no longer meets the quantitative thresholds that require Sempra Commodities to be reported as a reportable segment under applicable accounting rules, and we do not consider the remaining wind-down activities of the partnership to be of continuing significance. As a result, effective January 1, 2011, we are reporting the former Sempra Commodities segment in Parent and Other, and have restated prior year information to be consistent with this treatment.
 
 
COMPANY WEBSITES
 
Company website addresses are:
 
Sempra Energy – http://www.sempra.com
 
SDG&E – http://www.sdge.com
 
SoCalGas – http://www.socalgas.com
 
We make available free of charge on our website our annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any amendments to those reports as soon as reasonably practicable after such material is electronically filed with or furnished to the Securities and Exchange Commission (SEC). The charters of the audit, compensation and corporate governance committees of Sempra Energy’s board of directors (the board), the board’s corporate governance guidelines, and Sempra Energy’s code of business conduct and ethics for directors and officers are posted on Sempra Energy’s website.
 
SDG&E and SoCalGas make available free of charge via a hyperlink on their websites their annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any amendments to those reports as soon as reasonably practicable after such material is electronically filed with or furnished to the SEC.
 
Printed copies of all of these materials may be obtained by writing to our Corporate Secretary at Sempra Energy, 101 Ash Street, San Diego, CA 92101-3017.
 
The information on the websites of Sempra Energy, SDG&E and SoCalGas is not part of this report or any other report that we file with or furnish to the SEC, and is not incorporated herein by reference.
 
 
GOVERNMENT REGULATION
 
The most significant government regulation affecting Sempra Energy is the regulation of the Sempra Utilities.
 
 
California Utility Regulation
 
The Sempra Utilities are regulated in California by the California Public Utilities Commission (CPUC), the California Energy Commission (CEC) and the California Air Resources Board (CARB).
 
The California Public Utilities Commission:
 
§  
consists of five commissioners appointed by the Governor of California for staggered, six-year terms.
 
§  
regulates SDG&E’s and SoCalGas’ rates and conditions of service, sales of securities, rates of return, capital structure, rates of depreciation, and long-term resource procurement, except as described below in “United States Utility Regulation.”
 
§  
has jurisdiction over the proposed construction of major new electric transmission, electric distribution, and natural gas storage, transmission and distribution facilities in California.
 
§  
conducts reviews and audits of utility performance and compliance with regulatory guidelines, and conducts investigations into various matters, such as deregulation, competition and the environment, to determine its future policies.
 
§  
regulates the interactions and transactions of the Sempra Utilities with Sempra Energy and its other affiliates.
 
We provide further discussion in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report.
 
SDG&E is also subject to regulation by the CEC, which publishes electric demand forecasts for the state and for specific service territories.  Based upon these forecasts, the CEC:
 
§  
determines the need for additional energy sources and conservation programs;
 
§  
sponsors alternative-energy research and development projects;
 
§  
promotes energy conservation programs;
 
§  
maintains a statewide plan of action in case of energy shortages; and
 
§  
certifies power-plant sites and related facilities within California.
 
The CEC conducts a 20-year forecast of available supplies and prices for every market sector that consumes natural gas in California. This forecast includes resource evaluation, pipeline capacity needs, natural gas demand and wellhead prices, and costs of transportation and distribution. This analysis is one of many resource materials used to support the Sempra Utilities’ long-term investment decisions.
 
In 2010, the State of California required certain California electric retail sellers, including SDG&E, to deliver 20 percent of their retail energy sales from renewable energy sources. The rules governing this requirement, administered by both the CPUC and the CEC, are generally known as the Renewables Portfolio Standard (RPS) Program. In December 2011, California Senate Bill 2(1X) (33% RPS Program) went into effect, superseding the previous RPS program. The 33% RPS Program requires each California utility to procure 33 percent of its annual electric energy requirements from renewable energy sources by 2020, with an average 20 percent required over the three-year period January 1, 2011 through December 31, 2013; 25 percent by December 31, 2016; and 33 percent by December 31, 2020. We discuss this requirement as it applies to SDG&E in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report.
 
Certification of a generation project by the CEC as an Eligible Renewable Energy Resource (ERR) allows the purchase of output from such generation facility to be counted towards fulfillment of the RPS Program requirements, if such purchase meets the provisions of California Senate Bill 2(1X). This may affect the demand for output from renewables projects developed by Sempra Generation, particularly from California utilities. Final certification as an ERR for Sempra Generation’s El Dorado Solar generation facility was approved in June 2009 and for its Copper Mountain Solar 1 facility in Nevada in February 2011.
 
California Assembly Bill 32, the California Global Warming Solutions Act of 2006, assigns responsibility to CARB for monitoring and establishing policies for reducing greenhouse gas (GHG) emissions. The bill requires CARB to develop and adopt a comprehensive plan for achieving real, quantifiable and cost-effective GHG emission reductions, including a statewide GHG emissions cap, mandatory reporting rules, and regulatory and market mechanisms to achieve reductions of GHG emissions. CARB is a department within the California Environmental Protection Agency, an organization which reports directly to the Governor’s Office in the Executive Branch of California State Government. We provide further discussion in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report.
 
 
United States Utility Regulation
 
The Sempra Utilities are also regulated by the Federal Energy Regulatory Commission (FERC) and the Nuclear Regulatory Commission (NRC).
 
In the case of SDG&E, the FERC regulates the interstate sale and transportation of natural gas, the transmission and wholesale sales of electricity in interstate commerce, transmission access, rates of return on transmission investment, the uniform systems of accounts, rates of depreciation and electric rates involving sales for resale.
 
In the case of SoCalGas, the FERC regulates the interstate sale and transportation of natural gas and the uniform systems of accounts.
 
The NRC oversees the licensing, construction and operation of nuclear facilities in the United States, including the San Onofre Nuclear Generating Station (SONGS), in which SDG&E owns a 20-percent interest. NRC regulations require extensive review of the safety, radiological and environmental aspects of these facilities. Periodically, the NRC requires that newly developed data and techniques be used to reanalyze the design of a nuclear power plant and, as a result, may require plant modifications as a condition of continued operation.
 
The Department of Transportation (DOT) has established regulations regarding engineering standards and operating procedures applicable for the Sempra Utilities’ natural gas transmission and distribution pipelines. The DOT has certified the CPUC to administer oversight and compliance with these regulations for the entities they regulate in California.
 
 
State and Local Regulation Within the U.S.
 
SoCalGas has natural gas franchises with the 12 counties and 233 cities in its service territory. These franchises allow SoCalGas to locate, operate and maintain facilities for the transmission and distribution of natural gas. Most of the franchises have indefinite lives with no expiration date. Some franchises have fixed expiration dates, ranging from 2012 to 2048.
 
SDG&E has
 
§  
electric franchises with the two counties and the 26 cities in its electric service territory; and
 
§  
natural gas franchises with the one county and the 18 cities in its natural gas service territory.
 
These franchises allow SDG&E to locate, operate and maintain facilities for the transmission and distribution of electricity and/or natural gas. Most of the franchises have indefinite lives with no expiration dates. Some natural gas franchises have fixed expiration dates, ranging from 2012 to 2035, and some electric franchises have fixed expiration dates that range from 2012 to 2018.
 
Sempra Generation, Sempra Pipelines & Storage and Sempra LNG have operations or development projects in Alabama, Arizona, California, Colorado, Hawaii, Indiana, Kansas, Louisiana, Mississippi, Nevada, Pennsylvania and Texas. These entities are subject to state and local laws, and to regulations in the states in which they operate.
 
Sempra Pipelines & Storage operates Mobile Gas Service Corporation (Mobile Gas), a natural gas distribution utility serving southwest Alabama that is regulated by the Alabama Public Service Commission. Sempra Pipelines & Storage also develops and operates natural gas storage facilities in Alabama, Louisiana and Mississippi and is subject to regulation in the states in which the storage facilities are located.
 
 
Other U.S. Regulation
 
In the United States, the FERC, with ratemaking authority over wholesale sales of power and the transportation and storage of natural gas in interstate commerce, and siting and permitting authority for LNG terminals, regulates Sempra Generation’s, Sempra Pipelines & Storage’s and Sempra LNG’s operations.  Sempra Pipelines & Storage also owns an interest in the Rockies Express Pipeline, a natural gas pipeline which operates in several states in the United States and is subject to regulation by the FERC.
 
The FERC may regulate rates and terms of service based on a cost-of-service approach or, in geographic and product markets determined by the FERC to be sufficiently competitive, rates may be market-based. Our LNG terminal in the United States is subject to market-based rates and terms of service. FERC-regulated rates at the following businesses are
 
§  
Sempra Generation: market-based for wholesale electricity sales
 
§  
Sempra Pipelines & Storage: cost-based and market-based for the transportation and storage of natural gas, respectively
 
§  
Sempra LNG: market-based for the receipt, storage, vaporization and liquefaction of LNG and the purchase and sale of natural gas
 
Sempra Pipelines & Storage is also subject to DOT rules and regulations regarding pipeline safety.
 
 
Foreign Regulation
 
Several of our segments operate in Mexico as follows:
 
§  
Sempra Generation owns and operates a natural gas-fired power plant in Baja California, Mexico
 
§  
Sempra Pipelines & Storage’s Mexican utilities build and operate natural gas distribution systems in Mexicali, Chihuahua, and the La Laguna-Durango zone in north-central Mexico
 
§  
Sempra Pipelines & Storage owns and operates natural gas pipelines between the U.S. border and Baja California, Mexico and Sonora, Mexico. Sempra Pipelines & Storage also owns a 50-percent interest in a joint venture with PEMEX (the Mexican state-owned oil company) that operates two natural gas pipelines and a propane system in northern Mexico
 
§  
Sempra LNG owns and operates the Energía Costa Azul LNG terminal located in Baja California, Mexico
 
These operations are subject to regulation by the Energy Regulatory Commission (Comisión Reguladora de Energía, or CRE) and by the labor and environmental agencies of city, state and federal governments in Mexico.
 
Sempra Pipelines & Storage also has two utilities in South America that are subject to laws and regulations in the localities and countries in which they operate. Chilquinta Energía S.A. (Chilquinta Energía) is an electric distribution utility serving customers in the cities of Valparaiso and Viña del Mar in central Chile. Luz del Sur S.A.A. (Luz del Sur) is an electric distribution utility in the southern zone of metropolitan Lima, Peru. These utilities serve primarily regulated customers, and their revenues are based on tariffs that are set by the National Energy Commission (Comisión Nacional de Energía, or CNE) in Chile and the Energy and Mining Investment Supervisory Body (Organismo Supervisor de la Inversión en Energía y Minería, or OSINERGMIN) of the National Electricity Office under the Ministry of Energy and Mines in Peru.  
 
 
Licenses and Permits
 
The Sempra Utilities obtain numerous permits, authorizations and licenses in connection with the transmission and distribution of natural gas and electricity and the operation and construction of related assets, some of which may require periodic renewal.
 
Our other subsidiaries are also required to obtain numerous permits, authorizations and licenses in the normal course of business. Some of these permits, authorizations and licenses require periodic renewal.
 
Sempra Generation and its subsidiaries obtain a number of permits, authorizations and licenses in connection with the construction and operation of power generation facilities, and in connection with the wholesale distribution of electricity.
 
Sempra Pipelines & Storage’s Mexican and South American subsidiaries obtain numerous permits, authorizations and licenses for their electric and natural gas distribution and transmission systems from the local governments where the service is provided. Sempra Pipelines & Storage’s U.S. operations obtain licenses and permits for natural gas storage facilities and pipelines.
 
Sempra LNG obtains licenses and permits for the operation and expansion of LNG facilities, and the import and export of LNG and natural gas.
 
We describe other regulatory matters in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report.
 
CALIFORNIA NATURAL GAS UTILITY OPERATIONS
 
SoCalGas and SDG&E sell, distribute and transport natural gas. SoCalGas purchases and stores natural gas for itself and SDG&E on a combined portfolio basis and provides natural gas storage services for others. The Sempra Utilities’ resource planning, natural gas procurement, contractual commitments, and related regulatory matters are discussed below. We also provide further discussion in the Annual Report in “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” and in Note 14 of the Notes to Consolidated Financial Statements.
 
 
Customers
 
For regulatory purposes, end-use customers are classified as either core or noncore customers. Core customers are primarily residential and small commercial and industrial customers. Noncore customers at SoCalGas consist primarily of electric generation, wholesale, large commercial, industrial, and enhanced oil recovery customers. Wholesale customers are primarily other investor-owned utilities (IOUs), including SDG&E, or municipally owned natural gas distribution systems. Noncore customers at SDG&E consist primarily of electric generation and large commercial and industrial customers.
 
Most core customers purchase natural gas directly from SoCalGas or SDG&E. While core customers are permitted to purchase directly from producers, marketers or brokers, the Sempra Utilities are obligated to provide reliable supplies of natural gas to serve the requirements of their core customers. Noncore customers are responsible for the procurement of their natural gas requirements.
 
In 2011, SoCalGas added 15,000 new natural gas customer meters at a growth rate of 0.3 percent; in 2010, it added 24,000 new meters at a growth rate of 0.4 percent. SDG&E’s active natural gas customer meters increased by approximately 5,000 and 4,300 in 2011 and 2010, respectively, representing increases of 0.6 percent and 0.5 percent, respectively. Based on forecasts of new housing starts, SoCalGas and SDG&E each expects that its new meter growth rates in 2012 will be slightly higher than those in 2011.
 
 
Natural Gas Procurement and Transportation
 
SoCalGas purchases natural gas under short-term and long-term contracts for the Sempra Utilities’ core customers. SoCalGas purchases natural gas from Canada, the U.S. Rockies and the southwestern U.S. to meet customer requirements and maintain pipeline reliability. It also purchases some California natural gas production and additional supplies delivered directly to California for its remaining requirements. Purchases of natural gas are primarily priced based on published monthly bid-week indices.
 
To ensure the delivery of the natural gas supplies to its distribution system and to meet the seasonal and annual needs of customers, SoCalGas has entered into firm interstate pipeline capacity contracts that require the payment of fixed reservation charges to reserve firm transportation rights. Pipeline companies, primarily El Paso Natural Gas Company, Transwestern Pipeline Company, Gas Transmission Northwest, Pacific Gas & Electric Company, and Kern River Gas Transmission Company, provide transportation services into SoCalGas’ intrastate transmission system for supplies purchased by SoCalGas or its transportation customers from outside of California. The FERC regulates the rates that interstate pipeline companies may charge for natural gas and transportation services.
 
SoCalGas has natural gas transportation contracts with various interstate pipelines. These contracts expire on various dates between 2012 and 2027.
 
 
Natural Gas Storage
 
SoCalGas provides natural gas storage services for core, noncore and non-end-use customers. The Sempra Utilities’ core customers are allocated a portion of SoCalGas’ storage capacity. SoCalGas offers the remaining storage capacity for sale to others through an open bid process. The storage service program provides opportunities for these customers to purchase and store natural gas when natural gas costs are low, usually during the summer, thereby reducing purchases when natural gas costs are expected to be higher. This program allows customers to better manage their natural gas procurement and transportation needs.
 
 
Demand for Natural Gas
 
Growth in the demand for natural gas largely depends on the health and expansion of the Southern California economy, prices of alternative energy products, environmental regulations, renewable energy, legislation, and the effectiveness of energy efficiency programs. External factors such as weather, the price of electricity, electric deregulation, the use of hydroelectric power, development of renewable energy resources, development of new natural gas supply sources, and general economic conditions can also result in significant shifts in market price, which may in turn impact demand.
 
The Sempra Utilities face competition in the residential and commercial customer markets based on customers’ preferences for natural gas compared with other energy products. In the noncore industrial market, some customers are capable of securing alternate fuel supplies from other suppliers which can affect the demand for natural gas. The Sempra Utilities’ ability to maintain their respective industrial market shares is largely dependent on the relative spread between delivered energy prices.

Natural gas demand for electric generation within Southern California competes with electric power generated throughout the western U.S. Natural gas transported for electric generating plant customers may be affected by the growth in renewable generation, the addition of more efficient gas technologies and to the extent that regulatory changes and electric transmission infrastructure investment divert electric generation from the Sempra Utilities’ respective service areas. The demand may also fluctuate due to volatility in the demand for electricity and the availability of competing supplies of electricity such as hydro-electric generation and other renewable energy sources. We provide additional information regarding the electric industry in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report.
 
The natural gas distribution business is seasonal, and revenues generally are greater during the winter heating months. As is prevalent in the industry, SoCalGas injects natural gas into storage during the summer months (usually April through October) for withdrawal from storage during the winter months (usually November through March) when customer demand is higher.
 
 
ELECTRIC UTILITY OPERATIONS
 
 
SDG&E
 
 
Customers
 
SDG&E’s service area covers 4,100 square miles. At December 31, 2011, SDG&E had 1.4 million customer meters consisting of:
 
§  
1,238,900 residential
 
§  
147,700 commercial
 
§  
500 industrial
 
§  
2,100 street and highway lighting
 
§  
4,900 direct access
 
SDG&E’s active electric customer meters increased by approximately 8,000 and 7,000 in 2011 and 2010, respectively, representing increases of 0.6 percent and 0.5 percent, respectively. SDG&E expects the number of active meters to increase in 2012 by approximately 9,700, representing an increase of 0.7 percent.
 
Resource Planning and Power Procurement
 
SDG&E’s resource planning, power procurement and related regulatory matters are discussed in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and in Notes 14 and 15 of the Notes to Consolidated Financial Statements in the Annual Report.
 
 
Electric Resources
 
The supply of electric power available to SDG&E for resale is based on CPUC-approved purchased-power contracts currently in place with its various suppliers, its fully owned generating facilities, its 20-percent ownership interest in SONGS and purchases on a spot basis. This supply as of December 31, 2011 is as follows:

 
SDG&E ELECTRIC RESOURCES
Supplier
 
Source
 
Expiration date
Megawatts (MW)
PURCHASED-POWER CONTRACTS(1):
 
 
 
 
 
 
Department of Water Resources (DWR)-
 
 
 
 
 
 
     allocated contracts:
 
 
 
 
 
 
 
Sunrise Power Co. LLC
 
Natural gas
 
2012 
 
 570 
 
Other (2 contracts)
 
Wind
 
2013 
 
 104 
 
    Total
 
 
 
 
 
 674 
Other contracts with Qualifying Facilities (QFs)(2):
 
 
 
 
 
 
 
Applied Energy Inc.
 
Cogeneration
 
2019 
 
 114 
 
Yuma Cogeneration
 
Cogeneration
 
2024 
 
 57 
 
Goal Line Limited Partnership
 
Cogeneration
 
2025 
 
 50 
 
Other (10 contracts)
 
Cogeneration
 
2012 and thereafter
 
 37 
 
    Total
 
 
 
 
 
 258 
Other contracts with renewable sources:
 
 
 
 
 
 
 
NaturEner
 
Wind
 
2023 to 2024
 
 210 
 
Oasis Power Partners
 
Wind
 
2019 
 
 60 
 
Kumeyaay
 
Wind
 
2025 
 
 50 
 
Iberdrola Renewables
 
Wind
 
2018 
 
 25 
 
WTE/FPL
 
Wind
 
2018 
 
 17 
 
Covanta Delano
 
Biomass
 
2017 
 
 49 
 
Blue Lake Power
 
Biomass
 
2020 
 
 11 
 
Calpine Geysers
 
Geothermal
 
2014 
 
 25 
 
Southern California Edison(3)
 
Various
 
2013 
 
 29 
 
Silicon Valley Power
 
Geothermal
 
2012 
 
 40 
 
Other (14 contracts)
 
Bio-gas/Hydro/Wind
 
2012 to 2031
 
 53 
 
    Total
 
 
 
 
 
 569 
Other long-term and tolling contracts(4):
 
 
 
 
 
 
 
Otay Mesa Energy Center LLC
 
Natural gas
 
2019 
 
 603 
 
Orange Grove Energy L.P.
 
Natural gas
 
2035 
 
 100 
 
El Cajon Energy, LLC
 
Natural gas
 
2035 
 
 49 
 
Portland General Electric Company (PGE)
 
Coal
 
2013 
 
 89 
 
EnerNOC
 
Demand response/
 
 
 
 
 
 
 
Distributed generation
 
2016 
 
 25 
 
    Total
 
 
 
 
 
 866 
Total contracted
 
 
 
 
 
 2,367 
 
 
 
 
 
 
 
 
GENERATION:
 
 
 
 
 
 
 
Palomar Energy Center
 
Natural gas
 
 
 
 560 
 
SONGS
 
Nuclear
 
 
 
 430 
 
Miramar I and II Energy Center
 
Natural gas
 
 
 
 96 
 
Desert Star Energy Center
 
Natural gas
 
 
 
 495 
 
Cuyamaca Peak Energy Plant(3)
 
Natural gas
 
 
 
 42 
Total generation
 
 
 
 
 
 1,623 
TOTAL CONTRACTED AND GENERATION
 
 
 
 
 
 3,990 
(1)
Contracts covering 2012 - 2035.
(2)
A QF is a generating facility which meets the requirements for QF status under the Public Utility Regulatory Policies Act of 1978. It includes cogeneration facilities, which produce electricity and another form of useful thermal energy (such as heat or steam) used for industrial, commercial, residential or institutional purposes. It also includes small power production facilities, which are generating facilities whose primary energy source is renewable (hydro, wind, solar, etc.), biomass, waste, or geothermal resources. Small power production facilities are generally limited in size to 80 MW.
(3)
Effective January 1, 2012.
(4)
Tolling contracts are purchased-power agreements under which we provide the fuel for generation to the energy supplier.
 
Under the contract with PGE, SDG&E pays a capacity charge plus a charge based on the amount of energy received and/or PGE’s non-fuel costs. Costs under most of the contracts with QFs are based on SDG&E’s avoided cost. Charges under the remaining contracts are for firm and as-available energy, and are based on the amount of energy received or are tolls based on available capacity. The prices under these contracts are based on the market value at the time the contracts were negotiated.
 
 
Natural Gas Supply
 
SDG&E buys natural gas under short-term contracts for its Palomar, Miramar, Desert Star and Cuyamaca Peak generating facilities and for the Otay Mesa Energy Center LLC, Orange Grove Energy L.P., and El Cajon Energy, LLC tolling contracts. Purchases are from various southwestern U.S. suppliers and are primarily priced based on published monthly bid-week indices. SDG&E’s natural gas is typically delivered from southern California border receipt points to the SoCal CityGate pool via backbone transmission system rights which expire on September 30, 2014.  The natural gas is then delivered from the SoCal CityGate pool to the generating facilities through SoCalGas’ pipelines in accordance with a transportation agreement that expires on May 31, 2012. SDG&E has also contracted with SoCalGas for natural gas storage from April 1, 2011 to March 31, 2012.
 
SDG&E also buys natural gas as the California DWR’s limited agent for the DWR-allocated contracts. Most of the natural gas deliveries for the DWR-allocated contracts are transported through the Kern River Gas Transmission Pipeline under a long-term transportation agreement. The DWR is financially responsible for the costs of gas and transportation.
 
 
SONGS
 
SDG&E has a 20-percent ownership interest in SONGS, which is located south of San Clemente, California. SONGS consists of two operating nuclear generating units. The city of Riverside owns 1.79 percent and Southern California Edison Company (Edison), the operator of SONGS, owns the remaining interest.
 
The two units began commercial operation in August 1983 and April 1984, respectively. SDG&E’s share of the capacity from the two units is 430 MW.
 
A third unit was removed from service in November 1992. Decommissioning of that unit is largely complete, with the remaining work to be done in the future when the remaining two units are decommissioned. Its spent nuclear fuel is being stored on site in an independent spent fuel storage installation (ISFSI) licensed by the NRC.
 
SDG&E has fully recovered the capital invested through December 31, 2003 in SONGS and earns a return only on subsequent capital additions, including SDG&E’s share of costs associated with the steam generator replacement project, completed in 2011.
 
We provide additional information concerning the SONGS units and nuclear decommissioning below in “Environmental Matters” and in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and Notes 6, 14 and 15 of the Notes to Consolidated Financial Statements in the Annual Report.
 
 
Nuclear Fuel Supply
 
The nuclear fuel supply cycle includes materials and services performed by others under various contracts that extend through 2020. Fuel supply contracts are index-priced and provide nuclear fuel through 2022, the expiration of SONGS’ NRC license.
 
Spent fuel from SONGS is being stored on site in both the ISFSI and spent fuel pools. With the completion of the current phase of decommissioning, the site has adequate space to build ISFSI storage capacity through 2022. Pursuant to the Nuclear Waste Policy Act of 1982, SDG&E entered into a contract with the U.S. Department of Energy (DOE) for spent-fuel disposal. Under the agreement, the DOE is responsible for the ultimate disposal of spent fuel from SONGS. SDG&E pays the DOE a disposal fee of $1.00 per megawatt-hour of net nuclear generation, or $3 million per year. It is uncertain when the DOE will begin accepting spent fuel from any nuclear generation facility.
 
We provide additional information concerning nuclear fuel costs and the storage and movement of spent fuel in Notes 6 and 15, respectively, of the Notes to Consolidated Financial Statements in the Annual Report.
 
 
Power Pool
 
SDG&E is a participant in the Western Systems Power Pool, which includes an electric-power and transmission-rate agreement with utilities and power agencies located throughout the United States and Canada. More than 300 investor-owned and municipal utilities, state and federal power agencies, energy brokers and power marketers share power and information in order to increase efficiency and competition in the bulk power market. Participants are able to make power transactions on standardized terms, including market-based rates, preapproved by the FERC.
 
 
Transmission Arrangements
 
SDG&E’s 500-kilovolt (kV) Southwest Powerlink transmission line, which is shared with Arizona Public Service Company and Imperial Irrigation District, extends from Palo Verde, Arizona to San Diego, California. SDG&E’s share of the line is 1,162 MW, although it can be less under certain system conditions.
 
Mexico’s Baja California system is connected to SDG&E’s system via two 230-kV interconnections with combined capacity of 408 MW in the north to south direction and 800 MW in the south to north direction, although it can be less under certain system conditions.
 
Edison’s transmission is connected to SDG&E’s system at SONGS via five 230-kV interconnections with firm capacity of 2,500 MW, although it can be less under certain system conditions.
 
 
SDG&E’s Sunrise Powerlink, a 117-mile, 500-kV transmission line project that is designed to deliver up to 1,000 MW of energy from the Imperial Valley to the San Diego region, received approval from the CPUC in December 2008, the Bureau of Land Management in January 2009 and the U.S. Forest Service in July 2010. SDG&E commenced construction in the fall of 2010 and expects the line to be in commercial operation in the second half of 2012. We provide further discussion in Note 15 of the Notes to Consolidated Financial Statements in the Annual Report.
 
 
Transmission Access
 
The National Energy Policy Act governs procedures for requests for transmission service. The FERC approved the California IOUs transfer of operation and control of their transmission facilities to the Independent System Operator in 1998. We provide additional information regarding transmission issues in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report.
 
 
Chilquinta Energía
 
 
Customers
 
Chilquinta Energía is an electric distribution utility serving approximately 600,000 customers in the cities of Valparaiso and Viña del Mar in central Chile, with a main service area covering 4,400 square miles. At December 31, 2011, its customers consisted of:
 
§  
563,400 residential
 
§  
35,400 commercial
 
§  
1,400 industrial
 
§  
4,800 street and highway lighting
 
§  
4,400 agricultural
 

In Chile, customers are also classified as regulated and non-regulated customers depending on consumption. Regulated customers are those whose consumption is less than 500 kW. Non-regulated customers are those whose consumption is greater than 2,000 kW. Customers with consumption between 500 kW and 2,000 kW may choose to be classified as regulated or non-regulated. Non-regulated customers can buy power from other sources, such as directly from the generator.
 
In 2011, Chilquinta Energía added 16,000 new customers at a growth rate of three percent. Chilquinta Energía expects that its customer growth rate in 2012 will be comparable to that in 2011.
 
 
Electric Resources
 
The supply of electric power available to Chilquinta Energía comes from power purchase contracts currently in place with its various suppliers and its generating facilities. This supply as of December 31, 2011 is as follows:
 
CHILQUINTA ENERGÍA ELECTRIC RESOURCES
Supplier
 
Source(2)
Expiration date
Megawatts (MW)
PURCHASED-POWER CONTRACTS(1):
 
 
 
 
 
 
 
Endesa
 
Thermal
 
2020 to 2024
 
31 
 
Gener
 
Thermal
 
2023 to 2024
 
121 
 
Tecnored
 
Thermal
 
2012 to 2013
 
 
    Total
 
 
 
 
 
156 
 
 
 
 
 
 
 
 
 
Endesa
 
Hydro
 
2020 to 2024
 
169 
 
Gener
 
Hydro
 
2023 to 2024
 
56 
 
    Total
 
 
 
 
 
225 
 
 
 
 
 
 
 
 
Endesa
 
Wind
 
2020 to 2024
 
Total contracted
 
 
 
 
 
384 
 
 
 
 
 
 
 
 
GENERATION:
 
 
 
 
 
 
 
Small generation plants(3)
 
Thermal
 
 
 
TOTAL CONTRACTED AND GENERATION
 
 
 
 
 
392 
(1)
Contracts covering 2012 - 2024.
(2)
Contracts with fuel sources that include natural gas, coal or diesel are collectively referred to as thermal.
(3)
Chilquinta Energía has a long-term contract with Compañía de Petróleos de Chile Copec S.A. that supplies diesel fuel to five small generation plants using trucks from different stations throughout the region.
 
Power Generation System
 
The Centers for Economic Load Dispatch (Centros de Despacho Económico de Carga, or CDEC) are private organizations in charge of coordinating the operation of the electricity system.  Each interconnected system is subject to its own CDEC, hence there is a CDEC-SIC (Sistema Interconectado Central, Central Interconnected System) and CDEC-SING (Sistema Interconectado del Norte Grande, Northern Interconnected System) for the central and the northern interconnected system, respectively.  Chilquinta Energía operates within CDEC-SIC.
 
 
Transmission System and Access
 
Chile’s transmission system is divided into two parts, main transmission (sistema de transmisión troncal) and the sub-transmission (sistema de subtransmisión). In Chile, main transmission lines must be greater than or equal to 220 kV. Chilquinta Energía uses the company Transelec for all of its main transmission. In general, sub-transmission systems operate at voltage levels greater than 23 kV and lower than or equal to 110 kV. Sub-transmission systems, including those owned by Chilquinta Energía, are comprised of infrastructure that is interconnected to the electricity system and geared exclusively toward supplying non-regulated or regulated end-users located in the distribution service area.
 
 
Luz del Sur
 
Customers
 
Luz del Sur is an electric distribution utility serving approximately 900,000 customers in the southern zone of metropolitan Lima, Peru, with a main service area covering 1,160 square miles. At December 31, 2011, its customers consisted of:
 
§  
859,900 residential
 
§  
56,200 commercial
 
§  
3,500 industrial
 
§  
4,800 street and highway lighting
 
§  
1,200 agricultural
 
In Peru, customers are also classified as regulated and non-regulated customers depending on consumption. Regulated customers are those whose consumption is less than 200 kW and their energy supply is considered public service. Customers with consumption between 200 kW and 2,500 kW may choose to be classified as regulated or non-regulated.
 
In 2011, Luz del Sur added 35,000 new customers at a growth rate of four percent. Luz del Sur expects that its customer growth rate in 2012 will be comparable to that in 2011.
 
 
Electric Resources
 
The supply of electric power available to Luz del Sur comes from power purchase contracts currently in place with various suppliers, as well as purchases made on a spot basis. This supply as of December 31, 2011 is as follows:
 
LUZ DEL SUR ELECTRIC RESOURCES
Supplier
 
Source(2)
 
Expiration date
Megawatts (MW)
PURCHASED-POWER CONTRACTS(1):
 
 
 
 
 
 
Bilateral contracts:
 
 
 
 
 
 
 
SN Power (ex Electroandes)
 
Hydro
 
2012 
 
60 
 
Celepsa
 
Hydro
 
2013 
 
70 
 
Eepsa S.A.
 
Thermal
 
2013 
 
20 
 
Edegel S.A.A.
 
Hydro/Thermal
 
2013 
 
52 
 
Chinango S.A.C.
 
Hydro
 
2013 
 
 
Electroperú S.A.
 
Hydro/Thermal
 
2012 
 
50 
 
Egasa
 
Hydro/Thermal
 
2012 
 
50 
 
    Total
 
 
 
 
 
305 
Auction contracts:
 
 
 
 
 
 
 
Edegel S.A.A.
 
Hydro/Thermal
 
2012 to 2013
 
166 
 
EnerSur S.A.
 
Hydro/Thermal
 
2012 
 
226 
 
Kallpa Generación S.A.
 
Thermal
 
2013 
 
81 
 
Chinango S.A.C.
 
Hydro
 
2013 
 
12 
 
Termoselva S.R.L.
 
Thermal
 
2013 
 
54 
 
DE-Egenor S. en C. por A.
 
Hydro/Thermal
 
2013 
 
10 
 
Eepsa S.A.
 
Thermal
 
2013 
 
 
    Total
 
 
 
 
 
556 
TOTAL CONTRACTED
 
 
 
 
 
861 
(1)
Contracts covering 2012 - 2013.
(2)
Contracts with fuel sources that include natural gas, coal or diesel are collectively referred to as thermal.
 
Power Generation System
 
The Sistema Eléctrico Interconectado Nacional (SEIN) is the Peruvian national interconnected system.  Peru also has several isolated regional and smaller systems that provide electricity to specific areas. The OSINERGMIN is an autonomous public regulatory entity that controls and enforces compliance with legal and technical regulations related to electrical activities, sets tariffs and supervises the bidding processes required by distribution companies to purchase energy from generators.  

The Committee of Economic Operation of the System (Comité de Operación Económica del Sistema Interconectado Nacional, or COES) coordinates the operation and dispatch of electricity of the SEIN, and manages the short-term market. The COES oversees generation, transmission and distribution companies, as well unregulated customers with a demand higher than 200 kW.
 
Transmission System and Access
 
Transmission lines in Peru are divided into principal and secondary systems. The principal system lines are accessible by all generators and allow the flow of energy through the national grid. The secondary system lines connect principal transmission with the network of distribution companies or connect directly to certain final customers. The transmission company receives tariff revenues and collects tolls based on a charge per unit of electricity.
 
 
RATES AND REGULATION – UTILITIES
 
We provide information concerning rates and regulation applicable to the Sempra Utilities and Sempra Pipelines & Storage’s utilities in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and in Notes 1 and 14 of the Notes to Consolidated Financial Statements in the Annual Report.
 
 
SEMPRA GLOBAL
 
Sempra Global is a holding company for most of our subsidiaries that are not subject to California utility regulation. Sempra Global includes Sempra Generation, Sempra Pipelines & Storage and Sempra LNG. In addition to the discussion of Sempra Pipelines and Storage’s South American utilities above, we provide descriptions of these business units and information concerning their operations under “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and in Notes 1, 3, 4, 15, and 16 of the Notes to Consolidated Financial Statements in the Annual Report.
 
 
Competition
 
Sempra Energy’s non-utility businesses are among many others in the energy industry providing similar products and services. They are engaged in highly competitive activities that require significant capital investments and highly skilled and experienced personnel. Many of their competitors may have significantly greater financial, personnel and other resources than Sempra Global.
 
Sempra Generation
 
For sales of non-contracted power, Sempra Generation is subject to competition from energy marketers, utilities, industrial companies and other independent power producers. For a number of years, natural gas has been the fuel of choice for new power generation facilities for economic, operational and environmental reasons. While natural gas-fired facilities will continue to be an important part of the nation’s generation portfolio, some regulated utilities are now constructing units powered by renewable resources, often with subsidies or under legislative mandate. These utilities may have a lower cost of capital than most independent power producers and often are able to recover fixed costs through rate base mechanisms. This recovery allows them to build, buy and upgrade generation without relying exclusively on market clearing prices to recover their investments.
 
When Sempra Generation sells power not subject to long-term contract commitments, it is exposed to market fluctuations in prices based on a number of factors, including the amount of capacity available to meet demand, the price and availability of fuel, and the presence of transmission constraints. Additionally, generation from Sempra Generation’s renewable energy assets is exposed to fluctuations in naturally occurring conditions such as wind, weather and hours of sunlight. Some of Sempra Generation’s competitors, such as electric utilities and generation companies, have their own generation capacity, including natural gas, coal and nuclear generation.  These companies, generally larger than Sempra Generation, may have a lower cost of capital and may have competitive advantages as a result of their scale and the location of their generation facilities.
 
Sempra Generation’s competitors include
 
§ Calpine
 
§ GenOn Energy
 
§ Dynegy
 
§ NextEra Energy Resources
 
§ Edison Mission Energy
 
§ NRG Energy
 

 
Sempra Pipelines & Storage
 
Within its market area, Sempra Pipelines & Storage’s natural gas storage facilities and pipelines compete with other regulated and unregulated storage facilities and pipelines. It competes primarily on the basis of price (in terms of storage and transportation fees), available capacity, and connections to downstream markets.
 
Sempra Pipelines & Storage’s competitors include
 
§ AES Corporation
 
§ Boardwalk Pipeline Partners
 
§ Duke Energy
 
§ El Paso
 
§ Endesa
 
§ Energy Transfer Partners
 
§ Enterprise Product Partners
 
§ Iberdrola Renewables (Enstor)
 
§ Iberdrola
 
§ Kinder Morgan
 
§ Plains All-American
 
§ Spectra Energy
 
§ TransCanada
 
§ The Williams Companies
 
§ Various independent midstream asset developers
 
 
 
Sempra LNG
 
New supplies to meet North America’s natural gas demand may be developed from a combination of the following sources:
 
§  
existing producing basins in the United States, Canada and Mexico;
 
§  
frontier basins in Alaska, Canada, and offshore North America;
 
§  
areas currently restricted from exploration and development due to public policies, such as areas in the Rocky Mountains and offshore Atlantic, Pacific and Gulf of Mexico coasts;
 
§  
previously inaccessible or uneconomic natural gas reserves through hydraulic fracturing (natural gas recovery from shale formations) and other new exploration, drilling and production techniques;
 
§  
LNG imported into LNG terminals in operation or under development in the United States, Canada and Mexico; and
 
§  
biogas recovery from landfills and livestock operations.
 
In addition, the demand for energy currently met by natural gas could be met by other energy forms such as coal, hydroelectric, oil, wind, solar, geothermal, biomass and nuclear energy. Sempra LNG will, therefore, face competition from companies that supply each of these energy sources.
 
Sempra LNG currently competes with other companies that operate LNG receiving terminals and purchase and sell LNG. As of December 31, 2011, there were 14 existing and operating LNG receipt terminals in North America. There is one additional LNG receipt terminal currently under construction in North America. Worldwide, there are 87 existing and operating LNG receipt terminals in 25 countries. There are also other proposed LNG receipt terminals worldwide with which, if developed, Sempra LNG would compete to be the most economical delivery point for LNG supply of both long-term contracted and spot volumes.
 
 
Sempra LNG’s major domestic and international competitors include the following companies and their related LNG affiliates:
 
§ BG
 
§ Excelerate Energy
 
§ BP
 
§ Gas Natural Fenosa
 
§ Cheniere Energy
 
§ GDF Suez
 
§ Chevron
 
§ OAO Gazprom
 
§ ConocoPhillips
 
§ Repsol
 
§ Dominion Resources
 
§ Royal Dutch Shell
 
§ El Paso
 
§ Southern Union
 
§ Eni
 
§ Statoil
 
 
ENVIRONMENTAL MATTERS
 
We discuss environmental issues affecting us in Notes 14 and 15 of the Notes to Consolidated Financial Statements in the Annual Report. You should read the following additional information in conjunction with those discussions.
 
 
Hazardous Substances
 
In 1994, the CPUC approved the Hazardous Waste Collaborative mechanism, allowing California’s IOUs to recover hazardous waste cleanup costs for certain sites, including those related to certain Superfund sites. This mechanism permits the Sempra Utilities to recover in rates 90 percent of hazardous waste cleanup costs and related third-party litigation costs, and 70 percent of the related insurance-litigation expenses. In addition, the Sempra Utilities have the opportunity to retain a percentage of any recoveries from insurance carriers and other third parties to offset the cleanup and associated litigation costs not recovered in rates.
 
At December 31, 2011, we had accrued estimated remaining investigation and remediation liabilities of $0.6 million at SDG&E and $23.4 million at SoCalGas, both related to hazardous waste sites for which the Hazardous Waste Collaborative mechanism authorizes us to recover 90 percent of the costs. The accruals include costs for numerous locations, most of which had been manufactured-gas plants. This estimated cost excludes remediation costs of $1 million associated with SDG&E’s former fossil-fuel power plants and other locations for which the cleanup costs are not being recovered in rates. We believe that any costs not ultimately recovered through rates, insurance or other means will not have a material adverse effect on the consolidated results of operations, cash flows or financial condition of Sempra Energy, SDG&E or SoCalGas.
 
We record estimated liabilities for environmental remediation when amounts are probable and estimable. In addition, we record amounts authorized to be recovered in rates under the Hazardous Waste Collaborative mechanism as regulatory assets.
 
 
Air and Water Quality
 
The electric and natural gas industries are subject to increasingly stringent air-quality and greenhouse gas standards, such as those established by the United States Environmental Protection Agency (EPA) and the CARB. We discuss these standards in “Government Regulation – California Utility Regulation” above. The Sempra Utilities generally recover in rates the costs to comply with these standards.
 
In connection with the issuance of operating permits, SDG&E and the other owners of SONGS have an agreement with the California Coastal Commission to mitigate environmental impacts to the marine environment attributed to the cooling-water discharge from SONGS. SDG&E’s share of the mitigation costs is estimated to be $55 million, of which $38 million had been incurred through December 31, 2011, and $17 million is accrued for the remaining costs through 2050. In 2008, an artificial kelp reef project was completed. The remaining costs are to complete a wetlands project and maintain both projects through 2050.
 
 
   EXECUTIVE OFFICERS OF THE REGISTRANTS
 
 
   Sempra Energy
 
Name
Age(1)
Position(1)
Donald E. Felsinger
64
Executive Chairman
Debra L. Reed
55
Chief Executive Officer
Mark A. Snell
55
President
Javade Chaudhri
59
Executive Vice President and General Counsel
Joseph A. Householder
56
Executive Vice President, Chief Financial Officer and Chief Accounting Officer
G. Joyce Rowland
57
Senior Vice President – Human Resources, Diversity and Inclusion
(1) Ages and positions are as of February 28, 2012.

 
Each executive officer has been an officer of Sempra Energy or its subsidiaries for more than the last five years.
 
 
SDG&E and SoCalGas
 
Name
Age(1)
Position(1)
SAN DIEGO GAS & ELECTRIC COMPANY
Jessie J. Knight, Jr.
61
Chairman and Chief Executive Officer
Michael R. Niggli
62
President and Chief Operating Officer
James P. Avery
55
Senior Vice President – Power Supply
J. Chris Baker
52
Senior Vice President – Support Services and Chief Information Officer
Lee Schavrien
57
Senior Vice President – Finance, Regulatory and Legislative Affairs
W. Davis Smith
62
Senior Vice President and General Counsel
Robert M. Schlax
56
Vice President, Controller, Chief Financial Officer, Chief Accounting Officer and Treasurer
     
SOUTHERN CALIFORNIA GAS COMPANY
Michael W. Allman
51
Chairman, President and Chief Executive Officer
Anne S. Smith
58
Chief Operating Officer
J. Chris Baker
52
Senior Vice President – Support Services and Chief Information Officer
Erbin B. Keith
51
Senior Vice President – External Affairs and General Counsel
Lee Schavrien
57
Senior Vice President – Finance, Regulatory and Legislative Affairs
Robert M. Schlax
 
56
 
Vice President, Controller, Chief Financial Officer, Chief Accounting Officer and Treasurer
(1) Ages and positions are as of February 28, 2012.

 
Each executive officer of SDG&E and SoCalGas has been an officer or employee of Sempra Energy or its subsidiaries for more than the last five years.
 
 
OTHER MATTERS
 
 
Employees of Registrants
 
As of December 31, each company had the following number of employees:
 
 
December 31,
 
2011 
2010 
Sempra Energy Consolidated
 
 17,483 
 
 13,504 
SDG&E
 
 5,008 
 
 4,970 
SoCalGas
 
 7,370 
 
 7,067 
 
 
Labor Relations
 
 
SoCalGas
 
Field, technical and most clerical employees at SoCalGas are represented by the Utility Workers Union of America or the International Chemical Workers Union Council (collectively “Union”) under a single collective bargaining agreement. The collective bargaining agreement for these employees covering wages, hours, working conditions, and medical and other benefit plans expired on October 14, 2011, with SoCalGas and the Union agreeing to continue operating under the terms and conditions of the expired contract while negotiating a new agreement. A tentative agreement was reached between SoCalGas and Union leadership on January 29, 2012, which is subject to ratification by the membership of the Union. SoCalGas anticipates this ratification may occur either late first or early second quarter of 2012.
 
 
SDG&E
 
Field employees and some clerical and technical employees at SDG&E are represented by the International Brotherhood of Electrical Workers. Provisions of the collective bargaining agreement for these employees covering wages are in effect through August 31, 2014 and through August 31, 2015, for hours and working conditions. For these same employees, the agreement covering pension and savings plan benefits is in effect through December 4, 2012, and the agreement covering health and welfare benefits is in effect through December 31, 2013.
 
 
Luz del Sur
 
Field, technical and administrative employees at Luz del Sur representing 39 percent of the total workforce are represented by the Unified Trade Union of Electricity Workers of Lima and Callao, and the Trade Union of Employees of Electrolima. The collective bargaining agreement covering these employees is also extended to 118 nonrepresented employees. It covers wages, working conditions, and medical and other benefit plans and is in effect through December 31, 2012.
 
 
Chilquinta Energía 
 
Field, technical and administrative employees at Chilquinta Energía and its subsidiaries are represented by Labor Union Number 1 Chilquinta Energía, Litoral Labor Union, and Tecnored Labor Union Number 1. The collective bargaining agreements for employees represented by these unions cover wages, hours, working conditions and medical and other benefit plans and are in effect through various dates in 2013.
 
 
Professional employees at Chilquinta Energía are represented by Group of University Graduates of Chilquinta Energía. The collective bargaining agreement for these employees covers wages, hours, working conditions and medical and other benefit plans and is in effect through August 31, 2013.
 
 
 

ITEM 1A.  RISK FACTORS
 

When evaluating our company and its subsidiaries, you should consider carefully the following risk factors and all other information contained in this report. These risk factors could affect our actual results and cause such results to differ materially from those expressed in any forward-looking statements made by us or on our behalf. Other risks and uncertainties, in addition to those that are described below, may also materially impair our business operations. If any of the following occurs, our business, cash flows, results of operations and financial condition could be materially harmed. In addition, the trading price of our securities could substantially decline due to the occurrence of any of these risks. These risk factors should be read in conjunction with the other detailed information concerning our company set forth in the Notes to Consolidated Financial Statements and in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in the Annual Report.
 
Sempra Energy’s cash flows, ability to pay dividends and ability to meet its debt obligations largely depend on the performance of its subsidiaries.
 
Sempra Energy’s ability to pay dividends and meet its debt obligations depends almost entirely on cash flows from its subsidiaries and, in the short term, its ability to raise capital from external sources. In the long term, cash flows from the subsidiaries depend on their ability to generate operating cash flows in excess of their own capital expenditures and long-term debt obligations. In addition, the subsidiaries are separate and distinct legal entities and could be precluded from making such distributions under certain circumstances, including, without limitation, as a result of legislation, regulation, court order, contractual restrictions or in times of financial distress.
 
Our businesses may be materially adversely affected by conditions in the financial markets and economic conditions generally.
 
Our businesses are capital intensive and we rely significantly on long-term debt to fund a portion of our capital expenditures and refund outstanding debt, and on short-term borrowings to fund a portion of day-to-day business operations.
 
The credit markets and financial services industry have experienced a period of extreme world-wide turmoil characterized by the bankruptcy, failure, collapse or sale of many financial institutions and by extraordinary levels of government intervention and proposals for further intervention and additional regulation.
 
Limitations on the availability of credit and increases in interest rates or credit spreads may materially adversely affect our liquidity, results of operations and financial condition, as well as our ability to meet contractual and other commitments. In difficult credit markets, we may find it necessary to fund our operations and capital expenditures at a higher cost or we may be unable to raise as much funding as we need to support business activities. This could cause us to reduce capital expenditures and could increase our cost of funding, both of which could significantly reduce our short-term and long-term profitability.
 
The availability and cost of credit for our businesses may be greatly affected by credit ratings. If the credit ratings of SoCalGas or SDG&E were to be reduced, their businesses could be materially adversely affected and any reduction in Sempra Energy’s ratings could materially adversely affect Sempra Energy and its non-utility subsidiaries.
 
 
Risks Related to All Sempra Energy Subsidiaries
 
Our businesses are subject to complex government regulations and may be materially adversely affected by changes in these regulations or in their interpretation or implementation.
 
In recent years, the regulatory environment that applies to the electric power and natural gas industries has undergone significant changes, on both federal and state levels. These changes have affected the nature of these industries and the manner in which their participants conduct their businesses. These changes are ongoing, and we cannot predict the future course of changes in this regulatory environment or the ultimate effect that this changing regulatory environment will have on our businesses. Moreover, existing regulations, laws and tariffs may be revised or reinterpreted, and new regulations, laws and tariffs may be adopted or become applicable to us and our facilities. Special tariffs may also be imposed on components used in our businesses that could increase costs if applicable. Our businesses are subject to increasingly complex accounting and tax requirements, and the regulations, laws and tariffs that affect us may change in response to economic or political conditions. Compliance with these requirements could increase our operating costs, and new tax legislation, regulations or other interpretations could materially affect our tax expense. Changes in regulations, laws and tariffs and changes in the way regulations, laws and tariffs are implemented and interpreted may have a material adverse effect on our businesses, cash flows, financial condition and results of operations. 
 
Our operations are subject to rules relating to transactions among the Sempra Utilities and other Sempra Energy operations. These rules are commonly referred to as the Affiliate Transaction Rules. These businesses could be materially adversely affected by changes in these rules or by additional CPUC or FERC rules that further restrict our ability to sell electricity or natural gas, or to trade with the Sempra Utilities and with each other. Affiliate Transaction Rules also could require us to obtain prior approval from the CPUC before entering into any such transactions with the Sempra Utilities. Any such restrictions or approval requirements could materially adversely affect the LNG terminals, natural gas pipelines, electric generation facilities, or other operations of our subsidiaries, which could have a material adverse effect on our cash flows, financial condition and results of operations.
 
Our businesses require numerous permits and other governmental approvals from various federal, state, local and foreign governmental agencies; any failure to obtain or maintain required permits or approvals could cause our sales to materially decline and/or our costs to materially increase, and otherwise materially adversely affect our businesses, cash flows, financial condition and results of operations.
 
All of our existing and planned development projects require multiple approvals. The acquisition, ownership and operation of LNG terminals, natural gas pipelines and storage facilities, and electric generation and transmission facilities require numerous permits, licenses, certificates and other approvals from federal, state, local and foreign governmental agencies. Once received, approvals may be subject to litigation, and projects may be delayed or approvals reversed in litigation. In addition, permits, licenses, certificates, and other approvals may be modified or rescinded by one or more of the governmental agencies and authorities that oversee our businesses. If there is a delay in obtaining any required regulatory approvals or if we fail to obtain or maintain any required approvals or to comply with any applicable laws or regulations, we may not be able to construct or operate our facilities, or we may be forced to incur additional costs. Any such delay or failure to obtain or maintain the necessary permits, licenses, certificates and other approvals could cause our sales to materially decline, and/or our costs to increase, and otherwise materially adversely affect our businesses.
 
Our businesses have significant environmental compliance costs, and future environmental compliance costs could have a material adverse effect on our businesses, cash flows, financial condition and results of operations.
 
We are subject to extensive federal, state, local and foreign statutes, rules and regulations relating to environmental protection, including, in particular, climate change and GHG emissions. We are required to obtain numerous governmental permits, licenses, certificates and other approvals to construct and operate our businesses. Additionally, to comply with these legal requirements, we must spend significant sums on environmental monitoring, pollution control equipment, mitigation costs and emissions fees. In addition, we are generally responsible for all on-site liabilities associated with the environmental condition of our electric generation facilities and other energy projects, regardless of when the liabilities arose and whether they are known or unknown. If we fail to comply with applicable environmental laws, we may be subject to substantial penalties and fines and/or significant curtailments of our operations, which could materially adversely affect our businesses, cash flows, financial condition and results of operations.
 
The scope and effect of new environmental laws and regulations, including their effects on our current operations and future expansions, are difficult to predict. Increasing international, national, regional and state-level concerns as well as new or proposed legislation and regulation may have substantial negative effects on our operations, operating costs, and the scope and economics of proposed expansion. In particular, state-level laws and regulations, as well as proposed national and international legislation and regulation relating to the control and reduction of GHG emissions (including carbon dioxide, methane, nitrous oxide, hydrofluorocarbons, perfluorocarbons and sulfur hexafluoride), may materially limit or otherwise materially adversely affect our operations. The implementation of recent and proposed California and federal legislation and regulation may materially adversely affect our unregulated businesses by imposing, among other things, additional costs associated with emission limits, controls and the possible requirement of carbon taxes or the purchase of emissions credits. Similarly, the Sempra Utilities may be materially adversely affected if costs are not recoverable in rates. The effects of existing and proposed greenhouse gas emission reduction standards may cause rates to increase to levels that substantially reduce customer demand and growth. SDG&E may also be subject to significant penalties and fines if certain mandated renewable energy goals are not met.
 
In addition, existing and future laws and regulation on mercury, nitrogen and sulfur oxides, particulates, or other emissions could result in requirements for additional pollution control equipment or emission fees and taxes that could materially adversely affect our businesses and profitability. Moreover, existing rules and regulations may be interpreted or revised in ways that may materially adversely affect our facilities, operations and profitability. 
 
We provide further discussion of these matters in Notes 14 and 15 of the Notes to Consolidated Financial Statements in the Annual Report. 
 
Natural disasters, catastrophic accidents or acts of terrorism could materially adversely affect our businesses, financial condition, results of operations and cash flows.
 
Like other major industrial facilities, ours may be damaged by natural disasters, catastrophic accidents, or acts of terrorism. Such facilities include
 
§ power generation plants
 
§ chartered LNG tankers
 
§ electric transmission and distribution
 
§ natural gas pipelines and storage
 
§ LNG terminals and storage
 
§ nuclear waste storage facilities
 
Such incidents could result in severe business disruptions, significant decreases in revenues, and/or significant additional costs to us. Any such incident could have a material adverse effect on our financial condition, results of operations and cash flows.
 
Depending on the nature and location of the facilities affected, any such incident also could cause catastrophic fires, leaks, radioactive releases, explosions, spills or other significant damage to natural resources or property belonging to third parties, or cause personal injuries or fatalities. Any of these consequences could lead to significant claims against us. Insurance coverage may significantly increase in cost or become unavailable for certain of these risks, and any insurance proceeds we receive may be insufficient to cover our losses or liabilities, which could materially adversely affect our businesses, financial condition, results of operations and cash flows.
 
Our future results of operations, financial condition, and cash flows may be materially adversely affected by the outcome of pending litigation against us.
 
Sempra Energy and its subsidiaries are defendants in numerous lawsuits. We have spent, and continue to spend, substantial amounts of money and time defending these lawsuits, and in related investigations and regulatory proceedings. In particular, SDG&E is subject to numerous lawsuits arising out of San Diego County wildfires in 2007. We discuss this and other litigation in Note 15 of the Notes to Consolidated Financial Statements in the Annual Report. The uncertainties inherent in legal proceedings make it difficult to estimate with any degree of certainty the costs and effects of resolving these matters. In addition, California juries have demonstrated a willingness to grant large awards, including punitive damages, in personal injury, product liability, property damage and other claims. Accordingly, actual costs incurred may differ materially from insured or reserved amounts and may not be recoverable in whole or in part from our customers, which in each case could materially adversely affect our business, cash flows, results of operations and financial condition.
 
We discuss these proceedings in Note 15 of the Notes to Consolidated Financial Statements and in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in the Annual Report.
 
New business technologies present a risk for attacks on our information systems and the integrity of our energy grid.
 
Cybersecurity and the protection of our operations and activities are a priority at Sempra Energy, SDG&E and SoCalGas. The most significant cybersecurity risks to our businesses reside within the operations of our utilities. In addition to general information and cyber risks that all Fortune 500 corporations face (e.g. malware, malicious intent by insiders and inadvertent disclosure of sensitive information), the utility industry faces new cybersecurity risks associated with automated metering (virtually all of our SDG&E customers have such metering) and with Smart Grid infrastructure. Deployment of these new business technologies represents a new and large-scale opportunity for attacks on the utilities’ information systems and, more importantly, on the integrity of the energy grid. While addressing these risks is the subject of significant ongoing activities across Sempra Energy’s businesses, we cannot ensure that a successful attack will not occur. Such an attack to our information systems, the integrity of the energy grid, or one of our facilities could have a material adverse effect on our businesses, cash flows, financial condition, and results of operations.
 
 
Risks Related to the Sempra Utilities
 
The Sempra Utilities are subject to extensive regulation by state, federal and local legislative and regulatory authorities, which may materially adversely affect the operations, performance and growth of their businesses.
 
The CPUC regulates the Sempra Utilities’ rates, except SDG&E’s electric transmission rates which are regulated by the FERC. The CPUC also regulates the Sempra Utilities’:
 
§ conditions of service
 
§ rates of depreciation
 
§ capital structure
 
§ long-term resource procurement
 
§ rates of return
 
§ sales of securities
 
The CPUC conducts various reviews and audits of utility performance, compliance with CPUC regulations and standards, affiliate relationships and other matters. These reviews and audits may result in disallowances, fines and penalties that could materially adversely affect results of operations and cash flows. SoCalGas and SDG&E may be subject to penalties or fines related to their operation of natural gas pipelines under new regulations concerning natural gas pipeline safety, which could have a material adverse effect on their results of operations, financial condition and cash flows. We discuss various CPUC proceedings relating to the Sempra Utilities’ rates, costs, incentive mechanisms, and performance-based regulation in Note 14 of the Notes to Consolidated Financial Statements and in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in the Annual Report.
 
The Sempra Utilities may spend significant amounts of money related to a major capital project prior to receiving regulatory approval. If the project does not receive regulatory approval, if the regulatory approval is conditioned on major changes, or if management decides not to proceed with the project, they may be unable to recover all amounts spent for that project, which could materially adversely affect their businesses, financial condition, results of operations and cash flows.
 
The CPUC periodically approves the Sempra Utilities’ rates based on authorized capital expenditures, operating costs and an authorized rate of return on investment. If actual capital expenditures and operating costs were to exceed the amount approved by the CPUC, results of operations and cash flows could be materially adversely affected. Changes in interest rates may trigger mechanisms which determine the Sempra Utilities’ authorized rates of return, changes in which could materially adversely affect results of operations and cash flows, as we discuss under “Cost of Capital” in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report.
 
The CPUC applies performance-based measures and incentive mechanisms to all California utilities. Under these, earnings potential above authorized base margins is tied to achieving or exceeding specific performance and operating goals, rather than relying solely on expanding utility plant (rate base) to increase earnings. At the Sempra Utilities, the areas that are eligible for incentives are operational activities such as employee safety, energy efficiency programs and, at SoCalGas, natural gas procurement and unbundled natural gas storage and system operator hub services. Although the Sempra Utilities have received incentive awards in the past, there can be no assurance that they will receive awards in the future, or that any future awards earned would be in amounts comparable to prior periods. Additionally, if the Sempra Utilities fail to achieve certain minimum performance levels established under such mechanisms, they may be assessed financial disallowances, penalties and fines which could have a material negative effect on their results of operations, financial condition and cash flows.
 
The FERC regulates electric transmission rates, the transmission and wholesale sales of electricity in interstate commerce, transmission access, the rates of return on transmission investments, and other similar matters involving SDG&E.
 
The Sempra Utilities may be materially adversely affected by new regulations, decisions, orders or interpretations of the CPUC, the FERC or other regulatory bodies. New legislation, regulations, decisions, orders or interpretations could change how they operate, could affect their ability to recover various costs through rates or adjustment mechanisms, or could require them to incur substantial additional expenses.
 
The construction and expansion of the Sempra Utilities’ natural gas pipelines, SoCalGas’ storage facilities, and SDG&E’s electric transmission and distribution facilities require numerous permits, licenses and other approvals from federal, state and local governmental agencies. If there are delays in obtaining these approvals, or failure to obtain or maintain these approvals, or to comply with applicable laws or regulations, the Sempra Utilities’ business, cash flows, results of operations and financial condition could be materially adversely affected. Coordinating these projects so that they are on time and within budget requires superior execution from our employees and contractors, cooperation of third parties and the absence of litigation and regulatory delay. In the event that one or more of these major projects is delayed or experiences significant cost overruns, this could have a material adverse effect on the Sempra Utilities’ businesses, financial condition, results of operations and cash flows.
 
Recovery of 2007 Wildfire Litigation Costs
 
SDG&E is subject to numerous lawsuits arising out of the San Diego County wildfires in 2007. It expects that substantially all reasonably incurred costs of resolving 2007 wildfire claims that exceed its liability insurance coverage and any amounts recovered from other potentially responsible parties will be recovered from utility customers. At December 31, 2011, SDG&E’s Consolidated Balance Sheet includes a regulatory asset of $594 million associated with these costs. However, recovery from customers will require future regulatory actions, and a failure to obtain all or a significant portion of the expected recovery, or any negative assessment of the likelihood of recovery, would likely have a material adverse effect on Sempra Energy’s and SDG&E’s cash flows, financial condition and results of operations. In addition, SDG&E’s cash flows may be materially adversely affected due to the timing differences between resolution of claims and the recoveries from other potentially responsible parties and utility customers, which may extend over a number of years.
 
SDG&E may incur substantial costs and liabilities as a result of its ownership of nuclear facilities.
 
SDG&E has a 20-percent ownership interest in SONGS, a 2,150-MW nuclear generating facility near San Clemente, California, operated by Southern California Edison Company. The NRC has broad authority under federal law to impose licensing and safety-related requirements for the operation of nuclear generation facilities. SDG&E’s ownership interest in SONGS subjects it to the risks of nuclear generation, which include
 
§  
the potential that a natural disaster such as an earthquake or tsunami could cause a catastrophic failure of the safety systems in place that are designed to prevent the release of radioactive material. If such a failure were to occur, a substantial amount of radiation could be released and cause catastrophic harm to human health and the environment;
 
§  
the potential harmful effects on the environment and human health resulting from the operation of nuclear facilities and the storage, handling and disposal of radioactive materials;
 
§  
limitations on the amounts and types of insurance commercially available to cover losses that might arise in connection with nuclear operations;
 
§  
uncertainties with respect to the technological and financial aspects of equipment maintenance, and the decommissioning of nuclear plants; and
 
§  
a substantial increase in oversight and new and more onerous regulations due to the nuclear disaster at Japan’s Fukushima Daiichi plant in early 2011.
 
The occurrence of any of these events could have a material adverse effect on SDG&E’s and Sempra Energy’s businesses, cash flows, financial condition and results of operations.
 
 
Risks Related to our Generation, LNG, Pipelines & Storage and Other Businesses
 
Our businesses are exposed to market risks, including fluctuations in commodity prices, and our financial condition, results of operations, cash flows and liquidity may be materially adversely affected by these risks.
 
Sempra Generation generates electricity that it sells under long-term contracts and into the spot market or other competitive markets. It purchases natural gas to fuel its power plants and may also purchase electricity in the open market to satisfy its contractual obligations. As part of its risk management strategy, Sempra Generation may hedge a substantial portion of its electricity sales and natural gas purchases to manage its portfolio, which subjects us to the risk that the counterparty to such hedge may be unable to fulfill its obligations. Such a failure could materially adversely affect our businesses, cash flows, financial condition and results of operations.
 
We buy energy-related commodities from time to time, for power plants or for LNG terminals to satisfy contractual obligations with customers, in regional markets and other competitive markets in which we compete. Our revenues and results of operations could be materially adversely affected if the prevailing market prices for electricity, natural gas, LNG or other commodities that we buy change in a direction or manner not anticipated and for which we had not provided adequately through purchase or sale commitments or other hedging transactions.
 
Unanticipated changes in market prices for energy-related commodities result from multiple factors, including:
 
§  
weather conditions
 
§  
seasonality
 
§  
changes in supply and demand
 
§  
transmission or transportation constraints or inefficiencies
 
§  
availability of competitively priced alternative energy sources
 
§  
commodity production levels
 
§  
actions by the Organization of the Petroleum Exporting Countries with respect to the supply of crude oil
 
§  
federal, state and foreign energy and environmental regulation and legislation
 
§  
natural disasters, wars, embargoes and other catastrophic events
 
§  
expropriation of assets by foreign countries
 
The FERC has jurisdiction over wholesale power and transmission rates, independent system operators, and other entities that control transmission facilities or that administer wholesale power sales in some of the markets in which we operate. The FERC may impose additional price limitations, bidding rules and other mechanisms, or terminate existing price limitations from time to time. Any such action by the FERC may result in prices for electricity changing in an unanticipated direction or manner and, as a result, may have a material adverse effect on our businesses, financial condition, cash flows and results of operations.

When our businesses enter into fixed-price long-term contracts to provide services or commodities, we are exposed to inflationary pressures such as rising commodity prices, and interest rate risks.
 
Sempra Generation, Sempra Pipelines & Storage and Sempra LNG generally endeavor to secure long-term contracts with customers for services and commodities to optimize the use of their facilities, reduce volatility in earnings, and support the construction of new infrastructure. However, if these contracts are at fixed prices, the profitability of the contract may be materially adversely affected by inflationary pressures, including rising operational costs, costs of labor, materials, equipment and commodities, and rising interest rates that affect financing costs. We may try to mitigate these risks by using variable pricing tied to market indices, anticipating an escalation in costs when bidding on projects, providing for cost escalation or entering into hedges. However, these measures, if implemented, may not ensure that the increase in revenues they provide will fully offset increases in operating expenses and/or financing costs. The failure to so fully or substantially offset these increases could have a material adverse effect on our businesses, financial condition, cash flows and results of operations.
 
Business development activities may not be successful and projects under construction may not commence operation as scheduled, which could increase our costs and impair our ability to recover our investments.
 
The acquisition, development, construction and expansion of LNG terminals, natural gas pipelines and storage facilities, electric generation facilities, and other energy infrastructure projects involve numerous risks. We may be required to spend significant sums for preliminary engineering, permitting, fuel supply, resource exploration, legal, and other expenses before we can determine whether a project is feasible, economically attractive, or capable of being built.
 
Success in developing a particular project is contingent upon, among other things:
 
§  
negotiation of satisfactory engineering, procurement and construction agreements
 
§  
negotiation of supply and natural gas sales agreements or firm capacity service agreements
 
§  
receipt of required governmental permits
 
§  
timely implementation and satisfactory completion of construction
 
Successful completion of a particular project may be materially adversely affected by:
 
§  
unforeseen engineering problems
 
§  
construction delays and contractor performance shortfalls
 
§  
work stoppages
 
§  
equipment unavailability or delay and cost increases
 
§  
adverse weather conditions
 
§  
environmental and geological conditions
 
§  
litigation
 
§  
other factors
 
If we are unable to complete the development of a facility or if we have substantial delays or cost overruns, we may not be able to recover all or any part of our investment in the project.
 
The operation of existing and future facilities also involves many risks, including the breakdown or failure of generation or regasification and storage facilities or other equipment or processes, labor disputes, fuel interruption, and operating performance below expected levels. In addition, weather-related incidents and other natural disasters can disrupt generation, regasification, storage and transmission systems. The occurrence of any of these events could lead to operating facilities below expected capacity levels, which may result in lost revenues or increased expenses, including higher maintenance costs and penalties. Such occurrences could materially adversely affect our businesses, financial condition, cash flows and results of operations.

We may elect not to, or may not be able to, enter into long-term supply and sales agreements or long-term firm capacity agreements for our projects, which would subject our revenues to increased volatility and our businesses to increased competition.
 
The electric generation and wholesale power sales industries have become highly competitive. As more plants are built and competitive pressures increase, wholesale electricity prices may become more volatile. Without the benefit of long-term power sales agreements, our revenues may be subject to increased price volatility. The 10-year power sales agreement between Sempra Generation and the DWR, which comprised 6 percent of our revenues in 2011, 8 percent in 2010 and 9 percent in 2009, expired September 30, 2011. As a result, we may be unable to sell the power that Sempra Generation’s facilities are capable of producing, which could materially adversely affect our businesses, financial condition, results of operations and cash flows.
 
Sempra LNG utilizes its terminals by entering into long-term capacity agreements. Under these agreements, customers pay Sempra LNG capacity reservation and usage fees to receive, store and regasify the customer’s LNG. Sempra LNG also may enter into short-term and/or long-term supply agreements to purchase LNG to be received, stored and regasified at its terminals for sale to other parties. The long-term supply agreement contracts are expected to reduce our exposure to changes in natural gas prices through corresponding natural gas sales agreements or by tying LNG supply prices to prevailing natural gas market price indices. However, if Sempra LNG is unable to obtain sufficient long-term agreements or if the counterparties, customers or suppliers to one or more of the key agreements for the LNG facilities were to fail to perform or become unable to meet their contractual obligations on a timely basis, it could have a material adverse effect on our business, results of operations, cash flows and financial condition. In addition, reduced availability of LNG to the United States and Mexico due to inadequate supplies, increased demand and higher prices in other countries, abundant domestic supplies of natural gas and/or delays in the development of liquefaction capability at our own receipt terminals, or worldwide, are likely to delay attainment of full-capacity utilization at our facilities. Our potential LNG suppliers also may be subject to international political and economic pressures and risks, which may also affect the supply of LNG.
 
Sempra Pipelines & Storage’s natural gas pipeline operations are dependent on demand for and supply of LNG and/or natural gas from their transportation customers, which may include Sempra LNG facilities.
 
We provide information about these matters in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and in Note 15 of the Notes to Consolidated Financial Statements in the Annual Report.
 
Our businesses depend on counterparties, business partners, customers, and suppliers performing in accordance with their agreements. If they fail to so perform, we could incur substantial expenses and business disruptions and be exposed to commodity price risk and volatility, which could materially adversely affect our businesses, financial condition, cash flows and results of operations.
 
We are exposed to the risk that counterparties, business partners, customers, and suppliers that owe money or commodities as a result of market transactions or other long-term agreements will not perform their obligations in accordance with such agreements. Should they fail to so perform, we may be required to acquire alternative hedging arrangements or to honor the underlying commitment at then-current market prices. In such event, we may incur additional losses to the extent of amounts already paid to such counterparties or suppliers. In addition, many of our agreements are essential to the conduct and growth of our businesses. The failure of any of the parties to perform in accordance with these agreements could materially adversely affect our businesses, results of operations, cash flows and financial condition. Finally, we often extend credit to counterparties and customers. While we perform significant credit analyses prior to extending credit, we are exposed to the risk that we may not be able to collect amounts owed to us.
 
Sempra LNG’s obligations and those of its suppliers for LNG supplies are contractually subject to (1) suspension or termination for “force majeure” events beyond the control of the parties; and (2) substantial limitations of remedies for other failures to perform, including limitations on damages to amounts that could be substantially less than those necessary to provide full recovery of costs for breach of the agreements.
 
 
We rely on transportation assets and services, much of which we do not own or control, to deliver electricity and natural gas.
 
We depend on electric transmission lines, natural gas pipelines, and other transportation facilities owned and operated by third parties to:
 
§  
deliver the electricity and natural gas we sell to wholesale markets,
 
§  
supply natural gas to our electric generation facilities, and
 
§  
provide retail energy services to customers.
 
Sempra Pipelines & Storage also depends on natural gas pipelines to interconnect with their ultimate source or customers of the commodities they are transporting. Sempra LNG also relies on specialized ships to transport LNG to its facilities and on natural gas pipelines to transport natural gas for customers of the facilities. Sempra Generation relies on transmission lines to sell electricity to its customers. If transportation is disrupted, or if capacity is inadequate, we may be unable to sell and deliver our commodities, electricity and other services to some or all of our customers. As a result, we may be responsible for damages incurred by our customers, such as the additional cost of acquiring alternative natural gas supplies at then-current spot market rates, which could have a material adverse effect on our businesses, financial condition, cash flows and results of operations.
 
We cannot and do not attempt to fully hedge our assets or contract positions against changes in commodity prices. Our hedging procedures may not work as planned.
 
To reduce financial exposure related to commodity price fluctuations, we may enter into contracts to hedge our known or anticipated purchase and sale commitments, inventories of natural gas and LNG, electric generation capacity, and natural gas storage and pipeline capacity. As part of this strategy, we may use forward contracts, physical purchase and sales contracts, futures, financial swaps, and options. We do not hedge the entire exposure to market price volatility of our assets or our contract positions, and the coverage will vary over time. To the extent we have unhedged positions, or if our hedging strategies do not work as planned, fluctuating commodity prices could have a material adverse effect on our businesses, results of operations, cash flows and financial condition.
 
Risk management procedures may not prevent losses.
 
Although we have in place risk management systems and control systems that use advanced methodologies to quantify and manage risk, these systems may not always prevent material losses. Risk management procedures may not always be followed as required by the companies or may not always work as planned. In addition, daily value-at-risk and loss limits are based on historic price movements. If prices significantly or persistently deviate from historic prices, the limits may not protect us from significant losses. As a result of these and other factors, there is no assurance that our risk management procedures will prevent losses that would materially adversely affect our businesses, results of operations, cash flows and financial condition.
 
Our international businesses are exposed to different local, regulatory and business risks and challenges, which could have a material adverse effect on our financial condition, cash flows and results of operations.
 
We own or have interests in electricity generation and transmission, natural gas distribution and transportation, and LNG terminal projects in Mexico, and electricity and natural gas distribution businesses in Argentina, Chile and Peru. Developing infrastructure projects, owning energy assets, and operating businesses in foreign jurisdictions subject us to significant political, legal and financial risks that vary by country, including:
 
§  
changes in foreign laws and regulations, including tax and environmental laws and regulations, and U.S. laws and regulations related to foreign operations
 
§  
high rates of inflation
 
§  
volatility in exchange rates between the U.S. dollar and currencies of the countries in which we operate
 
§  
changes in government policies or personnel
 
§  
trade restrictions
 
§  
limitations on U.S. company ownership in foreign countries
 
§  
permitting and regulatory compliance
 
§  
changes in labor supply and labor relations
 
§  
adverse rulings by foreign courts or tribunals, challenges to permits and approvals, difficulty in enforcing contractual and property rights, and unsettled property rights and titles in Mexico and other foreign jurisdictions
 
§  
expropriation of assets
 
§  
general political, economic and business conditions
 
Our international businesses also are subject to foreign currency risks. These risks arise from both volatility in foreign currency exchange and inflation rates and devaluations of foreign currencies. In such cases, an appreciation of the U.S. dollar against a local currency could materially reduce the amount of cash and income received from those foreign subsidiaries. Fluctuations in foreign currency exchange and inflation rates may result in significantly increased taxes in foreign countries and materially adversely affect our businesses, cash flows and results of operations.
 
We discuss litigation related to Sempra LNG’s Energía Costa Azul LNG terminal in Note 15 of the Notes to Consolidated Financial Statements in the Annual Report.
 
 
Other Risks
 
Sempra Energy has substantial investments and other obligations in businesses that it does not control or manage.
 
Sempra Energy is a partner with RBS in RBS Sempra Commodities, a commodities-marketing firm, which divested substantially all of its businesses and assets in 2010 and early 2011, as we discuss above under “Description of Business – RBS Sempra Commodities LLP.” Our remaining investment in the partnership is $126 million at December 31, 2011. We expect the partnership to distribute substantially all of this amount to us in the first half of 2012. Minor amounts may be retained by the partnership beyond 2012 to help offset unanticipated future general and administrative costs necessary to complete the dissolution of the partnership. We have guaranteed various obligations of businesses previously owned and operated by RBS Sempra Commodities, as we discuss in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report. The failure to collect all or a substantial portion of our remaining investment in the partnership could have a corresponding effect on our cash flows, financial condition and results of operations.
 
As described above, SDG&E holds a 20-percent ownership interest in SONGS, which is operated by Edison. We also own a 25-percent interest in Rockies Express Pipeline LLC (Rockies Express), a joint venture which completed construction in 2009 of a 1,679-mile natural gas pipeline at a cost of $6.8 billion. Our investment in Rockies Express is $800 million at December 31, 2011. Rockies Express is controlled by Kinder Morgan Energy Partners, which holds a 50-percent interest. Sempra Generation has investments in several joint ventures to develop and operate renewable generation facilities. We also have smaller investments in other entities that we do not control or manage, or in which we share control, totaling $713 million at December 31, 2011. We continue to make such investments.
 
We have limited influence over these and other businesses in which we do not have a controlling interest. In addition to the other risks inherent in these businesses, if their management were to fail to perform adequately or the other investors in the businesses were unable or otherwise failed to perform their obligations to provide capital and credit support for these businesses, it could have a material adverse effect on our results of operations, financial position and cash flows.
 

 
 
 
 



 

ITEM 1B. UNRESOLVED STAFF COMMENTS
 

None.
 

 

ITEM 2. PROPERTIES
 

 
ELECTRIC PROPERTIES – SDG&E
 
At December 31, 2011, SDG&E owns and operates four natural gas-fired power plants:
 
1.  
 a 560-MW electric generation facility (the Palomar generation facility) in Escondido, California
 
2.  
 a 495-MW electric generation facility (the Desert Star generation facility) in Boulder City, Nevada
 
3.  
 a 47.6-MW electric generation peaking facility (the Miramar I generation facility) in San Diego, California
 
4.  
 a 48.6-MW electric generation peaking facility (the Miramar II generation facility) in San Diego, California
 
SDG&E purchased the 495-MW Desert Star (formerly El Dorado) natural gas-fired power plant from Sempra Generation in October 2011.
 
On January 1, 2012, SDG&E purchased a fifth natural gas-fired power plant, the 52-MW Cuyamaca Peak Energy Plant (formerly CalPeak El Cajon Energy Facility) located in El Cajon, California from CalPeak Power-El Cajon LLC.
 
SDG&E’s interest in SONGS is described above in Item 1 under “Electric Utility Operations – SDG&E.”
 
At December 31, 2011, SDG&E’s electric transmission and distribution facilities included substations, and overhead and underground lines. These electric facilities are located in San Diego, Imperial and Orange counties of California, and in Arizona and Nevada. The facilities consist of 1,896 miles of transmission lines and 22,449 miles of distribution lines. Periodically, various areas of the service territory require expansion to accommodate customer growth.
 
SDG&E expects to complete construction of the Sunrise Powerlink electric transmission line in the second half of 2012.  The Sunrise Powerlink is a new 117-mile, 500-kV electric transmission line that is designed to deliver up to 1,000 MW of energy from the Imperial Valley to the San Diego region.
 
 
NATURAL GAS PROPERTIES – SEMPRA UTILITIES
 
At December 31, 2011, SDG&E’s natural gas facilities consisted of the Moreno and Rainbow compressor stations, 168 miles of transmission pipelines, 8,490 miles of distribution mains and 6,388 miles of service lines.
 
At December 31, 2011, SoCalGas’ natural gas facilities included 2,960 miles of transmission and storage pipelines, 49,773 miles of distribution pipelines and 48,572 miles of service pipelines. They also included 11 transmission compressor stations and 4 underground natural gas storage reservoirs with a combined working capacity of 134 billion cubic feet (Bcf).
 
 
ENERGY PROPERTIES – SEMPRA GLOBAL
 
At December 31, 2011, Sempra Generation operates or owns interests in power plants and renewable generation facilities in North America with a total capacity of 2,200 MW. We provide additional information in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and in Notes 3 and 4 of the Notes to Consolidated Financial Statements in the Annual Report.
 
Sempra Generation leases or owns property in Arizona, California, Nevada, and Mexico for potential development of solar and wind electric generation facilities.
 
At December 31, 2011, Sempra Pipelines & Storage’s operations in Mexico included 1,903 miles of distribution pipelines, 224 miles of transmission pipelines and 3 compressor stations.
 
In 2006, Sempra Pipelines & Storage and ProLiance Transportation and Storage, LLC acquired three existing salt caverns representing 10 Bcf to 12 Bcf of potential natural gas storage capacity in Cameron Parish, Louisiana, with plans for development of a natural gas storage facility.
 
Sempra Pipelines & Storage operates Mobile Gas, a natural gas distribution utility located in Mobile and Baldwin counties in Alabama. Its property consists of distribution mains, service lines and regulating equipment.
 
Sempra Pipelines & Storage operates Chilquinta Energía located in Valparaiso, Chile.  Its property consists of 9,622 miles of distribution lines, 339 miles of transmission lines and 45 substations.
 
Sempra Pipelines & Storage operates Luz del Sur located in Lima, Peru.  Its property consists of 11,806 miles of distribution lines and 173 miles of transmission lines.
 
In Washington County, Alabama, Sempra Pipelines & Storage operates a 15.5 Bcf natural gas storage facility under a land lease, with current plans to expand total working capacity to 21 Bcf to be in-service in 2013. Sempra Pipelines & Storage also owns land in Simpson County, Mississippi, on which it operates a 7.5 Bcf natural gas storage facility, with current plans to develop natural gas storage with additional working capacity of 15 Bcf to be in-service in 2012 and 2013. Portions of both these properties are currently under construction.
 
Sempra LNG operates its Energía Costa Azul LNG terminal on land it owns in Baja California, Mexico and has a land lease in Hackberry, Louisiana, where it operates its Cameron LNG terminal. Sempra LNG also owns land in Port Arthur, Texas, for potential development.
 
 
OTHER PROPERTIES
 
Sempra Energy occupies its 19-story corporate headquarters building in San Diego, California, pursuant to an operating lease that expires in 2015. The lease has two five-year renewal options.
 
SoCalGas leases approximately one-fourth of a 52-story office building in downtown Los Angeles, California, pursuant to an operating lease expiring in 2026. The lease has four five-year renewal options.
 
SDG&E occupies a six-building office complex in San Diego pursuant to two separate operating leases, both ending in December 2017. One lease has four five-year renewal options and the other lease has three five-year renewal options.
 
Sempra Global leases office facilities at various locations in the U.S., Mexico, Chile and Peru, with the leases ending from 2012 to 2035.
 
Sempra Energy, SDG&E and SoCalGas own or lease other land, easements, rights of way, warehouses, offices, operating and maintenance centers, shops, service facilities and equipment necessary to conduct their businesses.
 

 

ITEM 3. LEGAL PROCEEDINGS
 

We are not party to, and our property is not the subject of, any material pending legal proceedings (other than ordinary routine litigation incidental to our businesses) except for the matters (1) described in Notes 14 and 15 of the Notes to Consolidated Financial Statements, or (2) referred to in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in the Annual Report.
 

 

ITEM 4. MINE SAFETY DISCLOSURES
 

Not applicable.
 

 
 
 
 

PART II
 

 

ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
 

 
COMMON STOCK AND RELATED SHAREHOLDER MATTERS
 
The common stock, related shareholder, and dividend restriction information required by Item 5 is included in “Common Stock Data” in the Annual Report.
 
 
SEMPRA ENERGY EQUITY COMPENSATION PLANS
 
Sempra Energy has long term incentive plans that permit the grant of a wide variety of equity and equity-based incentive awards to directors, officers and key employees. At December 31, 2011, outstanding awards consisted of stock options, restricted stock, and restricted stock units held by 331 employees.
 
The following table sets forth information regarding our equity compensation plans at December 31, 2011.
 

 
 
Number of shares to
 
 
 
 
be issued upon
 
Number of
 
 
exercise of
Weighted-average
additional
 
 
outstanding
exercise price of
shares remaining
 
 
options, warrants
outstanding options,
available for future
 
 
and rights(A)
warrants and rights
issuance
Equity compensation plans approved
 
 
 
 
 
    by shareholders:
 
 
 
 
 
        2008 Long Term Incentive Plan
 4,615,821 
$
 47.85 
 2,314,475 
(B)
 
 
 
 
 
 
 
Equity compensation plans not approved
 
 
 
 
 
    by shareholders:
 
 
 
 
 
        2008 Long Term Incentive Plan for
 
 
 
 
 
            EnergySouth, Inc. Employees and
 
 
 
 
 
            Other Eligible Individuals(C)
 15,150 
$
 49.44 
 240,952 
(D)
Total
 4,630,971 
$
 47.85 
 2,555,427 
 
(A)
Consists solely of options to purchase shares of our common stock, all of which were granted at an exercise price of 100% of the grant date fair market value of the shares subject to the option.
(B)
The number of shares available for future issuance is increased by the number of shares withheld to satisfy tax withholding obligations relating to stock option and other plan awards and by the number of shares subject to awards that lapse, expire or are otherwise terminated or are settled other than by the issuance of shares.
(C)
Adopted in connection with our acquisition of EnergySouth, Inc. in October 2008 to utilize shares remaining available under the 2008 Incentive Plan of EnergySouth, Inc., which had been previously approved by EnergySouth, Inc. shareholders.
(D)
The number of shares available for future issuance is increased by the number of shares subject to awards that terminate without the issuance of shares.

We provide additional discussion of share-based compensation in Note 9 of the Notes to Consolidated Financial Statements in the Annual Report.
 
 
PURCHASES OF EQUITY SECURITIES BY THE ISSUER AND AFFILIATED PURCHASERS
 
On September 11, 2007, the Sempra Energy board of directors authorized the repurchase of Sempra Energy common stock provided that the amounts spent for such purpose do not exceed the greater of $2 billion or amounts spent to purchase no more than 40 million shares.
 
During 2008, we expended $1 billion to purchase a total of 18,416,241 shares. No shares were repurchased under this authorization during 2009.
 
In 2010, we entered into a Collared Accelerated Share Acquisition Program with JPMorgan Chase Bank, National Association, under which we prepaid $500 million to repurchase shares of our common stock. We received 8,078,000 shares in 2010 and 1,496,435 shares in March 2011.  We discuss this program, which was completed in March 2011, in Note 13 of the Notes to Consolidated Financial Statements in the Annual Report.
 
Therefore, approximately $500 million remains authorized by the board for the purchase of additional shares, not to exceed approximately 12 million shares. We also may, from time to time, purchase shares of our common stock from restricted stock plan participants who elect to sell a sufficient number of vesting restricted shares to meet minimum statutory tax withholding requirements.
 

 

ITEM 6. SELECTED FINANCIAL DATA
 

The information required by Item 6 is included in “Five-Year Summaries” in the Annual Report.
 

 

ITEM 7. MANAGEMENTS DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
 

The information required by Item 7 is set forth under “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in the Annual Report, on pages 2 through 63.
 

 

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
 

The information required by Item 7A is set forth under “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Market Risk” in the Annual Report.
 

 

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
 

The information required by Item 8 is set forth on pages 75 through 203 of the Annual Report. Item 15(a)1 of Part IV of this report includes a listing of financial statements included.
 

 

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
 

Not applicable.
 

 

ITEM 9A. CONTROLS AND PROCEDURES
 

The information required by Item 9A is provided in “Controls and Procedures” in the Annual Report.
 

 

ITEM 9B. OTHER INFORMATION
 

None.
 

 
 
 
 

PART III
 

 

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
 

 
SEMPRA ENERGY
 
We provide the information required by Item 10 with respect to executive officers for Sempra Energy in Part I, Item 1. Business under “Executive Officers of the Registrants – Sempra Energy.” All other information required by Item 10 is incorporated by reference from “Corporate Governance” and “Share Ownership” in the Proxy Statement prepared for the May 2012 annual meeting of shareholders.
 
 
SDG&E AND SOCALGAS
 
We provide the information required by Item 10 with respect to executive officers for SDG&E and SoCalGas in Part I, Item 1. Business under “Executive Officers of the Registrants – SDG&E and SoCalGas.” All other information required by Item 10 is incorporated by reference from the companies’ Information Statements prepared for their June 2012 annual meetings of shareholders.
 

 

ITEM 11. EXECUTIVE COMPENSATION
 

The information required by Item 11 is incorporated by reference from “Corporate Governance” and “Executive Compensation,” including “Compensation Discussion and Analysis” and “Compensation Committee Report” in the Proxy Statement prepared for the May 2012 annual meeting of shareholders for Sempra Energy and from the Information Statements prepared for the June 2012 annual meetings of shareholders for SDG&E and SoCalGas.
 

 

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
 

 
SECURITIES AUTHORIZED FOR ISSUANCE UNDER EQUITY COMPENSATION PLANS
 
Information regarding securities authorized for issuance under equity compensation plans as required by Item 12 is included in Item 5.
 
 
SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
 
The security ownership information required by Item 12 is incorporated by reference from “Share Ownership” in the Proxy Statement prepared for the May 2012 annual meeting of shareholders for Sempra Energy and from the Information Statements prepared for the June 2012 annual meetings of shareholders for SDG&E and SoCalGas.
 

 

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
 

The information required by Item 13 is incorporated by reference from “Corporate Governance” in the Proxy Statement prepared for the May 2012 annual meeting of shareholders for Sempra Energy and from the Information Statements prepared for the June 2012 annual meetings of shareholders for SDG&E and SoCalGas.
 

 

ITEM 14.  PRINCIPAL ACCOUNTANT FEES AND SERVICES
 

Information regarding principal accountant fees and services, as required by Item 14, is incorporated by reference from “Proposals To Be Voted On - Proposal 2: Ratification of Independent Registered Public Accounting Firm” in the Proxy Statement prepared for the May 2012 annual meeting of shareholders for Sempra Energy and from the Information Statements prepared for the June 2012 annual meetings of shareholders for SDG&E and SoCalGas.
 

 
 
 
 

PART IV
 
 

ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
 

(a) The following documents are filed as part of this report:
 
 
1. FINANCIAL STATEMENTS
 
 
Page in Annual Report(1)
       
 
Sempra Energy
San Diego
Gas & Electric Company
Southern California Gas Company
       
Management’s Report On Internal Control Over Financial Reporting
68
68
68
       
Reports of Independent Registered Public Accounting Firm
69
71
73
       
Consolidated Statements of Operations for the years ended December 31, 2011, 2010 and 2009
75
82
88
       
Consolidated Balance Sheets at December 31, 2011 and 2010
76
83
89
       
Consolidated Statements of Cash Flows for the years ended December 31, 2011, 2010 and 2009
78
85
91
       
Consolidated Statements of Comprehensive Income and Changes in Equity for the years ended December 31, 2011, 2010 and 2009
80
87
92
       
Notes to Consolidated Financial Statements
93
93
93
(1) Incorporated by reference from the indicated pages of the 2011 Annual Report to Shareholders, filed as Exhibit 13.1.
 
2. FINANCIAL STATEMENT SCHEDULES
 
 
Sempra Energy
 
Schedule I--Sempra Energy Condensed Financial Information of Parent may be found on page 43.
 
Any other schedule for which provision is made in Regulation S-X is not required under the instructions contained therein, is inapplicable or the information is included in the Consolidated Financial Statements and Notes thereto in the Annual Report.
 
 
3. EXHIBITS
 
See Exhibit Index on page 50 of this report.
 

 
 
 
 

CONSENTS OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM AND REPORT ON SCHEDULE
 

 

SEMPRA ENERGY
 

 
To the Board of Directors and Shareholders of Sempra Energy:
 
We consent to the incorporation by reference in Registration Statement No. 333-176855 on Form S-3 and 333-56161, 333-50806, 333-49732, 333-121073, 333-128441, 333-151184, 333-155191, 333-129774 and 333-157567 on Form S-8 of our reports dated February 28, 2012, relating to the consolidated financial statements of Sempra Energy and subsidiaries (the “Company”), and the effectiveness of the Company’s internal control over financial reporting, incorporated by reference in this Annual Report on Form 10-K of Sempra Energy for the year ended December 31, 2011.
 
Our audits of the financial statements referred to in our aforementioned report relating to the consolidated financial statements also included the financial statement schedule of the Company, listed in Item 15.  This financial statement schedule is the responsibility of the Company’s management.  Our responsibility is to express an opinion based on our audits.  In our opinion, such financial statement schedule, when considered in relation to the basic consolidated financial statements taken as a whole, presents fairly, in all material respects, the information set forth therein.
 
 
/S/ DELOITTE & TOUCHE LLP
 
San Diego, California
 
February 28, 2012
 

 
 
 
 



 

SAN DIEGO GAS & ELECTRIC COMPANY
 

 
To the Board of Directors and Shareholders of San Diego Gas & Electric Company:
 
We consent to the incorporation by reference in Registration Statement No. 333-159046 on Form S-3 of our reports dated February 28, 2012, relating to the consolidated financial statements of San Diego Gas & Electric Company (the “Company”), and the effectiveness of the Company’s internal control over financial reporting, incorporated by reference in this Annual Report on Form 10-K of San Diego Gas & Electric Company for the year ended December 31, 2011.
 
 
/S/ DELOITTE & TOUCHE LLP
 
San Diego, California
 
February 28, 2012
 

 
 
 
 



 

SOUTHERN CALIFORNIA GAS COMPANY
 

 
To the Board of Directors and Shareholders of Southern California Gas Company:
 
We consent to the incorporation by reference in Registration Statement No. 333-159041 on Form S-3 of our reports dated February 28, 2012, relating to the consolidated financial statements of Southern California Gas Company and subsidiaries (the “Company”), and the effectiveness of the Company’s internal control over financial reporting, incorporated by reference in this Annual Report on Form 10-K of Southern California Gas Company for the year ended December 31, 2011.
 
 
/S/ DELOITTE & TOUCHE LLP
 
San Diego, California
 
February 28, 2012
 

 
 
 
 



 
SCHEDULE I – SEMPRA ENERGY CONDENSED FINANCIAL INFORMATION OF PARENT
 


SEMPRA ENERGY
CONDENSED STATEMENTS OF OPERATIONS
(Dollars in millions, except per share amounts)
 
Years ended December 31,
 
2011 
2010 
2009 
 
 
 
 
 
 
 
Interest income
$
 109 
$
 146 
$
 140 
Interest expense
 
 (242)
 
 (265)
 
 (244)
Operation and maintenance
 
 (64)
 
 (59)
 
 (81)
Other income, net
 
 42 
 
 65 
 
 50 
Income tax benefits
 
 82 
 
 79 
 
 89 
    Loss before equity in earnings of subsidiaries
 
 (73)
 
 (34)
 
 (46)
Equity in earnings of subsidiaries, net of income taxes
 
 1,430 
 
 773 
 
 1,165 
    Net income/earnings
$
 1,357 
$
 739 
$
 1,119 
 
 
 
 
 
 
 
Basic earnings per common share
$
 5.66 
$
 3.02 
$
 4.60 
    Weighted-average number of shares outstanding (thousands)
 
 239,720 
 
 244,736 
 
 243,339 
 
 
 
 
 
 
 
Diluted earnings per common share
$
 5.62 
$
 2.98 
$
 4.52 
    Weighted-average number of shares outstanding (thousands)
 
 241,523 
 
 247,942 
 
 247,384 
See Notes to Condensed Financial Information of Parent.



SEMPRA ENERGY
CONDENSED BALANCE SHEETS
(Dollars in millions)
 
December 31,
December 31,
 
2011 
2010 
Assets:
 
 
 
 
Cash and cash equivalents
$
 11 
$
 157 
Due from affiliates
 
 112 
 
 27 
Income taxes receivable
 
 ― 
 
 190 
Other current assets
 
 16 
 
 11 
    Total current assets
 
 139 
 
 385 
 
 
 
 
 
Investments in subsidiaries
 
 12,272 
 
 11,484 
Due from affiliates
 
 1,730 
 
 1,683 
Deferred income taxes
 
 1,200 
 
 305 
Other assets
 
 548 
 
 488 
    Total assets
$
 15,889 
$
 14,345 
 
 
 
 
 
Liabilities and shareholders’ equity:
 
 
 
 
Current portion of long-term debt
$
 8 
$
 32 
Due to affiliates
 
 1,014 
 
 1,331 
Income taxes payable
 
 246 
 
 ― 
Other current liabilities
 
 336 
 
 374 
    Total current liabilities
 
 1,604 
 
 1,737 
 
 
 
 
 
Long-term debt
 
 3,957 
 
 3,140 
Other long-term liabilities
 
 490 
 
 441 
Shareholders’ equity
 
 9,838 
 
 9,027 
Total liabilities and shareholders’ equity
$
 15,889 
$
 14,345 
See Notes to Condensed Financial Information of Parent.



SEMPRA ENERGY
CONDENSED STATEMENTS OF CASH FLOWS
(Dollars in millions)
 
Years ended December 31,
 
2011 
2010 
2009 
 
 
 
 
 
 
 
Net cash (used in) provided by operating activities
$
 (287)
$
 218 
$
 97 
 
 
 
 
 
 
 
Dividends received from subsidiaries
 
 50 
 
 100 
 
 150 
Expenditures for property, plant and equipment
 
 (2)
 
 (1)
 
 (1)
Proceeds from sale of short-term investments
 
 ― 
 
 ― 
 
 152 
Purchase of trust assets
 
 (7)
 
 ― 
 
 (30)
Proceeds from sales by trust
 
 12 
 
 11 
 
 ― 
(Increase) decrease in loans to affiliates, net
 
 (118)
 
 1,204 
 
 (1,285)
    Cash (used in) provided by investing activities
 
 (65)
 
 1,314 
 
 (1,014)
 
 
 
 
 
 
 
Common stock dividends paid
 
 (440)
 
 (364)
 
 (341)
Issuances of common stock
 
 28 
 
 40 
 
 73 
Repurchases of common stock
 
 (18)
 
 (502)
 
 (22)
Issuances of long-term debt
 
 799 
 
 40 
 
 1,492 
Payments on long-term debt
 
 (24)
 
 (565)
 
 (314)
(Decrease) increase in loans from affiliates, net
 
 (136)
 
 (40)
 
 4 
Other
 
 (3)
 
 9 
 
 20 
    Cash provided by (used in) financing activities
 
 206 
 
 (1,382)
 
 912 
 
 
 
 
 
 
 
(Decrease) increase in cash and cash equivalents
 
 (146)
 
 150 
 
 (5)
Cash and cash equivalents, January 1
 
 157 
 
 7 
 
 12 
Cash and cash equivalents, December 31
$
 11 
$
 157 
$
 7 
See Notes to Condensed Financial Information of Parent.



SEMPRA ENERGY
 
 
NOTES TO CONDENSED FINANCIAL INFORMATION OF PARENT
 
 
Note 1. Basis of Presentation
 
Sempra Energy accounts for the earnings of its subsidiaries under the equity method in this unconsolidated financial information.
 
Other Income, Net, on the Condensed Statements of Operations includes $22 million, $35 million and $55 million of gains associated with investment earnings or losses on dedicated assets in support of our executive retirement and deferred compensation plans in 2011, 2010 and 2009, respectively.
 
Because of its nature as a holding company, Sempra Energy classifies dividends received from subsidiaries as an investing cash flow.
 
 
Note 2. Long-Term Debt
 

 
December 31,
December 31,
(Dollars in millions)
2011 
2010 
 
 
 
 
 
6% Notes February 1, 2013
$
 400 
$
 400 
8.9% Notes November 15, 2013, including $200 at variable rates after
 
 
 
 
    fixed-to-floating rate swaps effective January 2011 (8.19% at December 31, 2011)
 
 250 
 
 250 
2% Notes March 15, 2014
 
 500 
 
 ― 
Notes at variable rates (1.22% at December 31, 2011) March 15, 2014
 
 300 
 
 ― 
6.5% Notes June 1, 2016, including $300 at variable rates after
 
 
 
 
    fixed-to-floating rate swaps effective January 2011 (4.86% at December 31, 2011)
 
 750 
 
 750 
6.15% Notes June 15, 2018
 
 500 
 
 500 
9.8% Notes February 15, 2019
 
 500 
 
 500 
6% Notes October 15, 2039
 
 750 
 
 750 
Employee Stock Ownership Plan Bonds at variable rates payable on demand
 
 
 
 
    (0.40% at December 31, 2011) November 1, 2014
 
 8 
 
 32 
Market value adjustments for interest rate swaps, net
 
 
 
 
    (expire November 2013 and June 2016)
 
 16 
 
 ― 
 
 
 3,974 
 
 3,182 
Current portion of long-term debt
 
 (8)
 
 (32)
Unamortized discount on long-term debt
 
 (9)
 
 (10)
Total long-term debt
$
 3,957 
$
 3,140 

Maturities of long-term debt are $8 million in 2012, $650 million in 2013, $800 million in 2014, $750 million in 2016, and $1.8 billion thereafter.
 
Additional information on Sempra Energy’s long-term debt is provided in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report.
 
 
Note 3. Commitments and Contingencies
 
For contingencies and guarantees related to Sempra Energy, refer to Notes 5 and 15 of the Notes to Consolidated Financial Statements in the Annual Report.
 

 
 
 
 

Sempra Energy:
SIGNATURES
     
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
     
 
SEMPRA ENERGY,
(Registrant)
   
 
By:  /s/ Debra L. Reed
 
Debra L. Reed
Chief Executive Officer
   
 
Date: February 28, 2012
     
 
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant in the capacities and on the dates indicated.
     
Name/Title
Signature
Date
 
Principal Executive Officer:
Debra L. Reed
Chief Executive Officer
 
 
/s/ Debra L. Reed
 
 
February 28, 2012
     
Principal Financial and Accounting Officer:
Joseph A. Householder
Executive Vice President, Chief Financial Officer and Chief Accounting Officer
 
 
 
/s/ Joseph A. Householder
 
 
 
February 28, 2012
     
Directors:
   
Donald E. Felsinger, Executive Chairman
/s/ Donald E. Felsinger
February 28, 2012
     
     
Alan L. Boeckmann, Director
/s/ Alan L. Boeckmann
February 28, 2012
     
     
James G. Brocksmith, Jr., Director
/s/ James G. Brocksmith, Jr.
February 28, 2012
     
     
Wilford D. Godbold, Jr., Director
/s/ Wilford D. Godbold, Jr.
February 28, 2012
     
     
William D. Jones, Director
/s/ William D. Jones
February 28, 2012
     
     
William G. Ouchi, Ph.D., Director
/s/ William G. Ouchi
February 28, 2012
     
     
Carlos Ruiz, Director
/s/ Carlos Ruiz
February 28, 2012
     
     
William C. Rusnack, Director
/s/ William C. Rusnack
February 28, 2012
     
     
William P. Rutledge, Director
/s/ William P. Rutledge
February 28, 2012
     
     
Lynn Schenk, Director
/s/ Lynn Schenk
February 28, 2012
     
     
Luis M. Téllez, Ph.D., Director
/s/ Luis M. Téllez
February 28, 2012
     
     
     
     
San Diego Gas & Electric Company:
SIGNATURES
 
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
 
 
SAN DIEGO GAS & ELECTRIC COMPANY,
(Registrant)
   
 
By:  /s/ Jessie J. Knight, Jr.
 
Jessie J. Knight, Jr.
Chairman and Chief Executive Officer
   
 
Date: February 28, 2012

 
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant in the capacities and on the dates indicated.
     
Name/Title
Signature
Date
Principal Executive Officer:
Jessie J. Knight, Jr.
Chairman and Chief Executive Officer
 
 
 
/s/ Jessie J. Knight, Jr.
 
 
 
February 28, 2012
     
Principal Financial and Accounting Officer:
Robert M. Schlax
Vice President, Controller, Chief Financial Officer and Chief Accounting Officer
 
 
 
/s/ Robert M. Schlax
 
 
 
February 28, 2012
     
Directors:
   
Jessie J. Knight, Jr., Chairman
/s/ Jessie J. Knight, Jr.
February 28, 2012
     
     
Javade Chaudhri, Director
/s/ Javade Chaudhri
February 28, 2012
     
     
Joseph A. Householder, Director
/s/ Joseph A. Householder
February 28, 2012
     
     
Steven D. Davis, Director
/s/ Steven D. Davis
February 28, 2012
     

 
Southern California Gas Company:
SIGNATURES
 
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
 
 
SOUTHERN CALIFORNIA GAS COMPANY,
(Registrant)
   
 
By:  /s/ Michael W. Allman
 
Michael W. Allman
Chairman, President and Chief Executive Officer
   
 
Date: February 28, 2012

 
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant in the capacities and on the dates indicated.
     
Name/Title
Signature
Date
 
Principal Executive Officer:
Michael W. Allman
Chairman, President and Chief Executive Officer
 
 
 
/s/ Michael W. Allman
 
 
 
February 28, 2012
     
Principal Financial and Accounting Officer:
Robert M. Schlax
Vice President, Controller, Chief Financial Officer and Chief Accounting Officer
 
 
 
/s/ Robert M. Schlax
 
 
 
February 28, 2012
     
Directors:
   
Michael W. Allman, Chairman
/s/ Michael W. Allman
February 28, 2012
     
     
Javade Chaudhri, Director
/s/ Javade Chaudhri
February 28, 2012
     
     
Joseph A. Householder, Director
/s/ Joseph A. Householder
February 28, 2012
     
     
Steven D. Davis, Director
/s/ Steven D. Davis
February 28, 2012
     

 
 
 
 

 
EXHIBIT INDEX
 
The exhibits filed under the Registration Statements, Proxy Statements and Forms 8-K, 10-K and 10-Q that are incorporated herein by reference were filed under Commission File Number 1-14201 (Sempra Energy), Commission File Number 1-40 (Pacific Lighting Corporation), Commission File Number 1-3779 (San Diego Gas & Electric Company) and/or Commission File Number 1-1402 (Southern California Gas Company).
 
The following exhibits relate to each registrant as indicated.
 
EXHIBIT 3 -- BYLAWS AND ARTICLES OF INCORPORATION
 
Sempra Energy
 
3.1  
Amended and Restated Articles of Incorporation of Sempra Energy effective May 23, 2008 (Appendix B to the 2008 Sempra Energy Definitive Proxy Statement, filed on April 15, 2008).
   
3.2  
Amended Bylaws of Sempra Energy effective December 4, 2007 (Sempra Energy Form 8-K filed on December 5, 2007, Exhibit 3(ii)).
   
3.3  
Amended and Restated Bylaws of Sempra Energy effective May 26, 1998 (Registration Statement on Form S-8 Sempra Energy Registration Statement No. 333-56161 dated June 5, 1998, Exhibit 3.2).
 
San Diego Gas & Electric Company
 
3.4  
Amended and Restated Bylaws of San Diego Gas & Electric effective June 15, 2010 (Form 8-K filed on June 17, 2010, Exhibit 3).
   
3.5  
Amended and Restated Articles of Incorporation of San Diego Gas & Electric Company effective November 10, 2006 (2006 SDG&E Form 10-K, Exhibit 3.02).
 
Southern California Gas Company
 
3.6  
Amended and Restated Bylaws of Southern California Gas Company effective June 14, 2010 (Form 8-K filed on June 17, 2010, Exhibit 3.1).
   
3.7  
Restated Articles of Incorporation of Southern California Gas Company (1996 SoCalGas Form 10-K, Exhibit 3.01).
 
EXHIBIT 4 -- INSTRUMENTS DEFINING THE RIGHTS OF SECURITY HOLDERS, INCLUDING INDENTURES
 
The companies agree to furnish a copy of each such instrument to the Commission upon request.
 
Sempra Energy
 
4.1  
Description of rights of Sempra Energy Common Stock (Amended and Restated Articles of Incorporation of Sempra Energy effective May 23, 2008, Exhibit 3.1 above).
   
4.2  
Indenture dated as of February 23, 2000, between Sempra Energy and U.S. Bank Trust National Association, as Trustee (Sempra Energy Registration Statement on Form S-3 (No. 333-153425), filed on September 11, 2008, Exhibit 4.1).
 
San Diego Gas & Electric Company
 
4.3  
Description of preferences of Cumulative Preferred Stock, Preference Stock (Cumulative) and Series Preference Stock (SDG&E Amended and Restated Articles of Incorporation as of November 10, 2006, Exhibit 3.5 above).
 
Southern California Gas Company
 
4.4  
Description of preferences of Preferred Stock, Preference Stock and Series Preferred Stock (Southern California Gas Company Restated Articles of Incorporation, Exhibit 3.7 above).
 
Sempra Energy / San Diego Gas & Electric Company
 
4.5  
Mortgage and Deed of Trust dated July 1, 1940 (SDG&E Registration Statement No. 2-49810, Exhibit 2A).
   
4.6  
Ninth Supplemental Indenture dated as of August 1, 1968 (SDG&E Registration Statement No. 2-68420, Exhibit 2D).
   
4.7  
Sixteenth Supplemental Indenture dated August 28, 1975 (SDG&E Registration Statement No. 2-68420, Exhibit 2E).
   
4.8  
Thirtieth Supplemental Indenture dated September 28, 1983 (SDG&E Registration Statement No. 33-34017, Exhibit 4.3).
 
Sempra Energy / Southern California Gas Company
 
4.9  
First Mortgage Indenture of Southern California Gas Company to American Trust Company dated October 1, 1940 (Registration Statement No. 2-4504 filed by Southern California Gas Company on September 16, 1940, Exhibit B-4).
   
4.10  
Supplemental Indenture of Southern California Gas Company to American Trust Company dated as of August 1, 1955 (Registration Statement No. 2-11997 filed by Pacific Lighting Corporation on October 26, 1955, Exhibit 4.07).
   
4.11  
Supplemental Indenture of Southern California Gas Company to American Trust Company dated as of June 1, 1956 (Registration Statement No. 2-12456 filed by Southern California Gas Company on April 23, 1956, Exhibit 2.08).
   
4.12  
Supplemental Indenture of Southern California Gas Company to American Trust Company dated as of December 1, 1956 (2006 Sempra Energy Form 10-K, Exhibit 4.09).
   
4.13  
Supplemental Indenture of Southern California Gas Company to Wells Fargo Bank dated as of June 1, 1965 (2006 Sempra Energy Form 10-K, Exhibit 4.10).
   
4.14  
Supplemental Indenture of Southern California Gas Company to Wells Fargo Bank, National Association dated as of August 1, 1972 (Registration Statement No. 2-59832 filed by Southern California Gas Company on September 6, 1977, Exhibit 2.19).
   
4.15  
Supplemental Indenture of Southern California Gas Company to Wells Fargo Bank, National Association dated as of May 1, 1976 (Registration Statement No. 2-56034 filed by Southern California Gas Company on April 14, 1976, Exhibit 2.20).
   
4.16  
Supplemental Indenture of Southern California Gas Company to Manufacturers Hanover Trust Company of California, successor to Wells Fargo Bank, National Association, and Crocker National Bank as Successor Trustee dated as of May 18, 1984 (Southern California Gas Company 1984 Form 10-K, Exhibit 4.29).
 
EXHIBIT 10 -- MATERIAL CONTRACTS
 
Sempra Energy / San Diego Gas & Electric Company / Southern California Gas Company
 
10.1  
Form of Continental Forge and California Class Action Price Reporting Settlement Agreement dated as of January 4, 2006 (Form 8-K filed on January 5, 2006, Exhibit 99.1).
   
10.2  
Form of Nevada Antitrust Settlement Agreement dated as of January 4, 2006 (Form 8-K filed on January 5, 2006, Exhibit 99.2).
 
Sempra Energy
 
10.3  
Indemnity Agreement, dated as of April 1, 2008, between Sempra Energy, Pacific Enterprises, Enova Corporation and The Royal Bank of Scotland plc (Sempra Energy March 31, 2008 Form 10-Q, Exhibit 10.2).
   
10.4  
First Amendment to Indemnity Agreement, dated as of March 30, 2009, by and among Sempra Energy, Pacific Enterprises, Enova Corporation and The Royal Bank of Scotland plc. (Sempra Energy March 31, 2009 Form 10-Q, Exhibit 10.3).
   
10.5  
Second Amendment to Indemnity Agreement, dated as of June 30, 2009, by and among Sempra Energy, Pacific Enterprises, Enova Corporation and The Royal Bank of Scotland plc. (Sempra Energy June 30, 2009 Form 10-Q, Exhibit 10.1).
   
10.6  
Third Amendment to Indemnity Agreement, dated as of December 3, 2009, by and among Sempra Energy, Pacific Enterprises, Enova Corporation and The Royal Bank of Scotland plc (2009 Sempra Energy Form 10-K, Exhibit 10.06).
   
10.7  
Fourth Amendment to Indemnity Agreement, dated as of April 15, 2011, by and among The Royal Bank of Scotland plc, Sempra Energy, Pacific Enterprises and Enova Corporation (Sempra Energy Form 8-K filed on April 21, 2011, Exhibit 10.2).
   
10.8  
Letter Agreement, dated as of April 15, 2011, by and among The Royal Bank of Scotland plc, Sempra Energy, Sempra Commodities, Inc. and Sempra Energy Holdings VII B.V. (Sempra Energy Form 8-K/A filed on April 21, 2011, Exhibit 10.1).
   
10.9  
Master Confirmation for Share Purchase Agreement, dated as of September 21, 2010, between Sempra Energy and JPMorgan Chase Bank, National Association. (Sempra Energy September 30, 2010 Form 10-Q, Exhibit 10.1).
   
10.10  
First Amendment to Purchase and Sale Agreement, dated as of June 30, 2010, entered into by and among J.P. Morgan Ventures Energy Corporation, Sempra Energy Trading LLC, RBS Sempra Commodities LLP, Sempra Energy and The Royal Bank of Scotland plc. (Sempra Energy June 30, 2010 Form 10-Q, Exhibit 10.1).
   
10.11  
Purchase and Sale Agreement, dated as of February 16, 2010, entered into by and among J.P. Morgan Ventures Energy Corporation, Sempra Energy Trading LLC, RBS Sempra Commodities LLP, Sempra Energy and The Royal Bank of Scotland plc. (Sempra Energy Form 8-K filed on February 19, 2010, Exhibit 10.1)
   
10.12  
Letter Agreement, dated as of February 16, 2010, entered into by and between Sempra Energy and The Royal Bank of Scotland plc. (Sempra Energy Form 8-K filed on February 19, 2010, Exhibit 10.2)
   
10.13  
Limited Liability Partnership Agreement, dated as of April 1, 2008, between Sempra Energy, Sempra Commodities, Inc., Sempra Energy Holdings, VII B.V., RBS Sempra Commodities LLP and The Royal Bank of Scotland plc (Sempra Energy March 31, 2008 Form 10-Q, Exhibit 10.1).
   
10.14  
First Amendment to Limited Liability Partnership Agreement, dated as of April 6, 2009 and effective as of November 14, 2008, by and among The Royal Bank of Scotland plc, Sempra Energy, Sempra Commodities, Inc., Sempra Energy Holdings VII B.V. and RBS Sempra Commodities LLP. (Sempra Energy March 31, 2009 Form 10-Q, Exhibit 10.4).
   
10.15  
Second Amendment to Limited Liability Partnership Agreement, dated December 23, 2009, by and among The Royal Bank of Scotland plc, Sempra Energy, Sempra Commodities, Inc., Sempra Energy Holdings VII B.V. and RBS Sempra Commodities LLP (2009 Sempra Energy Form 10-K, Exhibit 10.11).
   
10.16  
Master Confirmation for Share Purchase Agreement, dated as of April 1, 2008, between Sempra Energy and Merrill Lynch International (June 30, 2008 Sempra Energy Form 10-Q, Exhibit 10.4).
   
10.17  
First amendment to the Master Formation and Equity Interest Purchase Agreement, dated as of April 1, 2008, by and among Sempra Energy, Sempra Global, Sempra Energy Trading International, B.V. and The Royal Bank of Scotland plc (Sempra Energy March 31, 2008 Form 10-Q, Exhibit 10.3).
   
10.18  
Master Formation and Equity Interest Purchase Agreement, dated as of July 9, 2007, by and among Sempra Energy, Sempra Global, Sempra Energy Trading International, B.V. and The Royal Bank of Scotland plc (Sempra Energy Form 8-K filed on July 9, 2007, Exhibit 10.2).
   
10.19  
Energy Purchase Agreement between Sempra Energy Resources and the California Department of Water Resources, executed May 4, 2001 (2001 Sempra Energy Form 10-K, Exhibit 10.01).
 
Sempra Energy / San Diego Gas & Electric Company
 
10.20  
Amended and Restated Operating Order between San Diego Gas & Electric Company and the California Department of Water Resources effective March 10, 2011. (Sempra Energy March 31, 2011 Form 10-Q, Exhibit 10.4).
   
10.21  
Amended and Restated Servicing Order between San Diego Gas & Electric Company and the California Department of Water Resources effective March 10, 2011. (Sempra Energy March 31, 2011 Form 10-Q, Exhibit 10.5).
 
Compensation
 
Sempra Energy / San Diego Gas & Electric Company / Southern California Gas Company
 
10.22  
First Amendment to the Sempra Energy Employee and Director Savings Plan.
   
10.23  
Severance Pay Agreement between Sempra Energy and M. Javade Chaudhri.
   
10.24  
Severance Pay Agreement between Sempra Energy and Jessie J. Knight, Jr.
   
10.25  
Severance Pay Agreement between Sempra Energy and Michael W. Allman.
   
10.26  
Severance Pay Agreement between Sempra Energy and G. Joyce Rowland.
   
10.27  
Amended and Restated Sempra Energy Severance Pay Agreement between Sempra Energy and Debra L. Reed (Sempra Energy Form 8-K filed on July 1, 2011, Exhibit 10.1).
   
10.28  
Amendment to Severance Pay Agreement between Sempra Energy and Mark A. Snell (Sempra Energy Form 8-K filed on September 15, 2011, Exhibit 10.1).
   
10.29  
Severance Pay Agreement between Sempra Energy and Joseph A. Householder (Sempra Energy Form 8-K filed on September 15, 2011, Exhibit 10.2).
   
10.30  
Amendment to the Amendment and Restatement of the Sempra Energy 2005 Deferred Compensation Plan. (2010 Sempra Energy Form 10-K, Exhibit 10.20)
   
10.31  
Amendment to the Amended and Restated Sempra Energy Severance Pay Agreement between Sempra Energy and Donald E. Felsinger (see Exhibit 10.38 below) (2010 Sempra Energy Form 10-K, Exhibit 10.21).
   
10.32  
Form of Sempra Energy 2008 Long Term Incentive Plan, 2011 Performance-Based Restricted Stock Unit Award. (Sempra Energy March 31, 2011 Form 10-Q, Exhibit 10.2).
   
10.33  
Form of Sempra Energy 2008 Long Term Incentive Plan, 2010 Performance-Based Restricted Stock Unit Award (Sempra Energy March 31, 2010 Form 10-Q, Exhibit 10.1).
   
10.34  
Form of 2009 Sempra Energy Severance Pay Agreement (2009 Sempra Energy Form 10-K, Exhibit 10.18).
   
10.35  
Form of Sempra Energy 2008 Long Term Incentive Plan, 2009 Performance-Based Restricted Stock Unit Award (March 31, 2009 Sempra Energy Form 10-Q, Exhibit 10.1).
   
10.36  
Form of Sempra Energy 2008 Long Term Incentive Plan, 2009 Nonqualified Stock Option Agreement (March 31, 2009 Sempra Energy Form 10-Q, Exhibit 10.2).
   
10.37  
Sempra Energy 2008 Long Term Incentive Plan (Appendix A to the 2008 Sempra Energy Definitive Proxy Statement, filed on April 15, 2008).
   
10.38  
Form of Indemnification Agreement with Directors and Executive Officers (June 30, 2008 Sempra Energy Form 10-Q, Exhibit 10.2).
   
10.39  
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).
   
10.40  
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).
   
10.41  
Sempra Energy Amended and Restated Executive Life Insurance Plan (2008 Sempra Energy Form 10-K, Exhibit 10.15).
   
10.42  
Amendment and Restatement of the Sempra Energy Cash Balance Restoration Plan (2008 Sempra Energy Form 10-K, Exhibit 10.16).
   
10.43  
Form of Amended and Restated Sempra Energy Severance Pay Agreement (2008 Sempra Energy Form 10-K, Exhibit 10.17).
   
10.44  
Amendment and Restatement of the Sempra Energy 2005 Deferred Compensation Plan (2008 Sempra Energy Form 10-K, Exhibit 10.18).
   
10.45  
Amendment and Restatement of the Sempra Energy Supplemental Executive Retirement Plan (2008 Sempra Energy Form 10-K, Exhibit 10.19).
   
10.46  
Sempra Energy Executive Personal Financial Planning Program Policy Document (September 30, 2004 Sempra Energy Form 10-Q, Exhibit 10.11).
   
10.47  
2003 Sempra Energy Executive Incentive Plan B (2003 Sempra Energy Form 10-K, Exhibit 10.10).
   
10.48  
Sempra Energy Executive Incentive Plan effective January 1, 2003 (2002 Sempra Energy Form 10-K, Exhibit 10.09).
   
10.49  
Amended and Restated Sempra Energy Deferred Compensation and Excess Savings Plan (September 30, 2002 Sempra Energy Form 10-Q, Exhibit 10.3).
   
10.50  
Sempra Energy Employee Stock Ownership Plan and Trust Agreement effective January 1, 2001 (September 30, 2008 Sempra Energy Form 10-Q, Exhibit 10.1).
   
10.51  
Amendment to the Amended and Restated Sempra Energy Deferred Compensation and Excess Savings Plan (2008 Sempra Energy Form 10-K, Exhibit 10.25).
   
10.52  
Sempra Energy Amended and Restated Executive Medical Plan. (2008 Sempra Energy Form 10-K, Exhibit 10.26).
   
10.53  
 
Form of Sempra Energy 1998 Long Term Incentive Plan, 2008 Performance-Based Restricted Stock Unit Award (2007 Sempra Energy Form 10-K, Exhibit 10.09).
10.54  
Form of Sempra Energy 1998 Long Term Incentive Plan, 2008 Non-Qualified Stock Option Agreement (2007 Sempra Energy Form 10-K, Exhibit 10.10).
   
10.55  
Amended and Restated Sempra Energy 1998 Long-Term Incentive Plan (June 30, 2003 Sempra Energy Form 10-Q, Exhibit 10.2).
 
Sempra Energy
 
10.56  
Form of Sempra Energy 2008 Long Term Incentive Plan, 2010 Restricted Stock Unit Award for Sempra Energy’s Board of Directors (Sempra Energy June 30, 2010 Form 10-Q, Exhibit 10.2).
   
10.57  
Sempra Energy 2008 Long Term Incentive Plan for EnergySouth, Inc. Employees and Other Eligible Individuals (Registration Statement on Form S-8 Sempra Energy Registration Statement No. 333-155191 dated November 7, 2008, Exhibit 10.1).
   
10.58  
Form of Sempra Energy 2008 Non-Employee Directors’ Stock Plan, Nonqualified Stock Option Agreement (June 30, 2008 Sempra Energy Form 10-Q, Exhibit 10.5).
   
10.59  
Sempra Energy Amended and Restated Sempra Energy Retirement Plan for Directors (June 30, 2008 Sempra Energy Form 10-Q, Exhibit 10.7).
   
10.60  
Form of Sempra Energy 1998 Non-Employee Directors’ Stock Plan Non-Qualified Stock Option Agreement (2006 Sempra Energy Form 10-K, Exhibit 10.09).
   
10.61  
Sempra Energy 1998 Non-Employee Directors’ Stock Plan (Registration Statement on Form S-8 Sempra Energy Registration Statement No. 333-56161 dated June 5, 1998, Exhibit 4.2).
 
Nuclear
 
Sempra Energy / San Diego Gas & Electric Company
 
10.62  
Nuclear Facilities Qualified CPUC Decommissioning Master Trust Agreement for San Onofre Nuclear Generating Station, approved November 25, 1987 (1992 SDG&E Form 10-K, Exhibit 10.7).
   
10.63  
Amendment No. 1 to the Qualified CPUC Decommissioning Master Trust Agreement dated September 22, 1994 (see Exhibit 10.62 above)(1994 SDG&E Form 10-K, Exhibit 10.56).
   
10.64  
Second Amendment to the San Diego Gas & Electric Company Nuclear Facilities Qualified CPUC Decommissioning Master Trust Agreement for San Onofre Nuclear Generating Station (see Exhibit 10.62 above)(1994 SDG&E Form 10-K, Exhibit 10.57).
   
10.65  
Third Amendment to the San Diego Gas & Electric Company Nuclear Facilities Qualified CPUC Decommissioning Master Trust Agreement for San Onofre Nuclear Generating Station (see Exhibit 10.62 above)(1996 SDG&E Form 10-K, Exhibit 10.59).
   
10.66  
Fourth Amendment to the San Diego Gas & Electric Company Nuclear Facilities Qualified CPUC Decommissioning Master Trust Agreement for San Onofre Nuclear Generating Station (see Exhibit 10.62 above)(1996 SDG&E Form 10-K, Exhibit 10.60).
   
10.67  
Fifth Amendment to the San Diego Gas & Electric Company Nuclear Facilities Qualified CPUC Decommissioning Master Trust Agreement for San Onofre Nuclear Generating Station (see Exhibit 10.62 above)(1999 SDG&E Form 10-K, Exhibit 10.26).
   
10.68  
Sixth Amendment to the San Diego Gas & Electric Company Nuclear Facilities Qualified CPUC Decommissioning Master Trust Agreement for San Onofre Nuclear Generating Station (see Exhibit 10.62 above)(1999 SDG&E Form 10-K, Exhibit 10.27).
   
10.69  
Seventh Amendment to the San Diego Gas & Electric Company Nuclear Facilities Qualified CPUC Decommissioning Master Trust Agreement for San Onofre Nuclear Generating Station dated December 24, 2003 (see Exhibit 10.62 above)(2003 Sempra Energy Form 10-K, Exhibit 10.42).
   
10.70  
Eighth Amendment to the San Diego Gas & Electric Company Nuclear Facilities Qualified CPUC Decommissioning Master Trust Agreement for San Onofre Nuclear Generating Station dated October 12, 2011 (see Exhibit 10.62 above).
   
10.71  
Nuclear Facilities Non-Qualified CPUC Decommissioning Master Trust Agreement for San Onofre Nuclear Generating Station, approved November 25, 1987 (1992 SDG&E Form 10-K, Exhibit 10.8).
   
10.72  
First Amendment to the San Diego Gas & Electric Company Nuclear Facilities Non-Qualified CPUC Decommissioning Master Trust Agreement for San Onofre Nuclear Generating Station (see Exhibit 10.71 above)(1996 SDG&E Form 10-K, Exhibit 10.62).
   
10.73  
Second Amendment to the San Diego Gas & Electric Company Nuclear Facilities Non-Qualified CPUC Decommissioning Master Trust Agreement for San Onofre Nuclear Generating Station (see Exhibit 10.71 above)(1996 SDG&E Form 10-K, Exhibit 10.63).
   
10.74  
Third Amendment to the San Diego Gas & Electric Company Nuclear Facilities Non-Qualified CPUC Decommissioning Master Trust Agreement for San Onofre Nuclear Generating Station (see Exhibit 10.71 above)(1999 SDG&E Form 10-K, Exhibit 10.31).
   
10.75  
Fourth Amendment to the San Diego Gas & Electric Company Nuclear Facilities Non-Qualified CPUC Decommissioning Master Trust Agreement for San Onofre Nuclear Generating Station (see Exhibit 10.71 above)(1999 SDG&E Form 10-K, Exhibit 10.32).
   
10.76  
Fifth Amendment to the San Diego Gas & Electric Company Nuclear Facilities Non-Qualified CPUC Decommissioning Master Trust Agreement for San Onofre Nuclear Generating Station dated December 24, 2003 (see Exhibit 10.71 above)(2003 Sempra Energy Form 10-K, Exhibit 10.48).
   
10.77  
Sixth Amendment to the San Diego Gas & Electric Company Nuclear Facilities Non-Qualified CPUC Decommissioning Master Trust Agreement for San Onofre Nuclear Generating Station dated October 12, 2011 (see Exhibit 10.71 above).
   
10.78  
Second Amended San Onofre Operating Agreement among Southern California Edison Company, SDG&E, the City of Anaheim and the City of Riverside, dated February 26, 1987 (1990 SDG&E Form 10-K, Exhibit 10.6).
   
10.79  
U. S. Department of Energy contract for disposal of spent nuclear fuel and/or high-level radioactive waste, entered into between the DOE and Southern California Edison Company, as agent for SDG&E and others; Contract DE-CR01-83NE44418, dated June 10, 1983 (1988 SDG&E Form 10-K, Exhibit 10N).
   
10.80  
San Onofre Unit No. 1 Decommissioning Agreement between Southern California Edison Company and San Diego Gas & Electric Company dated March 23, 2000 (2009 Sempra Energy Form 10-K, Exhibit 10.62).
   
10.81  
First Amendment to the San Onofre Unit No. 1 Decommissioning Agreement between Southern California Edison Company and San Diego Gas & Electric Company dated January 22, 2010 (2009 Sempra Energy Form 10-K, Exhibit 10.63).
 
EXHIBIT 12 -- STATEMENTS RE: COMPUTATION OF RATIOS
 
Sempra Energy
 
12.1  
Sempra Energy Computation of Ratio of Earnings to Combined Fixed Charges and Preferred Stock Dividends for the years ended December 31, 2011, 2010, 2009, 2008 and 2007.
 
San Diego Gas & Electric Company
 
12.2  
San Diego Gas & Electric Computation of Ratio of Earnings to Combined Fixed Charges and Preferred Stock Dividends for the years ended December 31, 2011, 2010, 2009, 2008 and 2007.
 
Southern California Gas Company
 
12.3  
Southern California Gas Company Computation of Ratio of Earnings to Combined Fixed Charges and Preferred Stock Dividends for the years ended December 31, 2011, 2010, 2009, 2008 and 2007.
 
EXHIBIT 13 -- ANNUAL REPORT TO SECURITY HOLDERS
 
Sempra Energy / San Diego Gas & Electric Company / Southern California Gas Company
 
13.1  
Sempra Energy 2011 Annual Report to Shareholders. (Such report, except for the portions thereof which are expressly incorporated by reference in this Annual Report, is furnished for the information of the Securities and Exchange Commission and is not to be deemed “filed” as part of this Annual Report).
 
EXHIBIT 14 -- CODE OF ETHICS
 
 San Diego Gas & Electric Company / Southern California Gas Company
 
14.1  
Sempra Energy Code of Business Conduct and Ethics for Board of Directors and Senior Officers (also applies to directors and officers of San Diego Gas & Electric Company and Southern California Gas Company) (2006 SDG&E and SoCalGas Forms 10-K, Exhibit 14.01).
 
EXHIBIT 21 -- SUBSIDIARIES
 
Sempra Energy
 
21.1  
Sempra Energy Schedule of Significant Subsidiaries at December 31, 2011.
 
EXHIBIT 23 -- CONSENTS OF EXPERTS AND COUNSEL
 
23.1  
Consents of Independent Registered Public Accounting Firm and Report on Schedule, pages 40 through 42.
   
23.2  
Consent of Independent Registered Public Accounting Firm
 
EXHIBIT 31 -- SECTION 302 CERTIFICATIONS
 
Sempra Energy
 
31.1  
Statement of Sempra Energy’s Chief Executive Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.
   
31.2  
Statement of Sempra Energy’s Chief Financial Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.
 
San Diego Gas & Electric Company
 
31.3  
Statement of San Diego Gas & Electric Company’s Chief Executive Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.
   
31.4  
Statement of San Diego Gas & Electric Company’s Chief Financial Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.
 
Southern California Gas Company
 
31.5  
Statement of Southern California Gas Company’s Chief Executive Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.
   
31.6  
Statement of Southern California Gas Company’s Chief Financial Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.
 
EXHIBIT 32 -- SECTION 906 CERTIFICATIONS
 
Sempra Energy
 
32.1  
Statement of Sempra Energy’s Chief Executive Officer pursuant to 18 U.S.C. Sec. 1350.
   
32.2  
Statement of Sempra Energy’s Chief Financial Officer pursuant to 18 U.S.C. Sec. 1350.
 
San Diego Gas & Electric Company
 
32.3  
Statement of San Diego Gas & Electric Company’s Chief Executive Officer pursuant to 18 U.S.C. Sec. 1350.
   
32.4  
Statement of San Diego Gas & Electric Company’s  Chief Financial Officer pursuant to 18 U.S.C. Sec. 1350.
 
Southern California Gas Company
 
32.5  
Statement of Southern California Gas Company’s Chief Executive Officer pursuant to 18 U.S.C. Sec. 1350.
   
32.6  
Statement of Southern California Gas Company’s Chief Financial Officer pursuant to 18 U.S.C. Sec. 1350.
 
EXHIBIT 99 – ADDITIONAL EXHIBITS
 
Sempra Energy
 
99.1  
The unaudited consolidated financial statements of RBS Sempra Commodities LLP and Subsidiaries as of and for the year ended December 31, 2010 (Sempra Energy 2010 Form 10-K/A, Exhibit 99.1).
   
99.2  
The audited consolidated financial statements of RBS Sempra Commodities LLP and Subsidiaries as of December 31, 2009, and for the year ended December 31, 2009, and the period from April 1, 2008 (Date of Commencement) to December 31, 2008, and Report of Independent Registered Public Accounting Firm (Sempra Energy 2010 Form 10-K/A, Exhibit 99.2).
 
EXHIBIT 101 -- INTERACTIVE DATA FILE
 
101.INS  
XBRL Instance Document
   
101.SCH  
XBRL Taxonomy Extension Schema Document
   
101.CAL  
XBRL Taxonomy Extension Calculation Linkbase Document
   
101.DEF  
XBRL Taxonomy Extension Definition Linkbase Document
   
101.LAB  
XBRL Taxonomy Extension Label Linkbase Document
   
101.PRE  
XBRL Taxonomy Extension Presentation Linkbase Document
   





 
 
 
 

GLOSSARY
 
 
 
 
 
 
 
 
 
 
Annual Report
2011 Annual Report to Shareholders
 
LNG
Liquefied natural gas
Bcf
Billion cubic feet (of natural gas)
 
Luz del Sur
Luz del Sur S.A.A.
CARB
California Air Resources Board
 
Mobile Gas
Mobile Gas Service Corporation
CEC
California Energy Commission
 
MW
Megawatt
Chilquinta Energía
Chilquinta Energía S.A.
 
NRC
Nuclear Regulatory Commission
CNE
Comisión Nacional de Energía (National Energy Commission)
 
OSINERGMIN
Organismo Supervisor de la Inversión en Energía y Minería (Energy and Mining Investment Supervisory Body)
CPUC
California Public Utilities Commission
 
PEMEX
Petroleos Mexicanos (Mexican state-owned oil company)
CRE
Comisión Reguladora de Energía (Energy Regulatory Commission)
 
PGE
Portland General Electric Company
DOE
U.S. Department of Energy
 
QFs
Qualifying Facilities
DOT
Department of Transportation
 
RBS
The Royal Bank of Scotland plc
DWR
Department of Water Resources
 
RBS Sempra Commodities
RBS Sempra Commodities LLP
Edison
Southern California Edison Company
 
Rockies Express
Rockies Express Pipeline LLC
EPA
Environmental Protection Agency
 
RPS
Renewables Portfolio Standard
ERR
Eligible Renewable Energy Resource
 
SDG&E
San Diego Gas & Electric Company
FERC
Federal Energy Regulatory Commission
 
SEC
Securities and Exchange Commission
GHG
Greenhouse Gas
 
Sempra Utilities
San Diego Gas & Electric Company and Southern California Gas Company
IOUs
Investor-Owned Utilities
 
SoCalGas
Southern California Gas Company
ISFSI
Independent Spent Fuel Storage Installation
 
SONGS
San Onofre Nuclear Generating Station
kV
Kilovolt
 
The Board
Sempra Energy’s board of directors


 
 
 
 

Exhibit 10.22


Exhibit 10.22


FIRST AMENDMENT
TO THE SEMPRA ENERGY
EMPLOYEE AND DIRECTOR SAVINGS PLAN

Sempra Energy maintains the Sempra Energy Employee and Director Savings Plan (the “Plan”).  In order to amend the Plan in certain respects, this First Amendment to the Plan is hereby adopted, effective as of January 1, 2012.

The Plan is hereby amended, effective January 1, 2012 as follows:

1.

Section 3.1(c)(1) and (2) of the Plan are hereby amended in their entirety to read as follows:

“(1) Each Participant who is a Manager shall be permitted to defer, in any whole percentage: (A) from 6% to 85% of Base Salary and (B) from 6% to 85% of his Bonus.

(2) Each Participant who is an Executive Officer shall be permitted to defer, in any whole percentage: (A) from 6% to 85% of Base Salary, (B) from 6% to 85% of his Bonus and (C) from 10% to 100% of his Restricted Stock Units, Stock Option Gains, Severance Payments and SERP Lump Sum, subject to Section 3.1(b).”

Executed at San Diego, California this 7th day of November, 2011.

SEMPRA ENERGY

By:

______________________________

Title:

______________________________

Date:

______________________________




 


Exhibit 10.23


Exhibit 10.23




SEMPRA ENERGY
SEVERANCE PAY AGREEMENT

THIS AGREEMENT (this “Agreement”), dated as of October 1, 2011 (the “Effective Date”), is made by and between SEMPRA ENERGY, a California corporation (“Sempra Energy”), and M. JAVADE CHAUDHRI (the “Executive”).

WHEREAS, the Executive is currently employed by Sempra Energy or a direct or indirect subsidiary of Sempra Energy (Sempra Energy and its subsidiaries are hereinafter collectively referred to as the “Company”) as Executive Vice President and Chief General Counsel; and

WHEREAS, Sempra Energy and the Executive desire to enter into this Agreement; and

WHEREAS, the Board of Directors of Sempra Energy (the “Board”) has authorized this Agreement.

NOW, THEREFORE, in consideration of the premises and mutual covenants herein contained, the Company and the Executive hereby agree as follows:

Section 1.

Definitions.  For purposes of this Agreement, the following capitalized terms have the meanings set forth below:

Accounting Firm” has the meaning assigned thereto in Section 9(b) hereof.

Act” has the meaning assigned thereto in Section 2 hereof.

Additional Post-Change in Control Severance Payment” has the meaning assigned thereto in Section 6(a) hereof.

Affiliate” has the meaning set forth in Rule 12b-2 promulgated under the Exchange Act.

Annual Base Salary” means the Executive’s annual base salary from the Company.

Asset Purchaser” has the meaning assigned thereto in Section 16(e).

Asset Sale” has the meaning assigned thereto in Section 16(e).

Average Annual Bonus” means the average of the annual bonuses from the Company earned by the Executive with respect to the three (3) fiscal years of the Company immediately preceding the Date of Termination (the “Bonus Fiscal Years”); provided, however, that, if the Executive was employed by the Company during all or any portion of one or two of the Bonus Fiscal Years (but not three of the Bonus Fiscal Years), “Average Annual Bonus” means the average of the annual bonuses (if any) from the Company earned by the Executive with respect to the Bonus Fiscal Years during all or any portion of which the Executive was employed by the Company; and, provided, further, that, if the Executive was not employed by the Company during all or any portion of any of the Bonus Fiscal Years, “Average Annual Bonus” means zero.

Beneficial Owner” has the meaning set forth in Rule 13d-3 promulgated under the Exchange Act.

Cause” means:  

(a)

Prior to a Change in Control, (i) the willful failure by the Executive to substantially perform the Executive’s duties with the Company (other than any such failure resulting from the Executive’s incapacity due to physical or mental illness, (ii) the grossly negligent performance of such obligations referenced in clause (i) of this definition, (iii) the Executive’s gross insubordination; and/or (iv) the Executive’s commission of one or more acts of moral turpitude that constitute a violation of applicable law (including but not limited to a felony) which have or result in an adverse effect on the Company, monetarily or otherwise, or one or more significant acts of dishonesty.  For purposes of clause (i) of this subsection (a), no act, or failure to act, on the Executive’s part shall be deemed “willful” unless done, or omitted to be done, by the Executive not in good faith and without reasonable belief that the Executive’s act, or failure to act, was in the best interests of the Company.  

(b)

From and after a Change in Control, (i) the willful and continued failure by the Executive to substantially perform the Executive’s duties with the Company (other than any such failure resulting from the Executive’s incapacity due to physical or mental illness or any such actual or anticipated failure after the issuance of a Notice of Termination for Good Reason by the Executive pursuant to Section 3 hereof) and/or (ii) the Executive’s commission of one or more acts of moral turpitude that constitute a violation of applicable law (including but not limited to a felony) which have or result in an adverse effect on the Company, monetarily or otherwise, or one or more significant acts of dishonesty.  For purposes of clause (i) of this subsection (b), no act, or failure to act, on the Executive’s part shall be deemed “willful” unless done, or omitted to be done, by the Executive not in good faith and without reasonable belief that the Executive’s act, or failure to act, was in the best interests of the Company.  Notwithstanding the foregoing, the Executive shall not be deemed terminated for Cause pursuant to clause (i) of this subsection (b) unless and until the Executive shall have been provided with reasonable notice of and, if possible, a reasonable opportunity to cure the facts and circumstances claimed to provide a basis for termination of the Executive’s employment for Cause.

Change in Control” shall be deemed to have occurred on the date that a change in the ownership of Sempra Energy, a change in the effective control of Sempra Energy, or a change in the ownership of a substantial portion of assets of Sempra Energy occurs (each, as defined in subsection (a) below), except as otherwise provided in subsections (b), (c) and (d) below:

(a)

(i)

a “change in the ownership of Sempra Energy” occurs on the date that any one person, or more than one person acting as a group, acquires ownership of stock of Sempra Energy that, together with stock held by such person or group, constitutes more than fifty percent (50%) of the total fair market value or total voting power of the stock of Sempra Energy,

(ii)

a “change in the effective control of Sempra Energy” occurs only on either of the following dates:

(A)

the date any one person, or more than one person acting as a group, acquires (or has acquired during the twelve (12) month period ending on the date of the most recent acquisition by such person or persons) ownership of stock of Sempra Energy possessing thirty percent (30%) or more of the total voting power of the stock of Sempra Energy, or

(B)

the date a majority of the members of the Board is replaced during any twelve (12) month period by directors whose appointment or election is not endorsed by a majority of the members of the Board before the date of appointment or election, and

(iii)

a “change in the ownership of a substantial portion of assets of Sempra Energy” occurs on the date any one person, or more than one person acting as a group, acquires (or has acquired during the twelve (12) month period ending on the date of the most recent acquisition by such person or persons) assets from Sempra Energy that have a total gross fair market value equal to or more than eighty-five percent (85%) of the total gross fair market value of all of the assets of Sempra Energy immediately before such acquisition or acquisitions.

(b)

A “change in the ownership of Sempra Energy” or “a change in the effective control of Sempra Energy” shall not occur under clause (a)(i) or (a)(ii) by reason of any of the following:

(i)

an acquisition of ownership of stock of Sempra Energy directly from Sempra Energy or its Affiliates other than in connection with the acquisition by Sempra Energy or its Affiliates of a business,

(ii)

a merger or consolidation which would result in the voting securities of Sempra Energy outstanding immediately prior to such merger or consolidation continuing to represent (either by remaining outstanding or by being converted into voting securities of the surviving entity or any parent thereof), in combination with the ownership of any trustee or other fiduciary holding securities under an employee benefit plan of the Company, at least sixty percent (60%) of the combined voting power of the securities of Sempra Energy or such surviving entity or any parent thereof outstanding immediately after such merger or consolidation, or

(iii)

a merger or consolidation effected to implement a recapitalization of Sempra Energy (or similar transaction) in which no Person is or becomes the Beneficial Owner, directly or indirectly, of securities of Sempra Energy (not including the securities beneficially owned by such Person any securities acquired directly from Sempra Energy or its Affiliates other than in connection with the acquisition by Sempra Energy or its Affiliates of a business) representing twenty percent (20%) or more of the combined voting power of Sempra Energy’s then outstanding securities.

(c)

A “change in the ownership of a substantial portion of assets of Sempra Energy” shall not occur under clause (a)(iii) by reason of a sale or disposition by Sempra Energy of the assets of Sempra Energy to an entity, at least sixty percent (60%) of the combined voting power of the voting securities of which are owned by shareholders of Sempra Energy in substantially the same proportions as their ownership of Sempra Energy immediately prior to such sale.

(d)

This definition of “Change in Control” shall be limited to the definition of a “change in control event” relating to Sempra Energy under Treasury Regulation Section 1.409A-3(i)(5).  A “Change in Control” shall only occur if there is a “change in control event” relating to Sempra Energy under Treasury Regulation Section 1.409A-3(i)(5) with respect to the Executive.

Change in Control Date” means the date on which a Change in Control occurs.

Code” means the Internal Revenue Code of 1986, as amended.

Compensation Committee” means the compensation committee of the Board.

Consulting Period” has the meaning assigned thereto in Section 14(e) hereof.

Date of Termination” has the meaning assigned thereto in Section 3(b) hereof.

Deferred Compensation Plan” has the meaning assigned thereto in Section 5(f) hereof.

Disability” has the meaning set forth in the Company’s long-term disability plan or its successor; provided, however, that the Board may not terminate the Executive’s employment hereunder by reason of Disability unless (i) at the time of such termination there is no reasonable expectation that the Executive will return to work within the next ninety (90) day period and (ii) such termination is permitted by all applicable disability laws.  

Exchange Act” means the Securities Exchange Act of 1934, as amended, and the applicable rulings and regulations thereunder.

Excise Tax” has the meaning assigned thereto in Section 9(a) hereof.

Good Reason” means:

(a)

Prior to a Change in Control, the occurrence of any of the following without the prior written consent of the Executive, unless such act or failure to act is corrected by the Company prior to the Date of Termination specified in the Notice of Termination (as required under Section 3 hereof):

(i)

the assignment to the Executive of any duties materially inconsistent with the range of duties and responsibilities appropriate to a senior Executive within the Company (such range determined by reference to past, current and reasonable practices within the Company);

(ii)

a material reduction in the Executive’s overall standing and responsibilities within the Company, but not including (A) a mere change in title or (B) a transfer within the Company, which, in the case of both (A) and (B), does not adversely affect the Executive’s overall status within the Company;

(iii)

a material reduction by the Company in the Executive’s aggregate annualized compensation and benefits opportunities, except for across-the-board reductions (or modifications of benefit plans) similarly affecting all similarly situated executives (both of the Company and of any Person then in control of the Company) of comparable rank with the Executive;

(iv)

the failure by the Company to pay to the Executive any portion of the Executive’s current compensation and benefits or any portion of an installment of deferred compensation under any deferred compensation program of the Company within thirty (30) days of the date such compensation is due;

(v)

any purported termination of the Executive’s employment that is not effected pursuant to a Notice of Termination satisfying the requirements of Section 3 hereof; for purposes of this Agreement, no such purported termination shall be effective;

(vi)

the failure by Sempra Energy to perform its obligations under Section 16(c), (d) or (e) hereof;

(vii)

the failure by the Company to provide the indemnification and D&O insurance protection Section 11 of this Agreement requires it to provide; or

(viii)

the failure by Sempra Energy to comply with any material provision of this Agreement.

(b)

From and after a Change in Control, the occurrence of any of the following without the prior written consent of the Executive, unless such act or failure to act is corrected by the Company prior to the Date of Termination specified in the Notice of Termination (as required under Section 3 hereof):

(i)

an adverse change in the Executive’s title, authority, duties, responsibilities or reporting lines as in effect immediately prior to the Change in Control;

(ii)

a reduction by the Company in the Executive’s aggregate annualized compensation opportunities, except for across-the-board reductions in base salaries, annual bonus opportunities or long-term incentive compensation opportunities of less than ten percent (10%) similarly affecting all similarly situated executives (both of the Company and of any Person then in control of the Company) of comparable rank with the Executive; or the failure by the Company to continue in effect any material benefit plan in which the Executive participates immediately prior to the Change in Control, unless an equitable arrangement (embodied in an ongoing substitute or alternative plan) has been made with respect to such plan, or the failure by the Company to continue the Executive's participation therein (or in such substitute or alternative plan) on a basis not materially less favorable, both in terms of the amount of benefits provided and the level of the Executive's participation relative to other participants, as existed at the time of the Change in Control;

(iii)

the relocation of the Executive’s principal place of employment immediately prior to the Change in Control Date (the “Principal Location”) to a location which is both further away from the Executive’s residence and more than thirty (30) miles from such Principal Location, or the Company’s requiring the Executive to be based anywhere other than such Principal Location (or permitted relocation thereof), or a substantial increase in the Executive’s business travel obligations outside of the Southern California area as of the Effective Date other than any such increase that (A) arises in connection with extraordinary business activities of the Company of limited duration and (B) is understood not to be part of the Executive’s regular duties with the Company;

(iv)

the failure by the Company to pay to the Executive any portion of the Executive’s current compensation and benefits or any portion of an installment of deferred compensation under any deferred compensation program of the Company within thirty (30) days of the date such compensation is due;

(v)

any purported termination of the Executive’s employment that is not effected pursuant to a Notice of Termination satisfying the requirements of Section 3 hereof; for purposes of this Agreement, no such purported termination shall be effective;

(vi)

the failure by Sempra Energy to perform its obligations under Section 16(c), (d) or (e) hereof;

(vii)

the failure by the Company to provide the indemnification and D&O insurance protection Section 11 of this Agreement requires it to provide; or

(viii)

the failure by Sempra Energy to comply with any material provision of this Agreement.

Following a Change in Control, the Executive’s determination that an act or failure to act constitutes Good Reason shall be presumed to be valid unless such determination is deemed to be unreasonable by an arbitrator pursuant to the procedure described in Section 13 hereof.  The Executive’s right to terminate the Executive’s employment for Good Reason shall not be affected by the Executive’s incapacity due to physical or mental illness.  The Executive’s continued employment shall not constitute consent to, or a waiver of rights with respect to, any act or failure to act constituting Good Reason hereunder.

Incentive Compensation Awards” means awards granted under Incentive Compensation Plans providing the Executive with the opportunity to earn, on a year-by-year basis, annual and long-term incentive compensation.

Incentive Compensation Plans” means annual incentive compensation plans and long-term incentive compensation plans of the Company, which long-term incentive compensation plans may include plans offering stock options, restricted stock and other long-term incentive compensation.

Involuntary Termination” means (a) the Executive’s Separation from Service by reason of a termination of employment by the Company other than for Cause, death, or Disability, or (b) the Executive’s Separation from Service by reason of resignation of employment with the Company for Good Reason.    

JAMS Rules” has the meaning assigned thereto in Section 13 hereof.

Notice of Termination” has the meaning assigned thereto in Section 3(a) hereof.

Payment” has the meaning assigned thereto in Section 9(a) hereof.

Payment in Lieu of Notice” has the meaning assigned thereto in Section 3(b) hereof.

Person” has the meaning set forth in section 3(a)(9) of the Exchange Act, as modified and used in sections 13(d) and 14(d) thereof, except that such term shall not include (i) the Company or any of its Affiliates, (ii) a trustee or other fiduciary holding securities under an employee benefit plan of the Company or any of its Affiliates, (iii) an underwriter temporarily holding securities pursuant to an offering of such securities, (iv) a corporation owned, directly or indirectly, by the shareholders of the Company in substantially the same proportions as their ownership of stock of the Company, or (v) a person or group as used in Rule 13d-1(b) promulgated under the Exchange Act.

Post-Change in Control Accrued Obligations” has the meaning assigned thereto in Section 6(a) hereof.

Post-Change in Control Severance Payment” has the meaning assigned thereto in Section 6 hereof.

Pre-Change in Control Accrued Obligations” has the meaning assigned thereto in Section 5(a) hereof.

Pre-Change in Control Severance Payment” has the meaning assigned thereto in Section 5 hereof.

Principal Location” has the meaning assigned thereto in clause (b)(iii) of the definition of Good Reason, above.

Proprietary Information” has the meaning assigned thereto in Section 14(a) hereof.

Release” has the meaning assigned thereto in Section 14(d) hereof.

Section 409A Payments” means any of the following:  (a) the Payment in Lieu of Notice, (b) the Pre-Change in Control Severance Payment, (c) the Post-Change in Control Severance Payment, (d) the Additional Post-Change in Control Severance Payment, (e) the Consulting Payment, (f) the payment under Section 6(b) (but only to the extent such payment or portion thereof is subject to Section 409A of the Code), (g) the financial planning services provided under Sections 5(e) and 6(f), and (h) the legal fees and expenses reimbursed under Section 15.

Sempra Energy Control Group” means Sempra Energy and all persons with whom Sempra Energy would be considered a single employer under Section 414(b) or 414(c) of the Code, as determined from time to time.

Separation from Service”, with respect to the Executive (or another Service Provider), means the Executive’s (or such Service Provider’s) (a) termination of employment or (b) other termination or reduction in services, provided that such termination or reduction in clause (a) or (b) constitutes a “separation from service,” as defined in Treasury Regulation Section 1.409A-1(h), with respect to the Service Recipient.

SERP” has the meaning assigned thereto in Section 6(b) hereof.

Service Provider” means the Executive or any other “service provider,” as defined in Treasury Regulation Section 1.409A-1(f).

Service Recipient,” with respect to the Executive, means Sempra Energy (if the Executive is employed by Sempra Energy), or the subsidiary of Sempra Energy employing the Executive, whichever is applicable, and all persons considered part of the “service recipient,” as defined in Treasury Regulation Section 1.409A-1(g), as determined from time to time.  As provided in Treasury Regulation Section 1.409A-1(g), the “Service Recipient” shall mean the person for whom the services are performed and with respect to whom the legally binding right to compensation arises, and all persons with whom such person would be considered a single employer under Section 414(b) or 414(c) of the Code.

Specified Employee” means a Service Provider who, as of the date of the Service Provider’s Separation from Service is a “Key Employee” of the Service Recipient any stock of which is publicly traded on an established securities market or otherwise.  For purposes of this definition, a Service Provider is a “Key Employee” if the Service Provider meets the requirements of Section 416(i)(1)(A)(i), (ii) or (iii) of the Code (applied in accordance with the Treasury Regulations thereunder and disregarding Section 416(i)(5) of the Code) at any time during the Testing Year.  If a Service Provider is a “Key Employee” (as defined above) as of a Specified Employee Identification Date, the Service Provider shall be treated as “Key Employee” for the entire twelve (12) month period beginning on the Specified Employee Effective Date.  For purposes of this definition, a Service Provider’s compensation for a Testing Year shall mean such Service Provider’s compensation, as determined under Treasury Regulation Section 1.415(c)-2(a) (and applied as if the Service Recipient were not using any safe harbor provided in Treasury Regulation Section 1.415(c)-2(d), were not using any of the elective special timing rules provided in Treasury Regulation Section 1.415(c)-2(e), and were not using any of the elective special rules provided in Treasury Regulation Section 1.415(c)-2(g)), from the Service Recipient for such Testing Year.  The “Specified Employees” shall be determined in accordance with Section 409A(a)(2)(B)(i) of the Code and Treasury Regulation Section 1.409A-1(i).

Specified Employee Effective Date” means the first day of the fourth month following the Specified Employee Identification Date.  The Specified Employee Effective Date may be changed by Sempra Energy, in its discretion, in accordance with Treasury Regulation Section 1.409A-1(i)(4).

Specified Employee Identification Date”, for purposes of Treasury Regulation Section 1.409A-1(i)(3), shall mean December 31.  The “Specified Employee Identification Date” shall apply to all “nonqualified deferred compensation plans” (as defined in Treasury Regulation Section 1.409A-1(a)) of the Service Recipient and all affected Service Providers.  The “Specified Employee Identification Date” may be changed by Sempra Energy, in its discretion, in accordance with Treasury Regulation Section 1.409A-1(i)(3).

Testing Year” shall mean the twelve (12) month period ending on the Specified Employee Identification Date, as determined from time to time.

Underpayment” has the meaning assigned thereto in Section 9(b) hereof.

For purposes of this Agreement, references to any “Treasury Regulation” shall mean such Treasury Regulation as in effect on the date hereof.

Section 2.

Sarbanes-Oxley Act of 2002.  Notwithstanding anything herein to the contrary, if the Company determines, in its good faith judgment, that any provision of this Agreement is likely to be interpreted as a personal loan prohibited by the Sarbanes-Oxley Act of 2002 and the rules and regulations promulgated thereunder (the “Act”), then such provision shall be modified as necessary or appropriate so as to not violate the Act; and if this cannot be accomplished, then the Company shall use its reasonable efforts to provide the Executive with similar, but lawful, substitute benefit(s) at a cost to the Company not to significantly exceed the amount the Company would have otherwise paid to provide such benefit(s) to the Executive.  In addition, if the Executive is required to forfeit or to make any repayment of any compensation or benefit(s) to the Company under the Act or any other law, such forfeiture or repayment shall not constitute Good Reason.

Section 3.

Notice and Date of Termination.  

(a)

Any termination of the Executive’s employment by the Company or by the Executive shall be communicated by a written notice of termination to the other party (the “Notice of Termination”).  Where applicable, the Notice of Termination shall indicate the specific termination provision in this Agreement relied upon and shall set forth in reasonable detail the facts and circumstances claimed to provide a basis for termination of the Executive’s employment under the provision so indicated.  Unless the Board determines otherwise, a Notice of Termination by the Executive alleging a termination for Good Reason must be made within 180 days of the act or failure to act that the Executive alleges to constitute Good Reason.  

(b)

The date of the Executive’s termination of employment with the Company (the “Date of Termination”) shall be determined as follows:  (i) if the Executive has a Separation from Service by reason of the Company terminating his or her employment, either with or without Cause, the Date of Termination shall be the date specified in the Notice of Termination (which, in the case of a termination by the Company other than for Cause, shall not be less than two (2) weeks from the date such Notice of Termination is given unless the Company elects to pay the Executive, in addition to any other amounts payable hereunder, an amount (the “Payment in Lieu of Notice”) equal to two (2) weeks of the Executive’s Annual Base Salary in effect on the Date of Termination), and (ii) if the basis for the Executive’s Involuntary Termination is his resignation for Good Reason, the Date of Termination shall be determined by the Executive and specified in the Notice of Termination, but shall not in any event be less than fifteen (15) days nor more than sixty (60) days after the date such Notice of Termination is given.   The Payment in Lieu of Notice shall be paid on such date as is determined by the Company within thirty (30) days after the date of the Executive’s Separation from Service; provided, however, that if the Executive is a Specified Employee on the date of his or her Separation from Service, such Payment in Lieu of Notice shall be paid as provided in Section 10 hereof.

Section 4.

Termination from the Board.  Upon the termination of the Executive’s employment for any reason, the Executive’s membership on the Board, the board of directors of any of the Company’s Affiliates, any committees of the Board and any committees of the board of directors of any of the Company’s Affiliates, if applicable, shall be automatically terminated.

Section 5.

Severance Benefits upon Involuntary Termination Prior to Change in Control.  Except as provided in Section 6 and Section 19(i) hereof, in the event of the Involuntary Termination of the Executive prior to a Change in Control, the Company shall pay the Executive, in one lump sum cash payment, an amount (the “Pre-Change in Control Severance Payment”) equal to the greater of:  (X) 170% of the Executive’s Annual Base Salary as in effect on the Date of Termination, and (Y) the Executive’s Annual Base Salary as in effect on the Date of Termination, plus the Executive’s Average Annual Bonus.  In addition to the Pre-Change in Control Severance Payment, the Executive shall be entitled to the following additional benefits specified in subsections (a) through (e).  Except as provided in Section 5(f), the Pre-Change in Control Severance Payment and the payment under Section 5(a) shall be paid on such date as is determined by the Company within thirty (30) days after the date of the Involuntary Termination; provided, however, that, if the Executive is a Specified Employee on the date of the Executive’s Involuntary Termination, the Pre-Change in Control Severance Payment and the financial planning services provided under Section 5(e) shall be paid as provided in Section 10 hereof.  

(a)

Accrued Obligations.  The Company shall pay the Executive a lump sum amount in cash equal to the sum of (A) the Executive’s Annual Base Salary through the Date of Termination to the extent not theretofore paid, (B) an amount equal to any annual Incentive Compensation Awards earned with respect to fiscal years ended prior to the year that includes the Date of Termination to the extent not theretofore paid, (C) any accrued and unpaid vacation, if any, and (D) reimbursement for unreimbursed business expenses, if any, properly incurred by the Executive in the performance of his duties in accordance with policies established from time to time by the Board, in each case to the extent not theretofore paid.  (The amounts specified in clauses (A), (B), (C) and (D) shall be hereinafter referred to as the “Pre-Change in Control Accrued Obligations”).

(b)

Equity Based Compensation.  The Executive shall retain all rights to any equity-based compensation awards to the extent set forth in the applicable plan and/or award agreement.

(c)

Welfare Benefits.  Subject to Section 12 below, for a period of twelve (12) months following the date of the Involuntary Termination (and an additional twelve (12) months if the Executive provides consulting services under Section 14(e) hereof), the Executive and his dependents shall be provided with health insurance benefits substantially similar to those provided to the Executive and his dependents immediately prior to the date of the Involuntary Termination; provided, however, that such benefits shall be provided on substantially the same terms and conditions and at the same cost to the Executive as in effect immediately prior to the date of the Involuntary Termination.  Such benefits shall be provided through insurance maintained by the Company under the Company’s benefit plans.  Such benefits shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(a)(5).

(d)

Outplacement Services.  The Executive shall receive reasonable outplacement services, on an in-kind basis, suitable to his position and directly related to the Executive’s Involuntary Termination, for a period of twenty-four (24) months following the date of the Involuntary Termination, in an aggregate amount of cost to the Company not to exceed $50,000.  Notwithstanding the foregoing, the Executive shall cease to receive outplacement services on the date the Executive accepts employment with a subsequent employer.  Such outplacement services shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(b)(9)(v)(A).

(e)

Financial Planning Services.  The Executive shall receive financial planning services, on an in-kind basis, for a period of twenty-four (24) months following the Date of Termination.  Such financial planning services shall include expert financial and legal resources to assist the Executive with financial planning needs and shall be limited to (i) current investment portfolio management, (ii) tax planning, (iii) tax return preparation, and (iv) estate planning advice and document preparation (including wills and trusts); provided, however, that the Company shall provide such financial planning services during any taxable year of the Executive only to the extent the cost to the Company for such taxable year does not exceed $25,000.  The Company shall provide such financial planning services through a financial planner selected by the Company, and shall pay the fees for such financial planning services.  The financial planning services provided during any taxable year of the Executive shall not affect the financial planning services provided in any other taxable year of the Executive.  The Executive’s right to financial planning services shall not be subject to liquidation or exchange for any other benefit.  Such financial planning services shall be provided in a manner that complies with Treasury Regulation Section 1.409A-3(i)(1)(iv).  

(f)

Deferral of Payments.  The Executive shall have the right to elect to defer the Pre-Change in Control Severance Payment to be received by the Executive pursuant to this Section 5 under the terms and conditions of the Sempra Energy 2005 Deferred Compensation Plan (the “Deferred Compensation Plan”).  Any such deferral election shall be made in accordance with Section 18(b) hereof.

Section 6.

Severance Benefits upon Involuntary Termination in Connection with and after Change in Control.  Notwithstanding the provisions of Section 5 above, and except as provided in Section 19(i) hereof, in the event of the Involuntary Termination of the Executive on or within two (2) years following a Change in Control, in lieu of the payments described in Section 5 above, the Company shall pay the Executive, in one lump sum cash payment, an amount (the “Post-Change in Control Severance Payment”) equal to two times the greater of:  (X)  170% of the Executive’s Annual Base Salary as in effect immediately prior to the Change in Control or the Date of Termination, whichever is greater, and (Y) the Executive’s Annual Base Salary as in effect immediately prior to the Change in Control or on the Date of Termination, whichever is greater, plus the Executive’s Average Annual Bonus.  In addition to the Post-Change in Control Severance Payment, the Executive shall be entitled to the following additional benefits specified in subsections (a) through (f).  Except as provided in Sections 6(g) and 6(h), the Post-Change in Control Severance Payment and the payments under Sections 6(a) and (b) shall be paid on such date as is determined by the Company within thirty (30) days after the date of the Involuntary Termination; provided, however, that, if the Executive is a Specified Employee on the date of the Executive’s Involuntary Termination, the Post-Change in Control Severance Payment, the Additional Post-Change in Control Severance Payment under Section 6(a)(E), the payment under Section 6(b) (but only to the extent such payment or portion thereof is subject to Section 409A of the Code), and the financial planning services provided under Section 6(f) shall be paid as provided in Section 10 hereof.

(a)

Accrued Obligations.  The Company shall pay the Executive a lump sum amount in cash equal to the sum of (A) the Executive’s Annual Base Salary through the Date of Termination to the extent not theretofore paid, (B) an amount equal to any annual Incentive Compensation Awards earned with respect to fiscal years ended prior to the year that includes the Date of Termination to the extent not theretofore paid, (C) any accrued and unpaid vacation, if any, (D) reimbursement for unreimbursed business expenses, if any, properly incurred by the Executive in the performance of his duties in accordance with policies established from time to time by the Board, and (E) an amount (the “Additional Post-Change in Control Severance Payment”) equal to:  (i) the greater of:  (X) 70% of the Executive’s Annual Base Salary as in effect immediately prior to the Change in Control or on the Date of Termination, whichever is greater, or (Y) the Executive’s Average Annual Bonus, multiplied by (ii) a fraction, the numerator of which shall be the number of days from the beginning of such fiscal year to and including the Date of Termination and the denominator of which shall be 365, in the case of each amount described in clause (A), (B), (C) or (D) to the extent not theretofore paid.  (The amounts specified in clauses (A), (B), (C), (D) and (E) shall be hereinafter referred to as the “Post-Change in Control Accrued Obligations”).

(b)

Pension Supplement.  The Executive shall be entitled to receive a Supplemental Retirement Benefit under the Sempra Energy Supplemental Executive Retirement Plan, as in effect from time to time (“SERP”), determined in accordance with this Section 6(b), in the event that the Executive is a “Participant” (as defined in the SERP) as of the Date of Termination.  Such Supplemental Retirement Benefit shall be determined by crediting the Executive with additional months of Service (if any) equal to the number of full calendar months from the Date of Termination to the date on which the Executive would have attained age 62.  The Executive shall be entitled to receive such Supplemental Retirement Benefit without regard to whether the Executive has attained age 55 or completed five years of “Service” (as defined in the SERP) as of the Date of Termination.  The Executive shall be treated as qualified for “Retirement” (as defined in the SERP) as of the Date of Termination, and the Executive’s Vesting Factor with respect to the Supplemental Retirement Benefit shall be 100%.  The Executive’s Supplemental Retirement Benefit shall be calculated based on the Executive’s actual age as of the date of commencement of payment of such Supplemental Retirement Benefit (the “SERP Distribution Date”), and by applying the applicable early retirement factors under the SERP, if the Executive has not attained age 62 but has attained age 55 as of the SERP Distribution Date.  If the Executive has not attained age 55 as of the SERP Distribution Date, the Executive’s Supplemental Retirement Benefit shall be calculated by applying the applicable early retirement factor under the SERP for age 55, and the Supplemental Retirement Benefit otherwise payable at age 55 shall be actuarially adjusted to the Executive’s actual age as of the SERP Distribution Date using the following actuarial assumptions:  (i) the applicable mortality table promulgated by the Internal Revenue Service under Section 417(e)(3) of the Code, as in effect on the first day of the calendar year in which the SERP Distribution Date occurs, and (ii) the applicable interest rate promulgated by the Internal Revenue Service under Section 417(a)(3) of the Code for the November next preceding the first day of the calendar year in which the SERP Distribution Date occurs.  The Executive’s Supplemental Retirement Benefit shall be determined in accordance with this Section 6(b), notwithstanding any contrary provisions of the SERP and, to the extent subject to Section 409A of the Code, shall be paid in accordance with Treasury Regulation Section 1.409A-3(c)(1).  The Supplemental Retirement Benefit paid to or on behalf of the Executive in accordance with this Section 6(b) shall be in full satisfaction of any and all of the benefits payable to or on behalf of the Executive under the SERP.  

(c)

Equity-Based Compensation.  Notwithstanding the provisions of any applicable equity-compensation plan or award agreement to the contrary, all equity-based Incentive Compensation Awards (including, without limitation, stock options, stock appreciation rights, restricted stock awards, restricted stock units, performance share awards, awards covered under Section 162(m) of the Code, and dividend equivalents) held by the Executive shall immediately vest and become exercisable or payable, as the case may be, as of the Date of Termination, to be exercised or paid, as the case may be, in accordance with the terms of the applicable Incentive Compensation Plan and Incentive Compensation Award agreement, and any restrictions on any such Incentive Compensation Awards shall automatically lapse; provided, however, that any such stock option or stock appreciation rights awards granted on or after June 26, 1998 shall remain outstanding and exercisable until the earlier of (A) the later of eighteen (18) months following the Date of Termination or the period specified in the applicable Incentive Compensation Award agreements or (B) the expiration of the original term of such Incentive Compensation Award (or, if earlier, the tenth anniversary of the original date of grant) (it being understood that all Incentive Compensation Awards granted prior to or after June 26, 1998 shall remain outstanding and exercisable for a period that is no less than that provided for in the applicable agreement in effect as of the date of grant).

(d)

Welfare Benefits.  Subject to Section 12 below, for a period of twenty-four (24) months following the date of Involuntary Termination (and an additional twelve (12) months if the Executive provides consulting services under Section 14(e) hereof), the Executive and his dependents shall be provided with life, disability, accident and health insurance benefits substantially similar to those provided to the Executive and his dependents immediately prior to the date of Involuntary Termination or the Change in Control Date, whichever is more favorable to the Executive; provided, however, that such benefits shall be provided on substantially the same terms and conditions and at the same cost to the Executive as in effect immediately prior to the date of Involuntary Termination or the Change in Control Date, whichever is more favorable to the Executive.  Such benefits shall be provided through insurance maintained by the Company under the Company benefit plans.  Such benefits shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(a)(5).

(e)

Outplacement Services.  The Executive shall receive reasonable outplacement services, on an in-kind basis, suitable to his position and directly related to the Executive’s Involuntary Termination, for a period of thirty-six (36) months following the date of Involuntary Termination (but in no event beyond the last day of the Executive’s second taxable year following the Executive’s taxable year in which the Involuntary Termination occurs), in the aggregate amount of cost to the Company not to exceed $50,000.  Notwithstanding the foregoing, the Executive shall cease to receive outplacement services on the date the Executive accepts employment with a subsequent employer.  Such outplacement services shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(b)(9)(v)(A).

(f)

Financial Planning Services.  The Executive shall receive financial planning services, on an in-kind basis, for a period of thirty-six (36) months following the date of Involuntary Termination.  Such financial planning services shall include expert financial and legal resources to assist the Executive with financial planning needs and shall be limited to (i) current investment portfolio management, (ii) tax planning, (iii) tax return preparation, and (iv) estate planning advice and document preparation (including wills and trusts); provided, however, that the Company shall provide such financial services during any taxable year of the Executive only to the extent the cost to the Company for such taxable year does not exceed $25,000.  The Company shall provide such financial planning services through a financial planner selected by the Company, and shall pay the fees for such financial planning services.  The financial planning services provided during any taxable year of the Executive shall not affect the financial planning services provided in any other taxable year of the Executive.  The Executive’s right to financial planning services shall not be subject to liquidation or exchange for any other benefit.  Such financial planning services shall be provided in a manner that complies with Section 1.409A-3(i)(1)(iv).   

(g)

Involuntary Termination in Connection with a Change in Control.  Notwithstanding anything contained herein, in the event of an Involuntary Termination prior to a Change in Control, if the Involuntary Termination (1) was at the request of a third party who has taken steps reasonably calculated to effect such Change in Control or (2) otherwise arose in connection with or in anticipation of such Change in Control, then the Executive shall, in lieu of the payments described in Section 5 hereof, be entitled to the Post-Change in Control Severance Payment and the additional benefits described in this Section 6 as if such Involuntary Termination had occurred within two (2) years following the Change in Control.  The amounts specified in Section 6 that are to be paid under this Section 6(g) shall be reduced by any amount previously paid under Section 5.  The amounts to be paid under this Section 6(g) shall be paid within thirty (30) days after the Change in Control Date of such Change in Control.

(h)

Deferral of Payments.  The Executive shall have the right to elect to defer the Post-Change in Control Severance Payment to be received by the Executive pursuant to this Section 6 under the terms and conditions of the Deferred Compensation Plan.  Any such deferral election shall be made in accordance with Section 18(b) hereof.

Section 7.

Severance Benefits upon Termination by the Company for Cause or by the Executive Other than for Good Reason.  If the Executive’s employment shall be terminated for Cause, or if the Executive terminates employment other than for Good Reason, the Company shall have no further obligations to the Executive under this Agreement other than the Pre-Change in Control Accrued Obligations and any amounts or benefits described in Section 11 hereof.

Section 8.

Severance Benefits upon Termination due to Death or Disability.  If the Executive has a Separation from Service by reason of death or Disability, the Company shall pay the Executive or his estate, as the case may be, the Post-Change in Control Accrued Obligations (without regard to whether a Change in Control has occurred) and any amounts or benefits described in Section 11 hereof.  Such payments shall be in addition to those rights and benefits to which the Executive or his estate may be entitled under the relevant Company plans or programs.  Such payments shall be paid on such date as determined by the Company within thirty (30) days after the date of the Separation from Service; provided, however, that if the Executive is a Specified Employee on the date of the Executive’s Separation from Service by reason of Disability, the Additional Post-Change in Control Severance Payment under Section 6(a)(E) shall be paid as provided in Section 10 hereof.

Section 9.

Limitation on Payments by the Company.  

(a)

Anything in this Agreement to the contrary notwithstanding and except as set forth in this Section 9 below, in the event it shall be determined that any payment or distribution in the nature of compensation (within the meaning of Section 280G(b)(2) of the Code) to or for the benefit of the Executive, whether paid or payable pursuant to this Agreement or otherwise (the “Payment”) would be subject (in whole or in part) to the excise tax imposed by Section 4999 of the Code, (the “Excise Tax”), then, subject to subsection (b), the Pre-Change in Control Severance Payment or the Post-Change in Control Severance Payment (whichever is applicable) payable under this Agreement shall be reduced under this subsection (a) to the amount equal to the Reduced Payment.  For such Payment payable under this Agreement, the “Reduced Payment” shall be the amount equal to the greatest portion of the Payment (which may be zero)  that, if paid, would result in no portion of any Payment being subject to the Excise Tax.  

(b)

The Pre-Change in Control Severance Benefit or the Post-Change in Control Severance Payment (whichever is applicable) payable under this Agreement shall not be reduced under subsection (a) if:  

(i)

such reduction in such Payment is not sufficient to cause no portion of any Payment to be subject to the Excise Tax, or

(ii)

the Net After-Tax Unreduced Payments (as defined below) would equal or exceed one hundred and five percent (105%) of the Net After-Tax Reduced Payments (as defined below).  

For purposes of determining the amount of any Reduced Payment under subsection (a), and the Net-After Tax Reduced Payments and the Net After-Tax Unreduced Payments, the Executive shall be considered to pay federal, state and local income and employment taxes at the Executive’s applicable marginal rates taking into consideration any reduction in federal income taxes which could be obtained from the deduction of state and local income taxes, and any reduction or disallowance of itemized deductions and personal exemptions under applicable tax law).  The applicable federal, state and local income and employment taxes and the Excise Tax (to the extent applicable) are collectively referred to as the “Taxes”.

(c)

The following definitions shall apply for purposes of this Section 9:

(i)

“Net After-Tax Reduced Payments” shall mean the total amount of all Payments that the Executive would retain, on a Net After-Tax Basis, in the event that the Payments payable under this Agreement are reduced pursuant to subsection (a).

(ii)

“Net After-Tax Unreduced Payments” shall mean the total amount of all Payments that the Executive would retain, on a Net After-Tax Basis, in the event that the Payments payable under this Agreement are not reduced pursuant to subsection (a).

(iii)

“Net After-Tax Basis” shall mean, with respect to the Payments, either with or without reduction under subsection (a) (as applicable), the amount that would be retained by the Executive from such Payments after the payment of all Taxes.

(d)

All determinations required to be made under this Section 9 and the assumptions to be utilized in arriving at such determinations, shall be made by a nationally recognized accounting firm as may be agreed by the Company and the Executive (the “Accounting Firm”); provided, that the Accounting Firm’s determination shall be made based upon “substantial authority” within the meaning of Section 6662 of the Code.  The Accounting Firm shall provide detailed supporting calculations to both the Company and the Executive within fifteen (15) business days of the receipt of notice from the Executive that there has been a Payment or such earlier time as is requested by the Company.  All fees and expenses of the Accounting Firm shall be borne solely by the Company.  Any determination by the Accounting Firm shall be binding upon the Company and the Executive.  For purposes of determining whether and the extent to which the Payments will be subject to the Excise Tax, (i) no portion of the Payments the receipt or enjoyment of which the Executive shall have waived at such time and in such manner as not to constitute a “payment” within the meaning of Section 280G(b) of the Code shall be taken into account, (ii) no portion of the Payments shall be taken into account which, in the written opinion of the Accounting Firm, does not constitute a “parachute payment” within the meaning of Section 280G(b)(2) of the Code (including by reason of Section 280G(b)(4)(A) of the Code) and, in calculating the Excise Tax, no portion of such Payments shall be taken into account which, in the opinion of the Accounting Firm, constitutes reasonable compensation for services actually rendered, within the meaning of Section 280G(b)(4)(B) of the Code, in excess of the base amount (as defined in Section 280G(b)(3) of the Code) allocable to such reasonable compensation, and (iii) the value of any non-cash benefit or any deferred payment or benefit included in the Payments shall be determined by the Accounting Firm in accordance with the principles of Sections 280G(d)(3) and (4) of the Code.

Section 10.

Delayed Distribution under Section 409A of the Code.  If the Executive is a Specified Employee on the date of the Executive’s Involuntary Termination (or on the date of the Executive’s Separation from Service by reason of Disability), the Section 409A Payments, and any other payments or benefits under this Agreement subject to Section 409A of the Code, shall be delayed in order to avoid a prohibited distribution under Section 409A(a)(2)(B)(i) of the Code, and such payments or benefits shall be paid or distributed to the Executive during the thirty (30) day period commencing on the earlier of (a) the expiration of the six-month period measured from the date of the Executive’s Separation from Service or (b) the date of the Executive’s death.  Upon the expiration of the applicable six-month period under Section 409A(a)(2)(B)(i) of the Code, all payments deferred pursuant to this Section 10 (excluding in-kind benefits) shall be paid in a lump sum payment to the Executive, plus interest thereon from the date of the Executive’s Involuntary Termination through the payment date at an annual rate equal to Moody’s Rate.  The “Moody’s Rate” shall mean the average of the daily Moody’s Corporate Bond Yield Average – Monthly Average Corporates as published by Moody’s Investors Service, Inc. (or any successor) for the month next preceding the Date of Termination.  Any remaining payments due under the Agreement shall be paid as otherwise provided herein.

Section 11.

Nonexclusivity of Rights.  Nothing in this Agreement shall prevent or limit the Executive’s continuing or future participation in any benefit, plan, program, policy or practice provided by the Company and for which the Executive may qualify (except with respect to any benefit to which the Executive has waived his rights in writing), including, without limitation, any and all indemnification arrangements in favor of the Executive (whether under agreements or under the Company’s charter documents or otherwise), and insurance policies covering the Executive, nor shall anything herein limit or otherwise affect such rights as the Executive may have under any other contract or agreement entered into after the Effective Date with the Company.  Amounts which are vested benefits or which the Executive is otherwise entitled to receive under any benefit, plan, policy, practice or program of, or any contract or agreement entered into with, the Company shall be payable in accordance with such benefit, plan, policy, practice or program or contract or agreement except as explicitly modified by this Agreement.  At all times during the Executive’s employment with the Company and thereafter, the Company shall provide (to the extent permissible under applicable law) the Executive with indemnification and D&O insurance insuring the Executive against insurable events which occur or have occurred while the Executive was a director or the Executive officer of the Company, on terms and conditions that are at least as generous as that then provided to any other current or former director or the Executive officer of the Company or any Affiliate.  Such indemnification and D&O insurance shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(b)(10).

Section 12.

Full Settlement; Mitigation.  The Company’s obligation to make the payments provided for in this Agreement and otherwise to perform its obligations hereunder shall not be affected by any set-off, counterclaim, recoupment, defense or other claim, right or action which the Company may have against the Executive or others, provided that nothing herein shall preclude the Company from separately pursuing recovery from the Executive based on any such claim.  In no event shall the Executive be obligated to seek other employment or take any other action by way of mitigation of the amounts (including amounts for damages for breach) payable to the Executive under any of the provisions of this Agreement, and such amounts shall not be reduced whether or not the Executive obtains other employment.

Section 13.

Dispute Resolution.

Any disagreement, dispute, controversy or claim arising out of or relating to this Agreement or the interpretation of this Agreement or any arrangements relating to this Agreement or contemplated in this Agreement or the breach, termination or invalidity thereof shall be settled by final and binding arbitration administered by JAMS in San Diego, California in accordance with the then existing JAMS arbitration rules applicable to employment disputes (the “JAMS Rules”); provided that, notwithstanding any provision in such rules to the contrary, in all cases the parties shall be entitled to reasonable discovery.  In the event of such an arbitration proceeding, the Executive and the Company shall select a mutually acceptable neutral arbitrator from among the JAMS panel of arbitrators.  In the event the Executive and the Company cannot agree on an arbitrator, the arbitrator shall be selected in accordance with the then existing JAMS Rules.  Neither the Executive nor the Company nor the arbitrator shall disclose the existence, content or results of any arbitration hereunder without the prior written consent of all parties, except to the extent necessary to enforce any arbitration award in a court of competent jurisdiction.  Except as provided herein, the Federal Arbitration Act shall govern the interpretation of, enforcement of and all proceedings under this agreement to arbitrate.  The arbitrator shall apply the substantive law (and the law of remedies, if applicable) of the state of California, or federal law, or both, as applicable, and the arbitrator is without jurisdiction to apply any different substantive law.  The arbitrator shall have the authority to entertain a motion to dismiss and/or a motion for summary judgment by any party and shall apply the standards governing such motions under the Federal Rules of Civil Procedure.  The arbitrator shall render an award and a written, reasoned opinion in support thereof.  Judgment upon the award may be entered in any court having jurisdiction thereof.  The Executive shall not be required to pay any arbitration fee or cost that is unique to arbitration or greater than any amount he would be required to pay to pursue his claims in a court of competent jurisdiction.

Section 14.

Executive’s Covenants.    

(a)

Confidentiality.  The Executive acknowledges that in the course of his employment with the Company, he has acquired non-public privileged or confidential information and trade secrets concerning the operations, future plans and methods of doing business (“Proprietary Information”) of the Company and its Affiliates; and the Executive agrees that it would be extremely damaging to the Company and its Affiliates if such Proprietary Information were disclosed to a competitor of the Company and its Affiliates or to any other person or corporation.  The Executive understands and agrees that all Proprietary Information has been divulged to the Executive in confidence and further understands and agrees to keep all Proprietary Information secret and confidential (except for such information which is or becomes publicly available other than as a result of a breach by the Executive of this provision or information the Executive is required by any governmental, administrative or court order to disclose) without limitation in time.  In view of the nature of the Executive’s employment and the Proprietary Information the Executive has acquired during the course of such employment, the Executive likewise agrees that the Company and its Affiliates would be irreparably harmed by any disclosure of Proprietary Information in violation of the terms of this paragraph and that the Company and its Affiliates shall therefore be entitled to preliminary and/or permanent injunctive relief prohibiting the Executive from engaging in any activity or threatened activity in violation of the terms of this paragraph and to any other relief available to them.  Inquiries regarding whether specific information constitutes Proprietary Information shall be directed to the Company’s Senior Vice President, Public Policy (or, if such position is vacant, the Company’s then Chief Executive Officer); provided, that the Company shall not unreasonably classify information as Proprietary Information.

(b)

Non-Solicitation of Employees.  The Executive recognizes that he possesses and will possess confidential information about other employees of the Company and its Affiliates relating to their education, experience, skills, abilities, compensation and benefits, and inter-personal relationships with customers of the Company and its Affiliates.  The Executive recognizes that the information he possesses and will possess about these other employees is not generally known, is of substantial value to the Company and its Affiliates in developing their business and in securing and retaining customers, and has been and will be acquired by him because of his business position with the Company and its Affiliates.  The Executive agrees that at all times during the Executive’s employment with the Company and for a period of one (1) year thereafter, he will not, directly or indirectly, solicit or recruit any employee of the Company or its Affiliates for the purpose of being employed by him or by any competitor of the Company or its Affiliates on whose behalf he is acting as an agent, representative or employee and that he will not convey any such confidential information or trade secrets about other employees of the Company and its Affiliates to any other person; provided, however, that it shall not constitute a solicitation or recruitment of employment in violation of this paragraph to discuss employment opportunities with any employee of the Company or its Affiliates who has either first contacted the Executive or regarding whose employment the Executive has discussed with and received the written approval of the Company’s Vice President, Human Resources (or, if such position is vacant, the Company’s then Chief Executive Officer), prior to making such solicitation or recruitment.  In view of the nature of the Executive’s employment with the Company, the Executive likewise agrees that the Company and its Affiliates would be irreparably harmed by any solicitation or recruitment in violation of the terms of this paragraph and that the Company and its Affiliates shall therefore be entitled to preliminary and/or permanent injunctive relief prohibiting the Executive from engaging in any activity or threatened activity in violation of the terms of this paragraph and to any other relief available to them.

(c)

Survival of Provisions.  The obligations contained in Section 14(a) and Section 14(b) above shall survive the termination of the Executive’s employment within the Company and shall be fully enforceable thereafter.  If it is determined by a court of competent jurisdiction in any state that any restriction in Section 14(a) or Section 14(b) above is excessive in duration or scope or is unreasonable or unenforceable under the laws of that state, it is the intention of the parties that such restriction may be modified or amended by the court to render it enforceable to the maximum extent permitted by the law of that state.

(d)

Release; Lump Sum Payment.  In the event of the Executive’s Involuntary Termination,  if the Executive (i) agrees to the covenants described in Section 14(a) and Section 14(b) above, (ii) executes a release (the “Release”) of all claims substantially in the form attached hereto as Exhibit A within fifty (50) days after the date of Involuntary Termination and does not revoke such Release in accordance with the terms thereof, and (iii) agrees to provide the consulting services described in Section 14(e) below, then in consideration for such covenants, the Company shall pay the Executive, in one cash lump sum, an amount (the “Consulting Payment”) in cash equal to the greater of:  (X) 170% of the Executive’s Annual Base Salary as in effect on the Date of Termination, and (Y) the Executive’s Annual Base Salary as in effect on the Date of Termination, plus the Executive’s Average Annual Bonus.  Except as provided in this subsection, the Consulting Payment shall be paid on such date as is determined by the Company within the ten (10) day period commencing on the 60th day after the date of the Executive’s Involuntary Termination; provided, however, that if the Executive is a Specified Employee on the date of the Executive’s Involuntary Termination, the Consulting Payment shall be paid as provided in Section 10 hereof.  The Executive shall have the right to elect to defer the Consulting Payment under the terms and conditions of the Company’s Deferred Compensation Plan.  Any such deferral election shall be made in accordance with Section 18(b) hereof.

(e)

Consulting.  If the Executive agrees to the covenants described in Section 14(d) above,  then the Executive shall have the obligation to provide consulting services to the Company as an independent contractor, commencing on the Date of Termination and ending on the second anniversary of the Date of Termination (the “Consulting Period”).  The Executive shall hold himself available at reasonable times and on reasonable notice to render such consulting services as may be so assigned to him by the Board or the Company’s then Chief Executive Officer; provided, however, that unless the parties otherwise agree, the consulting services rendered by the Executive during the Consulting Period shall not exceed twenty (20) hours each month; and, provided, further, that the consulting services rendered by the Executive during the Consulting Period shall in no event exceed twenty percent (20%) of the average level of services performed by the Executive for the Company over the thirty-six (36) month period immediately preceding the Executive’s Separation from Service (or the full period of services to the Company, if the Executive has been providing services to the Company for less than thirty-six (36) months).  The Company agrees to use its best efforts during the Consulting Period to secure the benefit of the Executive’s consulting services so as to minimize the interference with the Executive’s other activities, including requiring the performance of consulting services at the Company’s offices only when such services may not be reasonably performed off-site by the Executive.

Section 15.

Legal Fees.  

(a)

Reimbursement of Legal Fees.  Subject to subsection (b), in the event of the Executive’s Separation from Service either (1) prior to a Change in Control, or (2) on or within two (2) years following a Change in Control, the Company shall reimburse the Executive for all legal fees and expenses (including but not limited to fees and expenses in connection with any arbitration) incurred by the Executive in disputing any issue arising under this Agreement relating to the Executive’s Separation from Service or in seeking to obtain or enforce any benefit or right provided by this Agreement.  

(b)

Requirements for Reimbursement.  The Company shall reimburse the Executive’s legal fees and expenses pursuant to subsection (a) above only to the extent the arbitrator or court determines the following:  (i) the Executive disputed such issue, or sought to obtain or enforce such benefit or right, in good faith, (ii) the Executive had a reasonable basis for such claim, and (iii) in the case of subsection (a)(1) above, the Executive is the prevailing party.  In addition, the Company shall reimburse such legal fees and expenses, only if such legal fees and expenses are incurred during the twenty (20) year period beginning on the date of the Executive’s Separation from Service.   The legal fees and expenses paid to the Executive for any taxable year of the Executive shall not affect the legal fees and expenses paid to the Executive for any other taxable year of the Executive.  The legal fees and expenses shall be paid to the Executive on or before the last day of the Executive’s taxable year following the taxable year in which the fees or expenses are incurred.  The Executive’s right to reimbursement of legal fees and expenses shall not be subject to liquidation or exchange for any other benefit.  Such right to reimbursement of legal fees and expenses shall be provided in a manner that complies with Treasury Regulation Section 1.409A-3(i)(1)(iv).  If the Executive is a Specified Employee on the date of the Executive’s Separation from Service, such right to reimbursement of legal fees and expenses shall be paid as provided in Section 10 hereof.

Section 16.

Successors.

(a)

Assignment by the Executive.  This Agreement is personal to the Executive and without the prior written consent of Sempra Energy shall not be assignable by the Executive otherwise than by will or the laws of descent and distribution.  This Agreement shall inure to the benefit of and be enforceable by the Executive’s legal representatives.

(b)

Successors and Assigns of Sempra Energy.  This Agreement shall inure to the benefit of and be binding upon Sempra Energy, its successors and assigns.  Sempra Energy may not assign this Agreement to any person or entity (except for a successor described in Section 16(c), (d) or (e) below) without the Executive’s written consent.

(c)

Assumption.  Sempra Energy shall require any successor (whether direct or indirect, by purchase, merger, consolidation or otherwise) to all or substantially all of the business and/or assets of Sempra Energy to assume expressly and agree to perform the obligations and satisfy and discharge the liabilities of this Agreement in the same manner and to the same extent that Sempra Energy would have been required to perform the obligations and satisfy and discharge the liabilities under this Agreement if no such succession had taken place, and Sempra Energy shall have no further obligations and liabilities under this Agreement.  Upon such assumption, references to Sempra Energy in this Agreement shall be replaced with references to such successor.

(d)

Sale of Subsidiary.  In the event that (i) the Executive is employed by a direct or indirect subsidiary of Sempra Energy that is a member of the Sempra Energy Control Group, (ii) Sempra Energy, directly or indirectly through one or more intermediaries, sells or otherwise disposes of such subsidiary, and (iii) such subsidiary ceases to be a member of the Sempra Energy Control Group, then if, on the date such subsidiary ceases to be a member of the Sempra Energy Control Group, the Executive continues in employment with such subsidiary and the Executive does not have a Separation from Service, Sempra Energy shall require such subsidiary or any successor (whether direct or indirect, by purchase merger, consolidation or otherwise) to such subsidiary, or the parent thereof, to assume expressly and agree to perform the obligations and satisfy and discharge the liabilities under this Agreement in the same manner and to the same extent that Sempra Energy would have been required to perform the obligations and satisfy and discharge the liabilities under this Agreement, if such subsidiary had not ceased to be part of the Sempra Energy Control Group, and, upon such assumption, Sempra Energy shall have no further obligations and liabilities under the Agreement.  Upon such assumption, (i) references to Sempra Energy in this Agreement shall be replaced with references to such subsidiary, or such successor or parent thereof, assuming this Agreement, and (ii) subsection (b) of the definition of “Cause” and subsection (b) of the definition of “Good Reason” shall apply thereafter, as if a Change in Control had occurred on the date of such cessation.

(e)

Sale of Assets of Subsidiary.  In the event that (i) the Executive is employed by a direct or indirect subsidiary of Sempra Energy, and (ii) such subsidiary sells or otherwise disposes of substantial assets of such subsidiary to an unrelated service recipient, as determined under Treasury Regulation Section 1.409A-1(f)(2)(ii) (the “Asset Purchaser”), in a transaction described in Treasury Regulation Section 1.409A-1(h)(4) (an “Asset Sale”), then if, on the date of such Asset Sale, the Executive becomes employed by the Asset Purchaser, Sempra Energy and the Asset Purchaser shall specify, in accordance with Treasury Regulation Section 1.409A-1(h)(4), that the Executive shall not be treated as having a Separation from Service, and Sempra Energy shall require such Asset Purchaser, or the parent thereof, to assume expressly and agree to perform the obligations and satisfy and discharge the liabilities under this Agreement in the same manner and to the same extent that Sempra Energy would have been required to perform the obligations and satisfy and discharge the liabilities under this Agreement, if the Asset Sale had not taken place, and, upon such assumption, Sempra Energy shall have no further obligations and liabilities under the Agreement.  Upon such assumption, (i) references to Sempra Energy in this Agreement shall be replaced with references to the Asset Purchaser or the parent thereof, as applicable, and (ii) subsection (b) of the definition of “Cause” and subsection (b) of the definition of “Good Reason” shall apply thereafter, as if a Change in Control had occurred on the date of the Asset Sale.

Section 17.

Administration Prior to Change in Control.  Prior to a Change in Control, the Compensation Committee shall have full and complete authority to construe and interpret the provisions of this Agreement, to determine an individual’s entitlement to benefits under this Agreement, to make in its sole and absolute discretion all determinations contemplated under this Agreement, to investigate and make factual determinations necessary or advisable to administer or implement this Agreement, and to adopt such rules and procedures as it deems necessary or advisable for the administration or implementation of this Agreement.  All determinations made under this Agreement by the Compensation Committee shall be final and binding on all interested persons.  Prior to a Change in Control, the Compensation Committee may delegate responsibilities for the operation and administration of this Agreement to one or more officers or employees of the Company.  The provisions of this Section 17 shall terminate and be of no further force and effect upon the occurrence of a Change in Control.   

Section 18.

Section 409A of the Code.

(a)

Compliance with and Exemption from Section 409A of the Code.  Certain payments and benefits payable under this Agreement (including, without limitation, the Section 409A Payments) are intended to comply with the requirements of Section 409A of the Code.  Certain payments and benefits payable under this Agreement are intended to be exempt from the requirements of Section 409A of the Code.  This Agreement shall be interpreted in accordance with the applicable requirements of, and exemptions from, Section 409A of the Code and the Treasury Regulations thereunder.  To the extent the payments and benefits under this Agreement are subject to Section 409A of the Code, this Agreement shall be interpreted, construed and administered in a manner that satisfies the requirements of Sections 409A(a)(2), (3) and (4) of the Code and the Treasury Regulations thereunder (subject to the transitional relief under Internal Revenue Service Notice 2005-1, the Proposed Regulations under Section 409A of the Code, Internal Revenue Service Notice 2006-79, Internal Revenue Service Notice 2007-78, Internal Revenue Service Notice 2007-86 and other applicable authority issued by the Internal Revenue Service).  As provided in Internal Revenue Notice 2007-86, notwithstanding any other provision of this Agreement, with respect to an election or amendment to change a time or form of payment under this Agreement made on or after January 1, 2008 and on or before December 31, 2008, the election or amendment shall apply only with respect to payments that would not otherwise be payable in 2008, and shall not cause payments to be made in 2008 that would not otherwise be payable in 2008.  If the Company and the Executive determine that any compensation, benefits or other payments that are payable under this Agreement and intended to comply with Sections 409A(a)(2), (3) and (4) of the Code do not comply with Section 409A of the Code, the Treasury Regulations thereunder and other applicable authority issued by the Internal Revenue Service, to the extent permitted under Section 409A of the Code, the Treasury Regulations thereunder and any applicable authority issued by the Internal Revenue Service, the Company and the Executive agree to amend this Agreement, or take such other actions as the Company and the Executive deem reasonably necessary or appropriate, to cause such compensation, benefits and other payments to comply with the requirements of Section 409A of the Code, the Treasury Regulations thereunder and other applicable authority issued by the Internal Revenue Service, while providing compensation, benefits and other payments that are, in the aggregate, no less favorable than the compensation, benefits and other payments provided under this Agreement.  In the case of any compensation, benefits or other payments that are payable under this Agreement and intended to comply with Sections 409A(a)(2), (3) and (4) of the Code, if any provision of the Agreement would cause such compensation, benefits or other payments to fail to so comply, such provision shall not be effective and shall be null and void with respect to such compensation, benefits or other payments to the extent such provision would cause a failure to comply, and such provision shall otherwise remain in full force and effect.

(b)

Deferral Elections.  As provided in Sections 5(f), 6(h) and 14(d), the Executive may elect to defer the Pre-Change in Control Severance Payment, the Post-Change in Control Severance Payment and the Consulting Payment as follows.    The Executive’s deferral election shall satisfy the requirements of Treasury Regulation Section 1.409A-2(b) and the terms and conditions of the Deferred Compensation Plan.  Such deferral election shall designate the whole percentage (up to a maximum of 100%) of the Pre-Change in Control Severance Payment, the Post-Change in Control Severance Payment and the Consulting Payment to be deferred, shall be irrevocable when made, and shall not take effect until at least twelve (12) months after the date on which the election is made.  Such deferral election shall provide that the amount deferred shall be deferred for a period of not less than five (5) years from the date the payment of the amount deferred would otherwise have been made, in accordance with Treasury Regulation Section 1.409A-2(b)(1)(ii).

Section 19.

Miscellaneous.

(a)

Governing Law.  This Agreement shall be governed by and construed in accordance with the laws of the State of California, without reference to its principles of conflict of laws.  The captions of this Agreement are not part of the provisions hereof and shall have no force or effect.  This Agreement may not be amended, modified, repealed, waived, extended or discharged except by an agreement in writing signed by the party against whom enforcement of such amendment, modification, repeal, waiver, extension or discharge is sought.  No person, other than pursuant to a resolution of the Board or a committee thereof, shall have authority on behalf of the Company to agree to amend, modify, repeal, waive, extend or discharge any provision of this Agreement or anything in reference thereto.

(b)

Notices.  All notices and other communications hereunder shall be in writing and shall be given by hand delivery to the other party or by registered or certified mail, return receipt requested, postage prepaid, addressed, in either case, to the Company’s headquarters or to such other address as either party shall have furnished to the other in writing in accordance herewith.  Notices and communications shall be effective when actually received by the addressee.

(c)

Severability.  The invalidity or unenforceability of any provision of this Agreement shall not affect the validity or enforceability of any other provision of this Agreement.

(d)

Taxes.  The Company may withhold from any amounts payable under this Agreement such federal, state or local taxes as shall be required to be withheld pursuant to any applicable law or regulation.

(e)

No Waiver.  The Executive’s or the Company’s failure to insist upon strict compliance with any provision hereof or any other provision of this Agreement or the failure to assert any right the Executive or the Company may have hereunder, including, without limitation, the right of the Executive to terminate employment for Good Reason pursuant to Section 1 hereof, or the right of the Company to terminate the Executive’s employment for Cause pursuant to Section 1 hereof shall not be deemed to be a waiver of such provision or right or any other provision or right of this Agreement.

(f)

Entire Agreement; Exclusive Benefit; Supersession of Prior Agreement.  This instrument contains the entire agreement of the Executive, the Company or any predecessor or subsidiary thereof with respect to any severance or termination pay.  The Pre-Change in Control Severance Payment, the Post-Change in Control Severance Payment and all other benefits provided hereunder shall be in lieu of any other severance payments to which the Executive is entitled under any other severance plan or program or arrangement sponsored by the Company, as well as pursuant to any individual employment or severance agreement that was entered into by the Executive and the Company, and, upon the Effective Date of this Agreement, all such plans, programs, arrangements and agreements are hereby automatically superseded and terminated.

(g)

No Right of Employment.  Nothing in this Agreement shall be construed as giving the Executive any right to be retained in the employ of the Company or shall interfere in any way with the right of the Company to terminate the Executive’s employment at any time, with or without Cause.

(h)

Unfunded Obligation.  The obligations under this Agreement shall be unfunded.  Benefits payable under this Agreement shall be paid from the general assets of the Company.  The Company shall have no obligation to establish any fund or to set aside any assets to provide benefits under this Agreement.

(i)

Termination upon Sale of Assets of Subsidiary.  Notwithstanding anything contained herein, this Agreement shall automatically terminate and be of no further force and effect and no benefits shall be payable hereunder in the event that (i) the Executive is employed by a direct or indirect subsidiary of Sempra Energy, and (ii) an Asset Sale (as defined in Section 16(e)) occurs (other than such a sale or disposition which is part of a transaction or series of transactions which would result in a Change in Control), and (iii) as a result of such Asset Sale, the Executive is offered employment by the Asset Purchaser in an executive position with reasonably comparable status, compensation, benefits and severance agreement (including the assumption of this Agreement in accordance with Section 16(e)) and which is consistent with the Executive’s experience and education, but the Executive declines to accept such offer and the Executive fails to become employed by the Asset Purchaser on the date of the Asset Sale.  

(j)

Term.  The term of this Agreement shall commence on the Effective Date and shall continue until the third (3rd) anniversary of the Effective Date; provided, however, that commencing on the second (2nd) anniversary of the Effective Date (and each anniversary of the Effective Date thereafter), the term of this Agreement shall automatically be extended for one (1) additional year, unless at least ninety (90) days prior to such date, the Company or the Executive shall give written notice to the other party that it or he, as the case may be, does not wish to so extend this Agreement.  Notwithstanding the foregoing, if the Company gives such written notice to the Executive less than two (2) years after a Change in Control, the term of this Agreement shall be automatically extended until the later of (A) the date that is one (1) year after the anniversary of the Effective Date that follows such written notice or (B) the second (2nd) anniversary of the Change in Control Date.

(k)

Counterparts.  This Agreement may be executed in several counterparts, each of which shall be deemed to be an original but all of which together shall constitute one and the same instrument.


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IN WITNESS WHEREOF, the Executive and, pursuant to due authorization from its Board of Directors, the Company have caused this Agreement to be executed as of the day and year first above written.

SEMPRA ENERGY


G. Joyce Rowland

Senior Vice President - Human Resources, Diversity & Inclusion


_____________________________________

Date


EXECUTIVE




M. Javade Chaudhri

Executive Vice President and General Counsel


_____________________________________

Date




 




EXHIBIT A


GENERAL RELEASE

This GENERAL RELEASE (the “Agreement”), dated ___________, is made by and between ______________________________, a California corporation (the “Company”) and  ___________________________ (“you” or “your”).

WHEREAS, you and the Company have previously entered into that certain Severance Pay Agreement dated ____________, 20___ (the “Severance Pay Agreement”); and

WHEREAS, Section 14(d) of the Severance Pay Agreement provides for the payment of a benefit to you by the Company in consideration for certain covenants, including your execution and non-revocation of a general release of claims by you against the Company and its subsidiaries and affiliates.

NOW, THEREFORE, in consideration of the premises and the mutual covenants herein contained, you and the Company hereby agree as follows:

ONE:  Your signing of this Agreement confirms that your employment with the Company shall terminate at the close of business on ____________, or earlier upon our mutual agreement.

TWO:  As a material inducement for the payment of the benefit under Section 14(d) of the Severance Pay Agreement, and except as otherwise provided in this Agreement, you and the Company hereby irrevocably and unconditionally release, acquit and forever discharge the other from any and all Claims either may have against the other.  For purposes of this Agreement and the preceding sentence, the words “Releasee” or “Releasees” and “Claim” or “Claims” shall have the meanings set forth below:

(a)

The words “Releasee” or “Releasees” shall refer to you and to the Company and each of the Company’s owners, stockholders, predecessors, successors, assigns, agents, directors, officers, employees, representatives, attorneys, advisors, parent companies, divisions, subsidiaries, affiliates (and agents, directors, officers, employees, representatives, attorneys and advisors of such parent companies, divisions, subsidiaries and affiliates) and all persons acting by, through, under or in concert with any of them.

(b)

The words “Claim” or “Claims” shall refer to any charges, complaints, claims, liabilities, obligations, promises, agreements, controversies, damages, actions, causes of action, suits, rights, demands, costs, losses, debts and expenses (including attorneys’ fees and costs actually incurred) of any nature whatsoever, known or unknown, suspected or unsuspected, which you or the Company now, in the past or, except as limited by law or regulation such as the Age Discrimination in Employment Act (ADEA), in the future may have, own or hold against any of the Releasees; provided, however, that the word “Claim” or “Claims” shall not refer to any charges, complaints, claims, liabilities, obligations, promises, agreements, controversies, damages, actions, causes of action, suits, rights, demands, costs, losses, debts and expenses (including attorneys’ fees and costs actually incurred) arising under [identify severance, employee benefits, stock option, indemnification and D&O  and other agreements containing duties, rights obligations etc. of either party that are to remain operative].  Claims released pursuant to this Agreement by you and the Company include, but are not limited to, rights arising out of alleged violations of any contracts, express or implied, any tort, any claim that you failed to perform or negligently performed or breached your duties during employment at the Company, any legal restrictions on the Company’s right to terminate employees or any federal, state or other governmental statute, regulation, or ordinance, including, without limitation:  (1) Title VII of the Civil Rights Act of 1964 (race, color, religion, sex and national origin discrimination); (2) 42 U.S.C. § 1981 (discrimination); (3) 29 U.S.C. §§ 621–634 (age discrimination); (4) 29 U.S.C. § 206(d)(l) (equal pay); (5) 42 U.S.C. §§ 12101, et seq. (disability); (6) the California Constitution, Article I, Section 8 (discrimination); (7) the California Fair Employment and Housing Act (discrimination, including race, color, national origin, ancestry, physical handicap, medical condition, marital status, religion, sex or age); (8) California Labor Code Section 1102.1 (sexual orientation discrimination); (9) the Executive Order 11246 (race, color, religion, sex and national origin discrimination); (10) the Executive Order 11141 (age discrimination); (11) §§ 503 and 504 of the Rehabilitation Act of 1973 (handicap discrimination); (12) The Worker Adjustment and Retraining Act (WARN Act); (13) the California Labor Code (wages, hours, working conditions, benefits and other matters); (14) the Fair Labor Standards Act (wages, hours, working conditions and other matters); the Federal Employee Polygraph Protection Act (prohibits employer from requiring employee to take polygraph test as condition of employment); and (15) any federal, state or other governmental statute, regulation or ordinance which is similar to any of the statutes described in clauses (1) through (14).

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

“A GENERAL RELEASE DOES NOT EXTEND TO CLAIMS WHICH THE CREDITOR DOES NOT KNOW OR SUSPECT TO EXIST IN HIS FAVOR AT THE TIME OF EXECUTING THE RELEASE, WHICH IF KNOWN BY HIM MUST HAVE MATERIALLY AFFECTED HIS SETTLEMENT WITH THE DEBTOR.”

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

FOUR:  The parties acknowledge that they might hereafter discover facts different from, or in addition to, those they now know or believe to be true with respect to a Claim or Claims released herein, and they expressly agree to assume the risk of possible discovery of additional or different facts, and agree that this Agreement shall be and remain effective, in all respects, regardless of such additional or different discovered facts.

FIVE:  You hereby represent and acknowledge that you have not filed any Claim of any kind against the Company or others released in this Agreement.  You further hereby expressly agree never to initiate against the Company or others released in this Agreement any administrative proceeding, lawsuit or any other legal or equitable proceeding of any kind asserting any Claims that are released in this Agreement.

The Company hereby represents and acknowledges that it has not filed any Claim of any kind against you or others released in this Agreement.  The Company further hereby expressly agrees never to initiate against you or others released in this Agreement any administrative proceeding, lawsuit or any other legal or equitable proceeding of any kind asserting any Claims that are released in this Agreement.

SIX:  You hereby represent and agree that you have not assigned or transferred, or attempted to have assigned or transfer, to any person or entity, any of the Claims that you are releasing in this Agreement.

The Company hereby represents and agrees that it has not assigned or transferred, or attempted to have assigned or transfer, to any person or entity, any of the Claims that it is releasing in this Agreement.

SEVEN:  As a further material inducement to the Company to enter into this Agreement, you hereby agree to indemnify and hold each of the Releasees harmless from all loss, costs, damages, or expenses, including without limitation, attorneys’ fees incurred by the Releasees, arising out of any breach of this Agreement by you or the fact that any representation made in this Agreement by you was false when made.

As a further material inducement to you to enter into this Agreement, the Company hereby agrees to indemnify and hold each of the Releasees harmless from all loss, costs, damages, or expenses, including without limitation, attorneys’ fees incurred by the Releasees, arising out of any breach of this Agreement by it or the fact that any representation made in this Agreement by it was knowingly false when made.

EIGHT:  You and the Company represent and acknowledge that in executing this Agreement, neither is relying upon any representation or statement not set forth in this Agreement or the Severance Agreement.

NINE:

(a)

This Agreement shall not in any way be construed as an admission by the Company that it has acted wrongfully with respect to you or any other person, or that you have any rights whatsoever against the Company, and the Company specifically disclaims any liability to or wrongful acts against you or any other person, on the part of itself, its employees or its agents.  This Agreement shall not in any way be construed as an admission by you that you have acted wrongfully with respect to the Company, or that you failed to perform your duties or negligently performed or breached your duties, or that the Company had good cause to terminate your employment.

(b)

If you are a party or are threatened to be made a party to any proceeding by reason of the fact that you were an officer or director of the Company, the Company shall indemnify you against any expenses (including reasonable attorneys’ fees; provided, that counsel has been approved by the Company prior to retention, which approval shall not be unreasonably withheld), judgments, fines, settlements and other amounts actually or reasonably incurred by you in connection with that proceeding; provided, that you acted in good faith and in a manner you reasonably believed to be in the best interest of the Company.  The limitations of California Corporations Code Section 317 shall apply to this assurance of indemnification.

(c)

You agree to cooperate with the Company and its designated attorneys, representatives and agents in connection with any actual or threatened judicial, administrative or other legal or equitable proceeding in which the Company is or may become involved.  Upon reasonable notice, you agree to meet with and provide to the Company or its designated attorneys, representatives or agents all information and knowledge you have relating to the subject matter of any such proceeding.  The Company agrees to reimburse you for any reasonable costs you incur in providing such cooperation.

TEN:  This Agreement is made and entered into in California.  This Agreement shall in all respects be interpreted, enforced and governed by and under the laws of the State of California and applicable Federal law.  Any dispute about the validity, interpretation, effect or alleged violation of this Agreement (an “arbitrable dispute”) must be submitted to arbitration in San Diego, California.  Arbitration shall take place before an experienced employment arbitrator licensed to practice law in such state and selected in accordance with the then existing JAMS arbitration rules applicable to employment disputes; provided, however, that in any event, the arbitrator shall allow reasonable discovery.  Arbitration shall be the exclusive remedy for any arbitrable dispute.  The arbitrator in any arbitrable dispute shall not have authority to modify or change the Agreement in any respect.  You and the Company shall each be responsible for payment of one-half (1/2) the amount of the arbitrator’s fee(s); provided, however, that in no event shall you be required to pay any fee or cost of arbitration that is unique to arbitration or exceeds the costs you would have incurred had any arbitrable dispute been pursued in a court of competent jurisdiction.  The Company shall make up any shortfall.  Should any party to this Agreement institute any legal action or administrative proceeding against the other with respect to any Claim waived by this Agreement or pursue any arbitrable dispute by any method other than arbitration, the prevailing party shall be entitled to recover from the non-prevailing party all damages, costs, expenses and attorneys’ fees incurred as a result of that action.  The arbitrator’s decision and/or award shall be rendered in writing and will be fully enforceable and subject to an entry of judgment by the Superior Court of the State of California for the County of San Diego, or any other court of competent jurisdiction.

ELEVEN:  Both you and the Company understand that this Agreement is final and binding eight (8) days after its execution and return.  Should you nevertheless attempt to challenge the enforceability of this Agreement as provided in Paragraph TEN or, in violation of that Paragraph, through litigation, as a further limitation on any right to make such a challenge, you shall initially tender to the Company, by certified check delivered to the Company, all monies received pursuant to Section 14(d) of the Severance Pay Agreement, plus interest, and invite the Company to retain such monies and agree with you to cancel this Agreement and void the Company’s obligations under Section 14(d) of the Severance Pay Agreement.  In the event the Company accepts this offer, the Company shall retain such monies and this Agreement shall be canceled and the Company shall have no obligation under Section 14(d) of the Severance Pay Agreement.  In the event the Company does not accept such offer, the Company shall so notify you and shall place such monies in an interest-bearing escrow account pending resolution of the dispute between you and the Company as to whether or not this Agreement and the Company’s obligations under Section 14(d) of the Severance Pay Agreement shall be set aside and/or otherwise rendered voidable or unenforceable.  Additionally, any consulting agreement then in effect between you and the Company shall be immediately rescinded with no requirement of notice.

TWELVE:  Any notices required to be given under this Agreement shall be delivered either personally or by first class United States mail, postage prepaid, addressed to the respective parties as follows:

To Company:

[TO COME]

Attn:  [TO COME]

To You:

______________________

______________________

______________________

THIRTEEN:  You understand and acknowledge that you have been given a period of forty-five (45) days to review and consider this Agreement (as well as statistical data on the persons eligible for similar benefits) before signing it and may use as much of this forty-five (45) day period as you wish prior to signing.  You are encouraged, at your personal expense, to consult with an attorney before signing this Agreement.  You understand and acknowledge that whether or not you do so is your decision.  You may revoke this Agreement within seven (7) days of signing it.  If you wish to revoke, the Company’s Vice President, Human Resources must receive written notice from you no later than the close of business on the seventh (7th) day after you have signed the Agreement.  If revoked, this Agreement shall not be effective and enforceable, and you will not receive payments or benefits under Section 14(d) of the Severance Pay Agreement.

FOURTEEN:  This Agreement constitutes the entire agreement of the parties hereto and supersedes any and all other agreements (except the Severance Pay Agreement) with respect to the subject matter of this Agreement, whether written or oral, between you and the Company.  All modifications and amendments to this Agreement must be in writing and signed by the parties.

FIFTEEN:  Each party agrees, without further consideration, to sign or cause to be signed, and to deliver to the other party, any other documents and to take any other action as may be necessary to fulfill the obligations under this Agreement.

SIXTEEN:  If any provision of this Agreement or the application thereof is held invalid, the invalidity shall not affect other provisions or applications of the Agreement which can be given effect without the invalid provisions or application; and to this end the provisions of this Agreement are declared to be severable.

SEVENTEEN:  This Agreement may be executed in counterparts.

I have read the foregoing General Release, and I accept and agree to the provisions it contains and hereby execute it voluntarily and with full understanding of its consequences.  I am aware it includes a release of all known or unknown claims.

DATED:  __________

__________________________________________

DATED:  __________

__________________________________________

You acknowledge that you first received this Agreement on [date].

_________________________






Exhibit 10.24


Exhibit 10.24




SEMPRA ENERGY
SEVERANCE PAY AGREEMENT

THIS AGREEMENT (this “Agreement”), dated as of December 31, 2011 (the “Effective Date”), is made by and between SEMPRA ENERGY, a California corporation (“Sempra Energy”), and JESSIE J. KNIGHT, JR. (the “Executive”).

WHEREAS, the Executive is currently employed by Sempra Energy or a direct or indirect subsidiary of Sempra Energy (Sempra Energy and its subsidiaries are hereinafter collectively referred to as the “Company”) as Chief Executive Officer, San Diego Gas and Electric Company; and

WHEREAS, Sempra Energy and the Executive desire to enter into this Agreement; and

WHEREAS, the Board of Directors of Sempra Energy (the “Board”) has authorized this Agreement.

NOW, THEREFORE, in consideration of the premises and mutual covenants herein contained, the Company and the Executive hereby agree as follows:

Section 1.

Definitions.  For purposes of this Agreement, the following capitalized terms have the meanings set forth below:

Accounting Firm” has the meaning assigned thereto in Section 9(b) hereof.

Act” has the meaning assigned thereto in Section 2 hereof.

Additional Post-Change in Control Severance Payment” has the meaning assigned thereto in Section 6(a) hereof.

Affiliate” has the meaning set forth in Rule 12b-2 promulgated under the Exchange Act.

Annual Base Salary” means the Executive’s annual base salary from the Company.

Asset Purchaser” has the meaning assigned thereto in Section 16(e).

Asset Sale” has the meaning assigned thereto in Section 16(e).

Average Annual Bonus” means the average of the annual bonuses from the Company earned by the Executive with respect to the three (3) fiscal years of the Company immediately preceding the Date of Termination (the “Bonus Fiscal Years”); provided, however, that, if the Executive was employed by the Company during all or any portion of one or two of the Bonus Fiscal Years (but not three of the Bonus Fiscal Years), “Average Annual Bonus” means the average of the annual bonuses (if any) from the Company earned by the Executive with respect to the Bonus Fiscal Years during all or any portion of which the Executive was employed by the Company; and, provided, further, that, if the Executive was not employed by the Company during all or any portion of any of the Bonus Fiscal Years, “Average Annual Bonus” means zero.

Beneficial Owner” has the meaning set forth in Rule 13d-3 promulgated under the Exchange Act.

Cause” means:  

(a)

Prior to a Change in Control, (i) the willful failure by the Executive to substantially perform the Executive’s duties with the Company (other than any such failure resulting from the Executive’s incapacity due to physical or mental illness, (ii) the grossly negligent performance of such obligations referenced in clause (i) of this definition, (iii) the Executive’s gross insubordination; and/or (iv) the Executive’s commission of one or more acts of moral turpitude that constitute a violation of applicable law (including but not limited to a felony) which have or result in an adverse effect on the Company, monetarily or otherwise, or one or more significant acts of dishonesty.  For purposes of clause (i) of this subsection (a), no act, or failure to act, on the Executive’s part shall be deemed “willful” unless done, or omitted to be done, by the Executive not in good faith and without reasonable belief that the Executive’s act, or failure to act, was in the best interests of the Company.  

(b)

From and after a Change in Control, (i) the willful and continued failure by the Executive to substantially perform the Executive’s duties with the Company (other than any such failure resulting from the Executive’s incapacity due to physical or mental illness or any such actual or anticipated failure after the issuance of a Notice of Termination for Good Reason by the Executive pursuant to Section 3 hereof) and/or (ii) the Executive’s commission of one or more acts of moral turpitude that constitute a violation of applicable law (including but not limited to a felony) which have or result in an adverse effect on the Company, monetarily or otherwise, or one or more significant acts of dishonesty.  For purposes of clause (i) of this subsection (b), no act, or failure to act, on the Executive’s part shall be deemed “willful” unless done, or omitted to be done, by the Executive not in good faith and without reasonable belief that the Executive’s act, or failure to act, was in the best interests of the Company.  Notwithstanding the foregoing, the Executive shall not be deemed terminated for Cause pursuant to clause (i) of this subsection (b) unless and until the Executive shall have been provided with reasonable notice of and, if possible, a reasonable opportunity to cure the facts and circumstances claimed to provide a basis for termination of the Executive’s employment for Cause.

Change in Control” shall be deemed to have occurred on the date that a change in the ownership of Sempra Energy, a change in the effective control of Sempra Energy, or a change in the ownership of a substantial portion of assets of Sempra Energy occurs (each, as defined in subsection (a) below), except as otherwise provided in subsections (b), (c) and (d) below:

(a)

(i)

a “change in the ownership of Sempra Energy” occurs on the date that any one person, or more than one person acting as a group, acquires ownership of stock of Sempra Energy that, together with stock held by such person or group, constitutes more than fifty percent (50%) of the total fair market value or total voting power of the stock of Sempra Energy,

(ii)

a “change in the effective control of Sempra Energy” occurs only on either of the following dates:

(A)

the date any one person, or more than one person acting as a group, acquires (or has acquired during the twelve (12) month period ending on the date of the most recent acquisition by such person or persons) ownership of stock of Sempra Energy possessing thirty percent (30%) or more of the total voting power of the stock of Sempra Energy, or

(B)

the date a majority of the members of the Board is replaced during any twelve (12) month period by directors whose appointment or election is not endorsed by a majority of the members of the Board before the date of appointment or election, and

(iii)

a “change in the ownership of a substantial portion of assets of Sempra Energy” occurs on the date any one person, or more than one person acting as a group, acquires (or has acquired during the twelve (12) month period ending on the date of the most recent acquisition by such person or persons) assets from Sempra Energy that have a total gross fair market value equal to or more than eighty-five percent (85%) of the total gross fair market value of all of the assets of Sempra Energy immediately before such acquisition or acquisitions.

(b)

A “change in the ownership of Sempra Energy” or “a change in the effective control of Sempra Energy” shall not occur under clause (a)(i) or (a)(ii) by reason of any of the following:

(i)

an acquisition of ownership of stock of Sempra Energy directly from Sempra Energy or its Affiliates other than in connection with the acquisition by Sempra Energy or its Affiliates of a business,

(ii)

a merger or consolidation which would result in the voting securities of Sempra Energy outstanding immediately prior to such merger or consolidation continuing to represent (either by remaining outstanding or by being converted into voting securities of the surviving entity or any parent thereof), in combination with the ownership of any trustee or other fiduciary holding securities under an employee benefit plan of the Company, at least sixty percent (60%) of the combined voting power of the securities of Sempra Energy or such surviving entity or any parent thereof outstanding immediately after such merger or consolidation, or

(iii)

a merger or consolidation effected to implement a recapitalization of Sempra Energy (or similar transaction) in which no Person is or becomes the Beneficial Owner, directly or indirectly, of securities of Sempra Energy (not including the securities beneficially owned by such Person any securities acquired directly from Sempra Energy or its Affiliates other than in connection with the acquisition by Sempra Energy or its Affiliates of a business) representing twenty percent (20%) or more of the combined voting power of Sempra Energy’s then outstanding securities.

(c)

A “change in the ownership of a substantial portion of assets of Sempra Energy” shall not occur under clause (a)(iii) by reason of a sale or disposition by Sempra Energy of the assets of Sempra Energy to an entity, at least sixty percent (60%) of the combined voting power of the voting securities of which are owned by shareholders of Sempra Energy in substantially the same proportions as their ownership of Sempra Energy immediately prior to such sale.

(d)

This definition of “Change in Control” shall be limited to the definition of a “change in control event” relating to Sempra Energy under Treasury Regulation Section 1.409A-3(i)(5).  A “Change in Control” shall only occur if there is a “change in control event” relating to Sempra Energy under Treasury Regulation Section 1.409A-3(i)(5) with respect to the Executive.

Change in Control Date” means the date on which a Change in Control occurs.

Code” means the Internal Revenue Code of 1986, as amended.

Compensation Committee” means the compensation committee of the Board.

Consulting Period” has the meaning assigned thereto in Section 14(e) hereof.

Date of Termination” has the meaning assigned thereto in Section 3(b) hereof.

Deferred Compensation Plan” has the meaning assigned thereto in Section 5(f) hereof.

Disability” has the meaning set forth in the Company’s long-term disability plan or its successor; provided, however, that the Board may not terminate the Executive’s employment hereunder by reason of Disability unless (i) at the time of such termination there is no reasonable expectation that the Executive will return to work within the next ninety (90) day period and (ii) such termination is permitted by all applicable disability laws.  

Exchange Act” means the Securities Exchange Act of 1934, as amended, and the applicable rulings and regulations thereunder.

Excise Tax” has the meaning assigned thereto in Section 9(a) hereof.

Good Reason” means:

(a)

Prior to a Change in Control, the occurrence of any of the following without the prior written consent of the Executive, unless such act or failure to act is corrected by the Company prior to the Date of Termination specified in the Notice of Termination (as required under Section 3 hereof):

(i)

the assignment to the Executive of any duties materially inconsistent with the range of duties and responsibilities appropriate to a senior Executive within the Company (such range determined by reference to past, current and reasonable practices within the Company);

(ii)

a material reduction in the Executive’s overall standing and responsibilities within the Company, but not including (A) a mere change in title or (B) a transfer within the Company, which, in the case of both (A) and (B), does not adversely affect the Executive’s overall status within the Company;

(iii)

a material reduction by the Company in the Executive’s aggregate annualized compensation and benefits opportunities, except for across-the-board reductions (or modifications of benefit plans) similarly affecting all similarly situated executives (both of the Company and of any Person then in control of the Company) of comparable rank with the Executive;

(iv)

the failure by the Company to pay to the Executive any portion of the Executive’s current compensation and benefits or any portion of an installment of deferred compensation under any deferred compensation program of the Company within thirty (30) days of the date such compensation is due;

(v)

any purported termination of the Executive’s employment that is not effected pursuant to a Notice of Termination satisfying the requirements of Section 3 hereof; for purposes of this Agreement, no such purported termination shall be effective;

(vi)

the failure by Sempra Energy to perform its obligations under Section 16(c), (d) or (e) hereof;

(vii)

the failure by the Company to provide the indemnification and D&O insurance protection Section 11 of this Agreement requires it to provide; or

(viii)

the failure by Sempra Energy to comply with any material provision of this Agreement.

(b)

From and after a Change in Control, the occurrence of any of the following without the prior written consent of the Executive, unless such act or failure to act is corrected by the Company prior to the Date of Termination specified in the Notice of Termination (as required under Section 3 hereof):

(i)

an adverse change in the Executive’s title, authority, duties, responsibilities or reporting lines as in effect immediately prior to the Change in Control;

(ii)

a reduction by the Company in the Executive’s aggregate annualized compensation opportunities, except for across-the-board reductions in base salaries, annual bonus opportunities or long-term incentive compensation opportunities of less than ten percent (10%) similarly affecting all similarly situated executives (both of the Company and of any Person then in control of the Company) of comparable rank with the Executive; or the failure by the Company to continue in effect any material benefit plan in which the Executive participates immediately prior to the Change in Control, unless an equitable arrangement (embodied in an ongoing substitute or alternative plan) has been made with respect to such plan, or the failure by the Company to continue the Executive's participation therein (or in such substitute or alternative plan) on a basis not materially less favorable, both in terms of the amount of benefits provided and the level of the Executive's participation relative to other participants, as existed at the time of the Change in Control;

(iii)

the relocation of the Executive’s principal place of employment immediately prior to the Change in Control Date (the “Principal Location”) to a location which is both further away from the Executive’s residence and more than thirty (30) miles from such Principal Location, or the Company’s requiring the Executive to be based anywhere other than such Principal Location (or permitted relocation thereof), or a substantial increase in the Executive’s business travel obligations outside of the Southern California area as of the Effective Date other than any such increase that (A) arises in connection with extraordinary business activities of the Company of limited duration and (B) is understood not to be part of the Executive’s regular duties with the Company;

(iv)

the failure by the Company to pay to the Executive any portion of the Executive’s current compensation and benefits or any portion of an installment of deferred compensation under any deferred compensation program of the Company within thirty (30) days of the date such compensation is due;

(v)

any purported termination of the Executive’s employment that is not effected pursuant to a Notice of Termination satisfying the requirements of Section 3 hereof; for purposes of this Agreement, no such purported termination shall be effective;

(vi)

the failure by Sempra Energy to perform its obligations under Section 16(c), (d) or (e) hereof;

(vii)

the failure by the Company to provide the indemnification and D&O insurance protection Section 11 of this Agreement requires it to provide; or

(viii)

the failure by Sempra Energy to comply with any material provision of this Agreement.

Following a Change in Control, the Executive’s determination that an act or failure to act constitutes Good Reason shall be presumed to be valid unless such determination is deemed to be unreasonable by an arbitrator pursuant to the procedure described in Section 13 hereof.  The Executive’s right to terminate the Executive’s employment for Good Reason shall not be affected by the Executive’s incapacity due to physical or mental illness.  The Executive’s continued employment shall not constitute consent to, or a waiver of rights with respect to, any act or failure to act constituting Good Reason hereunder.

Incentive Compensation Awards” means awards granted under Incentive Compensation Plans providing the Executive with the opportunity to earn, on a year-by-year basis, annual and long-term incentive compensation.

Incentive Compensation Plans” means annual incentive compensation plans and long-term incentive compensation plans of the Company, which long-term incentive compensation plans may include plans offering stock options, restricted stock and other long-term incentive compensation.

Involuntary Termination” means (a) the Executive’s Separation from Service by reason of a termination of employment by the Company other than for Cause, death, or Disability, or (b) the Executive’s Separation from Service by reason of resignation of employment with the Company for Good Reason.    

JAMS Rules” has the meaning assigned thereto in Section 13 hereof.

Notice of Termination” has the meaning assigned thereto in Section 3(a) hereof.

Payment” has the meaning assigned thereto in Section 9(a) hereof.

Payment in Lieu of Notice” has the meaning assigned thereto in Section 3(b) hereof.

Person” has the meaning set forth in section 3(a)(9) of the Exchange Act, as modified and used in sections 13(d) and 14(d) thereof, except that such term shall not include (i) the Company or any of its Affiliates, (ii) a trustee or other fiduciary holding securities under an employee benefit plan of the Company or any of its Affiliates, (iii) an underwriter temporarily holding securities pursuant to an offering of such securities, (iv) a corporation owned, directly or indirectly, by the shareholders of the Company in substantially the same proportions as their ownership of stock of the Company, or (v) a person or group as used in Rule 13d-1(b) promulgated under the Exchange Act.

Post-Change in Control Accrued Obligations” has the meaning assigned thereto in Section 6(a) hereof.

Post-Change in Control Severance Payment” has the meaning assigned thereto in Section 6 hereof.

Pre-Change in Control Accrued Obligations” has the meaning assigned thereto in Section 5(a) hereof.

Pre-Change in Control Severance Payment” has the meaning assigned thereto in Section 5 hereof.

Principal Location” has the meaning assigned thereto in clause (b)(iii) of the definition of Good Reason, above.

Proprietary Information” has the meaning assigned thereto in Section 14(a) hereof.

Release” has the meaning assigned thereto in Section 14(d) hereof.

Section 409A Payments” means any of the following:  (a) the Payment in Lieu of Notice, (b) the Pre-Change in Control Severance Payment, (c) the Post-Change in Control Severance Payment, (d) the Additional Post-Change in Control Severance Payment, (e) the Consulting Payment, (f) the payment under Section 6(b) (but only to the extent such payment or portion thereof is subject to Section 409A of the Code), (g) the financial planning services provided under Sections 5(e) and 6(f), and (h) the legal fees and expenses reimbursed under Section 15.

Sempra Energy Control Group” means Sempra Energy and all persons with whom Sempra Energy would be considered a single employer under Section 414(b) or 414(c) of the Code, as determined from time to time.

Separation from Service”, with respect to the Executive (or another Service Provider), means the Executive’s (or such Service Provider’s) (a) termination of employment or (b) other termination or reduction in services, provided that such termination or reduction in clause (a) or (b) constitutes a “separation from service,” as defined in Treasury Regulation Section 1.409A-1(h), with respect to the Service Recipient.

SERP” has the meaning assigned thereto in Section 6(b) hereof.

Service Provider” means the Executive or any other “service provider,” as defined in Treasury Regulation Section 1.409A-1(f).

Service Recipient,” with respect to the Executive, means Sempra Energy (if the Executive is employed by Sempra Energy), or the subsidiary of Sempra Energy employing the Executive, whichever is applicable, and all persons considered part of the “service recipient,” as defined in Treasury Regulation Section 1.409A-1(g), as determined from time to time.  As provided in Treasury Regulation Section 1.409A-1(g), the “Service Recipient” shall mean the person for whom the services are performed and with respect to whom the legally binding right to compensation arises, and all persons with whom such person would be considered a single employer under Section 414(b) or 414(c) of the Code.

Specified Employee” means a Service Provider who, as of the date of the Service Provider’s Separation from Service is a “Key Employee” of the Service Recipient any stock of which is publicly traded on an established securities market or otherwise.  For purposes of this definition, a Service Provider is a “Key Employee” if the Service Provider meets the requirements of Section 416(i)(1)(A)(i), (ii) or (iii) of the Code (applied in accordance with the Treasury Regulations thereunder and disregarding Section 416(i)(5) of the Code) at any time during the Testing Year.  If a Service Provider is a “Key Employee” (as defined above) as of a Specified Employee Identification Date, the Service Provider shall be treated as “Key Employee” for the entire twelve (12) month period beginning on the Specified Employee Effective Date.  For purposes of this definition, a Service Provider’s compensation for a Testing Year shall mean such Service Provider’s compensation, as determined under Treasury Regulation Section 1.415(c)-2(a) (and applied as if the Service Recipient were not using any safe harbor provided in Treasury Regulation Section 1.415(c)-2(d), were not using any of the elective special timing rules provided in Treasury Regulation Section 1.415(c)-2(e), and were not using any of the elective special rules provided in Treasury Regulation Section 1.415(c)-2(g)), from the Service Recipient for such Testing Year.  The “Specified Employees” shall be determined in accordance with Section 409A(a)(2)(B)(i) of the Code and Treasury Regulation Section 1.409A-1(i).

Specified Employee Effective Date” means the first day of the fourth month following the Specified Employee Identification Date.  The Specified Employee Effective Date may be changed by Sempra Energy, in its discretion, in accordance with Treasury Regulation Section 1.409A-1(i)(4).

Specified Employee Identification Date”, for purposes of Treasury Regulation Section 1.409A-1(i)(3), shall mean December 31.  The “Specified Employee Identification Date” shall apply to all “nonqualified deferred compensation plans” (as defined in Treasury Regulation Section 1.409A-1(a)) of the Service Recipient and all affected Service Providers.  The “Specified Employee Identification Date” may be changed by Sempra Energy, in its discretion, in accordance with Treasury Regulation Section 1.409A-1(i)(3).

Testing Year” shall mean the twelve (12) month period ending on the Specified Employee Identification Date, as determined from time to time.

Underpayment” has the meaning assigned thereto in Section 9(b) hereof.

For purposes of this Agreement, references to any “Treasury Regulation” shall mean such Treasury Regulation as in effect on the date hereof.

Section 2.

Sarbanes-Oxley Act of 2002.  Notwithstanding anything herein to the contrary, if the Company determines, in its good faith judgment, that any provision of this Agreement is likely to be interpreted as a personal loan prohibited by the Sarbanes-Oxley Act of 2002 and the rules and regulations promulgated thereunder (the “Act”), then such provision shall be modified as necessary or appropriate so as to not violate the Act; and if this cannot be accomplished, then the Company shall use its reasonable efforts to provide the Executive with similar, but lawful, substitute benefit(s) at a cost to the Company not to significantly exceed the amount the Company would have otherwise paid to provide such benefit(s) to the Executive.  In addition, if the Executive is required to forfeit or to make any repayment of any compensation or benefit(s) to the Company under the Act or any other law, such forfeiture or repayment shall not constitute Good Reason.

Section 3.

Notice and Date of Termination.  

(a)

Any termination of the Executive’s employment by the Company or by the Executive shall be communicated by a written notice of termination to the other party (the “Notice of Termination”).  Where applicable, the Notice of Termination shall indicate the specific termination provision in this Agreement relied upon and shall set forth in reasonable detail the facts and circumstances claimed to provide a basis for termination of the Executive’s employment under the provision so indicated.  Unless the Board determines otherwise, a Notice of Termination by the Executive alleging a termination for Good Reason must be made within 180 days of the act or failure to act that the Executive alleges to constitute Good Reason.  

(b)

The date of the Executive’s termination of employment with the Company (the “Date of Termination”) shall be determined as follows:  (i) if the Executive has a Separation from Service by reason of the Company terminating his or her employment, either with or without Cause, the Date of Termination shall be the date specified in the Notice of Termination (which, in the case of a termination by the Company other than for Cause, shall not be less than two (2) weeks from the date such Notice of Termination is given unless the Company elects to pay the Executive, in addition to any other amounts payable hereunder, an amount (the “Payment in Lieu of Notice”) equal to two (2) weeks of the Executive’s Annual Base Salary in effect on the Date of Termination), and (ii) if the basis for the Executive’s Involuntary Termination is his resignation for Good Reason, the Date of Termination shall be determined by the Executive and specified in the Notice of Termination, but shall not in any event be less than fifteen (15) days nor more than sixty (60) days after the date such Notice of Termination is given.   The Payment in Lieu of Notice shall be paid on such date as is determined by the Company within thirty (30) days after the date of the Executive’s Separation from Service; provided, however, that if the Executive is a Specified Employee on the date of his or her Separation from Service, such Payment in Lieu of Notice shall be paid as provided in Section 10 hereof.

Section 4.

Termination from the Board.  Upon the termination of the Executive’s employment for any reason, the Executive’s membership on the Board, the board of directors of any of the Company’s Affiliates, any committees of the Board and any committees of the board of directors of any of the Company’s Affiliates, if applicable, shall be automatically terminated.

Section 5.

Severance Benefits upon Involuntary Termination Prior to Change in Control.  Except as provided in Section 6 and Section 19(i) hereof, in the event of the Involuntary Termination of the Executive prior to a Change in Control, the Company shall pay the Executive, in one lump sum cash payment, an amount (the “Pre-Change in Control Severance Payment”) equal to the greater of:  (X) 170% of the Executive’s Annual Base Salary as in effect on the Date of Termination, and (Y) the Executive’s Annual Base Salary as in effect on the Date of Termination, plus the Executive’s Average Annual Bonus.  In addition to the Pre-Change in Control Severance Payment, the Executive shall be entitled to the following additional benefits specified in subsections (a) through (e).  Except as provided in Section 5(f), the Pre-Change in Control Severance Payment and the payment under Section 5(a) shall be paid on such date as is determined by the Company within thirty (30) days after the date of the Involuntary Termination; provided, however, that, if the Executive is a Specified Employee on the date of the Executive’s Involuntary Termination, the Pre-Change in Control Severance Payment and the financial planning services provided under Section 5(e) shall be paid as provided in Section 10 hereof.  

(a)

Accrued Obligations.  The Company shall pay the Executive a lump sum amount in cash equal to the sum of (A) the Executive’s Annual Base Salary through the Date of Termination to the extent not theretofore paid, (B) an amount equal to any annual Incentive Compensation Awards earned with respect to fiscal years ended prior to the year that includes the Date of Termination to the extent not theretofore paid, (C) any accrued and unpaid vacation, if any, and (D) reimbursement for unreimbursed business expenses, if any, properly incurred by the Executive in the performance of his duties in accordance with policies established from time to time by the Board, in each case to the extent not theretofore paid.  (The amounts specified in clauses (A), (B), (C) and (D) shall be hereinafter referred to as the “Pre-Change in Control Accrued Obligations”).

(b)

Equity Based Compensation.  The Executive shall retain all rights to any equity-based compensation awards to the extent set forth in the applicable plan and/or award agreement.

(c)

Welfare Benefits.  Subject to Section 12 below, for a period of twelve (12) months following the date of the Involuntary Termination (and an additional twelve (12) months if the Executive provides consulting services under Section 14(e) hereof), the Executive and his dependents shall be provided with health insurance benefits substantially similar to those provided to the Executive and his dependents immediately prior to the date of the Involuntary Termination; provided, however, that such benefits shall be provided on substantially the same terms and conditions and at the same cost to the Executive as in effect immediately prior to the date of the Involuntary Termination.  Such benefits shall be provided through insurance maintained by the Company under the Company’s benefit plans.  Such benefits shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(a)(5).

(d)

Outplacement Services.  The Executive shall receive reasonable outplacement services, on an in-kind basis, suitable to his position and directly related to the Executive’s Involuntary Termination, for a period of twenty-four (24) months following the date of the Involuntary Termination, in an aggregate amount of cost to the Company not to exceed $50,000.  Notwithstanding the foregoing, the Executive shall cease to receive outplacement services on the date the Executive accepts employment with a subsequent employer.  Such outplacement services shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(b)(9)(v)(A).

(e)

Financial Planning Services.  The Executive shall receive financial planning services, on an in-kind basis, for a period of twenty-four (24) months following the Date of Termination.  Such financial planning services shall include expert financial and legal resources to assist the Executive with financial planning needs and shall be limited to (i) current investment portfolio management, (ii) tax planning, (iii) tax return preparation, and (iv) estate planning advice and document preparation (including wills and trusts); provided, however, that the Company shall provide such financial planning services during any taxable year of the Executive only to the extent the cost to the Company for such taxable year does not exceed $25,000.  The Company shall provide such financial planning services through a financial planner selected by the Company, and shall pay the fees for such financial planning services.  The financial planning services provided during any taxable year of the Executive shall not affect the financial planning services provided in any other taxable year of the Executive.  The Executive’s right to financial planning services shall not be subject to liquidation or exchange for any other benefit.  Such financial planning services shall be provided in a manner that complies with Treasury Regulation Section 1.409A-3(i)(1)(iv).  

(f)

Deferral of Payments.  The Executive shall have the right to elect to defer the Pre-Change in Control Severance Payment to be received by the Executive pursuant to this Section 5 under the terms and conditions of the Sempra Energy Employee and Director Savings Plan (the “Deferred Compensation Plan”).  Any such deferral election shall be made in accordance with Section 18(b) hereof.

Section 6.

Severance Benefits upon Involuntary Termination in Connection with and after Change in Control.  Notwithstanding the provisions of Section 5 above, and except as provided in Section 19(i) hereof, in the event of the Involuntary Termination of the Executive on or within two (2) years following a Change in Control, in lieu of the payments described in Section 5 above, the Company shall pay the Executive, in one lump sum cash payment, an amount (the “Post-Change in Control Severance Payment”) equal to two times the greater of:  (X)  170% of the Executive’s Annual Base Salary as in effect immediately prior to the Change in Control or the Date of Termination, whichever is greater, and (Y) the Executive’s Annual Base Salary as in effect immediately prior to the Change in Control or on the Date of Termination, whichever is greater, plus the Executive’s Average Annual Bonus.  In addition to the Post-Change in Control Severance Payment, the Executive shall be entitled to the following additional benefits specified in subsections (a) through (f).  Except as provided in Sections 6(g) and 6(h), the Post-Change in Control Severance Payment and the payments under Sections 6(a) and (b) shall be paid on such date as is determined by the Company within thirty (30) days after the date of the Involuntary Termination; provided, however, that, if the Executive is a Specified Employee on the date of the Executive’s Involuntary Termination, the Post-Change in Control Severance Payment, the Additional Post-Change in Control Severance Payment under Section 6(a)(E), the payment under Section 6(b) (but only to the extent such payment or portion thereof is subject to Section 409A of the Code), and the financial planning services provided under Section 6(f) shall be paid as provided in Section 10 hereof.

(a)

Accrued Obligations.  The Company shall pay the Executive a lump sum amount in cash equal to the sum of (A) the Executive’s Annual Base Salary through the Date of Termination to the extent not theretofore paid, (B) an amount equal to any annual Incentive Compensation Awards earned with respect to fiscal years ended prior to the year that includes the Date of Termination to the extent not theretofore paid, (C) any accrued and unpaid vacation, if any, (D) reimbursement for unreimbursed business expenses, if any, properly incurred by the Executive in the performance of his duties in accordance with policies established from time to time by the Board, and (E) an amount (the “Additional Post-Change in Control Severance Payment”) equal to:  (i) the greater of:  (X) 70% of the Executive’s Annual Base Salary as in effect immediately prior to the Change in Control or on the Date of Termination, whichever is greater, or (Y) the Executive’s Average Annual Bonus, multiplied by (ii) a fraction, the numerator of which shall be the number of days from the beginning of such fiscal year to and including the Date of Termination and the denominator of which shall be 365, in the case of each amount described in clause (A), (B), (C) or (D) to the extent not theretofore paid.  (The amounts specified in clauses (A), (B), (C), (D) and (E) shall be hereinafter referred to as the “Post-Change in Control Accrued Obligations”).

(b)

Pension Supplement.  The Executive shall be entitled to receive a Supplemental Retirement Benefit under the Sempra Energy Supplemental Executive Retirement Plan, as in effect from time to time (“SERP”), determined in accordance with this Section 6(b), in the event that the Executive is a “Participant” (as defined in the SERP) as of the Date of Termination.  Such Supplemental Retirement Benefit shall be determined by crediting the Executive with additional months of Service (if any) equal to the number of full calendar months from the Date of Termination to the date on which the Executive would have attained age 62.  The Executive shall be entitled to receive such Supplemental Retirement Benefit without regard to whether the Executive has attained age 55 or completed five years of “Service” (as defined in the SERP) as of the Date of Termination.  The Executive shall be treated as qualified for “Retirement” (as defined in the SERP) as of the Date of Termination, and the Executive’s Vesting Factor with respect to the Supplemental Retirement Benefit shall be 100%.  The Executive’s Supplemental Retirement Benefit shall be calculated based on the Executive’s actual age as of the date of commencement of payment of such Supplemental Retirement Benefit (the “SERP Distribution Date”), and by applying the applicable early retirement factors under the SERP, if the Executive has not attained age 62 but has attained age 55 as of the SERP Distribution Date.  If the Executive has not attained age 55 as of the SERP Distribution Date, the Executive’s Supplemental Retirement Benefit shall be calculated by applying the applicable early retirement factor under the SERP for age 55, and the Supplemental Retirement Benefit otherwise payable at age 55 shall be actuarially adjusted to the Executive’s actual age as of the SERP Distribution Date using the following actuarial assumptions:  (i) the applicable mortality table promulgated by the Internal Revenue Service under Section 417(e)(3) of the Code, as in effect on the first day of the calendar year in which the SERP Distribution Date occurs, and (ii) the applicable interest rate promulgated by the Internal Revenue Service under Section 417(a)(3) of the Code for the November next preceding the first day of the calendar year in which the SERP Distribution Date occurs.  The Executive’s Supplemental Retirement Benefit shall be determined in accordance with this Section 6(b), notwithstanding any contrary provisions of the SERP and, to the extent subject to Section 409A of the Code, shall be paid in accordance with Treasury Regulation Section 1.409A-3(c)(1).  The Supplemental Retirement Benefit paid to or on behalf of the Executive in accordance with this Section 6(b) shall be in full satisfaction of any and all of the benefits payable to or on behalf of the Executive under the SERP.  

(c)

Equity-Based Compensation.  Notwithstanding the provisions of any applicable equity-compensation plan or award agreement to the contrary, all equity-based Incentive Compensation Awards (including, without limitation, stock options, stock appreciation rights, restricted stock awards, restricted stock units, performance share awards, awards covered under Section 162(m) of the Code, and dividend equivalents) held by the Executive shall immediately vest and become exercisable or payable, as the case may be, as of the Date of Termination, to be exercised or paid, as the case may be, in accordance with the terms of the applicable Incentive Compensation Plan and Incentive Compensation Award agreement, and any restrictions on any such Incentive Compensation Awards shall automatically lapse; provided, however, that any such stock option or stock appreciation rights awards granted on or after June 26, 1998 shall remain outstanding and exercisable until the earlier of (A) the later of eighteen (18) months following the Date of Termination or the period specified in the applicable Incentive Compensation Award agreements or (B) the expiration of the original term of such Incentive Compensation Award (or, if earlier, the tenth anniversary of the original date of grant) (it being understood that all Incentive Compensation Awards granted prior to or after June 26, 1998 shall remain outstanding and exercisable for a period that is no less than that provided for in the applicable agreement in effect as of the date of grant).

(d)

Welfare Benefits.  Subject to Section 12 below, for a period of twenty-four (24) months following the date of Involuntary Termination (and an additional twelve (12) months if the Executive provides consulting services under Section 14(e) hereof), the Executive and his dependents shall be provided with life, disability, accident and health insurance benefits substantially similar to those provided to the Executive and his dependents immediately prior to the date of Involuntary Termination or the Change in Control Date, whichever is more favorable to the Executive; provided, however, that such benefits shall be provided on substantially the same terms and conditions and at the same cost to the Executive as in effect immediately prior to the date of Involuntary Termination or the Change in Control Date, whichever is more favorable to the Executive.  Such benefits shall be provided through insurance maintained by the Company under the Company benefit plans.  Such benefits shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(a)(5).

(e)

Outplacement Services.  The Executive shall receive reasonable outplacement services, on an in-kind basis, suitable to his position and directly related to the Executive’s Involuntary Termination, for a period of thirty-six (36) months following the date of Involuntary Termination (but in no event beyond the last day of the Executive’s second taxable year following the Executive’s taxable year in which the Involuntary Termination occurs), in the aggregate amount of cost to the Company not to exceed $50,000.  Notwithstanding the foregoing, the Executive shall cease to receive outplacement services on the date the Executive accepts employment with a subsequent employer.  Such outplacement services shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(b)(9)(v)(A).

(f)

Financial Planning Services.  The Executive shall receive financial planning services, on an in-kind basis, for a period of thirty-six (36) months following the date of Involuntary Termination.  Such financial planning services shall include expert financial and legal resources to assist the Executive with financial planning needs and shall be limited to (i) current investment portfolio management, (ii) tax planning, (iii) tax return preparation, and (iv) estate planning advice and document preparation (including wills and trusts); provided, however, that the Company shall provide such financial services during any taxable year of the Executive only to the extent the cost to the Company for such taxable year does not exceed $25,000.  The Company shall provide such financial planning services through a financial planner selected by the Company, and shall pay the fees for such financial planning services.  The financial planning services provided during any taxable year of the Executive shall not affect the financial planning services provided in any other taxable year of the Executive.  The Executive’s right to financial planning services shall not be subject to liquidation or exchange for any other benefit.  Such financial planning services shall be provided in a manner that complies with Section 1.409A-3(i)(1)(iv).   

(g)

Involuntary Termination in Connection with a Change in Control.  Notwithstanding anything contained herein, in the event of an Involuntary Termination prior to a Change in Control, if the Involuntary Termination (1) was at the request of a third party who has taken steps reasonably calculated to effect such Change in Control or (2) otherwise arose in connection with or in anticipation of such Change in Control, then the Executive shall, in lieu of the payments described in Section 5 hereof, be entitled to the Post-Change in Control Severance Payment and the additional benefits described in this Section 6 as if such Involuntary Termination had occurred within two (2) years following the Change in Control.  The amounts specified in Section 6 that are to be paid under this Section 6(g) shall be reduced by any amount previously paid under Section 5.  The amounts to be paid under this Section 6(g) shall be paid within thirty (30) days after the Change in Control Date of such Change in Control.

(h)

Deferral of Payments.  The Executive shall have the right to elect to defer the Post-Change in Control Severance Payment to be received by the Executive pursuant to this Section 6 under the terms and conditions of the Deferred Compensation Plan.  Any such deferral election shall be made in accordance with Section 18(b) hereof.

Section 7.

Severance Benefits upon Termination by the Company for Cause or by the Executive Other than for Good Reason.  If the Executive’s employment shall be terminated for Cause, or if the Executive terminates employment other than for Good Reason, the Company shall have no further obligations to the Executive under this Agreement other than the Pre-Change in Control Accrued Obligations and any amounts or benefits described in Section 11 hereof.

Section 8.

Severance Benefits upon Termination due to Death or Disability.  If the Executive has a Separation from Service by reason of death or Disability, the Company shall pay the Executive or his estate, as the case may be, the Post-Change in Control Accrued Obligations (without regard to whether a Change in Control has occurred) and any amounts or benefits described in Section 11 hereof.  Such payments shall be in addition to those rights and benefits to which the Executive or his estate may be entitled under the relevant Company plans or programs.  Such payments shall be paid on such date as determined by the Company within thirty (30) days after the date of the Separation from Service; provided, however, that if the Executive is a Specified Employee on the date of the Executive’s Separation from Service by reason of Disability, the Additional Post-Change in Control Severance Payment under Section 6(a)(E) shall be paid as provided in Section 10 hereof.

Section 9.

Limitation on Payments by the Company.  

(a)

Anything in this Agreement to the contrary notwithstanding and except as set forth in this Section 9 below, in the event it shall be determined that any payment or distribution in the nature of compensation (within the meaning of Section 280G(b)(2) of the Code) to or for the benefit of the Executive, whether paid or payable pursuant to this Agreement or otherwise (the “Payment”) would be subject (in whole or in part) to the excise tax imposed by Section 4999 of the Code, (the “Excise Tax”), then, subject to subsection (b), the Pre-Change in Control Severance Payment or the Post-Change in Control Severance Payment (whichever is applicable) payable under this Agreement shall be reduced under this subsection (a) to the amount equal to the Reduced Payment.  For such Payment payable under this Agreement, the “Reduced Payment” shall be the amount equal to the greatest portion of the Payment (which may be zero)  that, if paid, would result in no portion of any Payment being subject to the Excise Tax.  

(b)

The Pre-Change in Control Severance Benefit or the Post-Change in Control Severance Payment (whichever is applicable) payable under this Agreement shall not be reduced under subsection (a) if:  

(i)

such reduction in such Payment is not sufficient to cause no portion of any Payment to be subject to the Excise Tax, or

(ii)

the Net After-Tax Unreduced Payments (as defined below) would equal or exceed one hundred and five percent (105%) of the Net After-Tax Reduced Payments (as defined below).  

For purposes of determining the amount of any Reduced Payment under subsection (a), and the Net-After Tax Reduced Payments and the Net After-Tax Unreduced Payments, the Executive shall be considered to pay federal, state and local income and employment taxes at the Executive’s applicable marginal rates taking into consideration any reduction in federal income taxes which could be obtained from the deduction of state and local income taxes, and any reduction or disallowance of itemized deductions and personal exemptions under applicable tax law).  The applicable federal, state and local income and employment taxes and the Excise Tax (to the extent applicable) are collectively referred to as the “Taxes”.

(c)

The following definitions shall apply for purposes of this Section 9:

(i)

“Net After-Tax Reduced Payments” shall mean the total amount of all Payments that the Executive would retain, on a Net After-Tax Basis, in the event that the Payments payable under this Agreement are reduced pursuant to subsection (a).

(ii)

“Net After-Tax Unreduced Payments” shall mean the total amount of all Payments that the Executive would retain, on a Net After-Tax Basis, in the event that the Payments payable under this Agreement are not reduced pursuant to subsection (a).

(iii)

“Net After-Tax Basis” shall mean, with respect to the Payments, either with or without reduction under subsection (a) (as applicable), the amount that would be retained by the Executive from such Payments after the payment of all Taxes.

(d)

All determinations required to be made under this Section 9 and the assumptions to be utilized in arriving at such determinations, shall be made by a nationally recognized accounting firm as may be agreed by the Company and the Executive (the “Accounting Firm”); provided, that the Accounting Firm’s determination shall be made based upon “substantial authority” within the meaning of Section 6662 of the Code.  The Accounting Firm shall provide detailed supporting calculations to both the Company and the Executive within fifteen (15) business days of the receipt of notice from the Executive that there has been a Payment or such earlier time as is requested by the Company.  All fees and expenses of the Accounting Firm shall be borne solely by the Company.  Any determination by the Accounting Firm shall be binding upon the Company and the Executive.  For purposes of determining whether and the extent to which the Payments will be subject to the Excise Tax, (i) no portion of the Payments the receipt or enjoyment of which the Executive shall have waived at such time and in such manner as not to constitute a “payment” within the meaning of Section 280G(b) of the Code shall be taken into account, (ii) no portion of the Payments shall be taken into account which, in the written opinion of the Accounting Firm, does not constitute a “parachute payment” within the meaning of Section 280G(b)(2) of the Code (including by reason of Section 280G(b)(4)(A) of the Code) and, in calculating the Excise Tax, no portion of such Payments shall be taken into account which, in the opinion of the Accounting Firm, constitutes reasonable compensation for services actually rendered, within the meaning of Section 280G(b)(4)(B) of the Code, in excess of the base amount (as defined in Section 280G(b)(3) of the Code) allocable to such reasonable compensation, and (iii) the value of any non-cash benefit or any deferred payment or benefit included in the Payments shall be determined by the Accounting Firm in accordance with the principles of Sections 280G(d)(3) and (4) of the Code.

Section 10.

Delayed Distribution under Section 409A of the Code.  If the Executive is a Specified Employee on the date of the Executive’s Involuntary Termination (or on the date of the Executive’s Separation from Service by reason of Disability), the Section 409A Payments, and any other payments or benefits under this Agreement subject to Section 409A of the Code, shall be delayed in order to avoid a prohibited distribution under Section 409A(a)(2)(B)(i) of the Code, and such payments or benefits shall be paid or distributed to the Executive during the thirty (30) day period commencing on the earlier of (a) the expiration of the six-month period measured from the date of the Executive’s Separation from Service or (b) the date of the Executive’s death.  Upon the expiration of the applicable six-month period under Section 409A(a)(2)(B)(i) of the Code, all payments deferred pursuant to this Section 10 (excluding in-kind benefits) shall be paid in a lump sum payment to the Executive, plus interest thereon from the date of the Executive’s Involuntary Termination through the payment date at an annual rate equal to Moody’s Rate.  The “Moody’s Rate” shall mean the average of the daily Moody’s Corporate Bond Yield Average – Monthly Average Corporates as published by Moody’s Investors Service, Inc. (or any successor) for the month next preceding the Date of Termination.  Any remaining payments due under the Agreement shall be paid as otherwise provided herein.

Section 11.

Nonexclusivity of Rights.  Nothing in this Agreement shall prevent or limit the Executive’s continuing or future participation in any benefit, plan, program, policy or practice provided by the Company and for which the Executive may qualify (except with respect to any benefit to which the Executive has waived his rights in writing), including, without limitation, any and all indemnification arrangements in favor of the Executive (whether under agreements or under the Company’s charter documents or otherwise), and insurance policies covering the Executive, nor shall anything herein limit or otherwise affect such rights as the Executive may have under any other contract or agreement entered into after the Effective Date with the Company.  Amounts which are vested benefits or which the Executive is otherwise entitled to receive under any benefit, plan, policy, practice or program of, or any contract or agreement entered into with, the Company shall be payable in accordance with such benefit, plan, policy, practice or program or contract or agreement except as explicitly modified by this Agreement.  At all times during the Executive’s employment with the Company and thereafter, the Company shall provide (to the extent permissible under applicable law) the Executive with indemnification and D&O insurance insuring the Executive against insurable events which occur or have occurred while the Executive was a director or the Executive officer of the Company, on terms and conditions that are at least as generous as that then provided to any other current or former director or the Executive officer of the Company or any Affiliate.  Such indemnification and D&O insurance shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(b)(10).

Section 12.

Full Settlement; Mitigation.  The Company’s obligation to make the payments provided for in this Agreement and otherwise to perform its obligations hereunder shall not be affected by any set-off, counterclaim, recoupment, defense or other claim, right or action which the Company may have against the Executive or others, provided that nothing herein shall preclude the Company from separately pursuing recovery from the Executive based on any such claim.  In no event shall the Executive be obligated to seek other employment or take any other action by way of mitigation of the amounts (including amounts for damages for breach) payable to the Executive under any of the provisions of this Agreement, and such amounts shall not be reduced whether or not the Executive obtains other employment.

Section 13.

Dispute Resolution.

Any disagreement, dispute, controversy or claim arising out of or relating to this Agreement or the interpretation of this Agreement or any arrangements relating to this Agreement or contemplated in this Agreement or the breach, termination or invalidity thereof shall be settled by final and binding arbitration administered by JAMS in San Diego, California in accordance with the then existing JAMS arbitration rules applicable to employment disputes (the “JAMS Rules”); provided that, notwithstanding any provision in such rules to the contrary, in all cases the parties shall be entitled to reasonable discovery.  In the event of such an arbitration proceeding, the Executive and the Company shall select a mutually acceptable neutral arbitrator from among the JAMS panel of arbitrators.  In the event the Executive and the Company cannot agree on an arbitrator, the arbitrator shall be selected in accordance with the then existing JAMS Rules.  Neither the Executive nor the Company nor the arbitrator shall disclose the existence, content or results of any arbitration hereunder without the prior written consent of all parties, except to the extent necessary to enforce any arbitration award in a court of competent jurisdiction.  Except as provided herein, the Federal Arbitration Act shall govern the interpretation of, enforcement of and all proceedings under this agreement to arbitrate.  The arbitrator shall apply the substantive law (and the law of remedies, if applicable) of the state of California, or federal law, or both, as applicable, and the arbitrator is without jurisdiction to apply any different substantive law.  The arbitrator shall have the authority to entertain a motion to dismiss and/or a motion for summary judgment by any party and shall apply the standards governing such motions under the Federal Rules of Civil Procedure.  The arbitrator shall render an award and a written, reasoned opinion in support thereof.  Judgment upon the award may be entered in any court having jurisdiction thereof.  The Executive shall not be required to pay any arbitration fee or cost that is unique to arbitration or greater than any amount he would be required to pay to pursue his claims in a court of competent jurisdiction.

Section 14.

Executive’s Covenants.    

(a)

Confidentiality.  The Executive acknowledges that in the course of his employment with the Company, he has acquired non-public privileged or confidential information and trade secrets concerning the operations, future plans and methods of doing business (“Proprietary Information”) of the Company and its Affiliates; and the Executive agrees that it would be extremely damaging to the Company and its Affiliates if such Proprietary Information were disclosed to a competitor of the Company and its Affiliates or to any other person or corporation.  The Executive understands and agrees that all Proprietary Information has been divulged to the Executive in confidence and further understands and agrees to keep all Proprietary Information secret and confidential (except for such information which is or becomes publicly available other than as a result of a breach by the Executive of this provision or information the Executive is required by any governmental, administrative or court order to disclose) without limitation in time.  In view of the nature of the Executive’s employment and the Proprietary Information the Executive has acquired during the course of such employment, the Executive likewise agrees that the Company and its Affiliates would be irreparably harmed by any disclosure of Proprietary Information in violation of the terms of this paragraph and that the Company and its Affiliates shall therefore be entitled to preliminary and/or permanent injunctive relief prohibiting the Executive from engaging in any activity or threatened activity in violation of the terms of this paragraph and to any other relief available to them.  Inquiries regarding whether specific information constitutes Proprietary Information shall be directed to the Company’s Senior Vice President, Public Policy (or, if such position is vacant, the Company’s then Chief Executive Officer); provided, that the Company shall not unreasonably classify information as Proprietary Information.

(b)

Non-Solicitation of Employees.  The Executive recognizes that he possesses and will possess confidential information about other employees of the Company and its Affiliates relating to their education, experience, skills, abilities, compensation and benefits, and inter-personal relationships with customers of the Company and its Affiliates.  The Executive recognizes that the information he possesses and will possess about these other employees is not generally known, is of substantial value to the Company and its Affiliates in developing their business and in securing and retaining customers, and has been and will be acquired by him because of his business position with the Company and its Affiliates.  The Executive agrees that at all times during the Executive’s employment with the Company and for a period of one (1) year thereafter, he will not, directly or indirectly, solicit or recruit any employee of the Company or its Affiliates for the purpose of being employed by him or by any competitor of the Company or its Affiliates on whose behalf he is acting as an agent, representative or employee and that he will not convey any such confidential information or trade secrets about other employees of the Company and its Affiliates to any other person; provided, however, that it shall not constitute a solicitation or recruitment of employment in violation of this paragraph to discuss employment opportunities with any employee of the Company or its Affiliates who has either first contacted the Executive or regarding whose employment the Executive has discussed with and received the written approval of the Company’s Vice President, Human Resources (or, if such position is vacant, the Company’s then Chief Executive Officer), prior to making such solicitation or recruitment.  In view of the nature of the Executive’s employment with the Company, the Executive likewise agrees that the Company and its Affiliates would be irreparably harmed by any solicitation or recruitment in violation of the terms of this paragraph and that the Company and its Affiliates shall therefore be entitled to preliminary and/or permanent injunctive relief prohibiting the Executive from engaging in any activity or threatened activity in violation of the terms of this paragraph and to any other relief available to them.

(c)

Survival of Provisions.  The obligations contained in Section 14(a) and Section 14(b) above shall survive the termination of the Executive’s employment within the Company and shall be fully enforceable thereafter.  If it is determined by a court of competent jurisdiction in any state that any restriction in Section 14(a) or Section 14(b) above is excessive in duration or scope or is unreasonable or unenforceable under the laws of that state, it is the intention of the parties that such restriction may be modified or amended by the court to render it enforceable to the maximum extent permitted by the law of that state.

(d)

Release; Lump Sum Payment.  In the event of the Executive’s Involuntary Termination,  if the Executive (i) agrees to the covenants described in Section 14(a) and Section 14(b) above, (ii) executes a release (the “Release”) of all claims substantially in the form attached hereto as Exhibit A within fifty (50) days after the date of Involuntary Termination and does not revoke such Release in accordance with the terms thereof, and (iii) agrees to provide the consulting services described in Section 14(e) below, then in consideration for such covenants, the Company shall pay the Executive, in one cash lump sum, an amount (the “Consulting Payment”) in cash equal to the greater of:  (X) 170% of the Executive’s Annual Base Salary as in effect on the Date of Termination, and (Y) the Executive’s Annual Base Salary as in effect on the Date of Termination, plus the Executive’s Average Annual Bonus.  Except as provided in this subsection, the Consulting Payment shall be paid on such date as is determined by the Company within the ten (10) day period commencing on the 60th day after the date of the Executive’s Involuntary Termination; provided, however, that if the Executive is a Specified Employee on the date of the Executive’s Involuntary Termination, the Consulting Payment shall be paid as provided in Section 10 hereof.  The Executive shall have the right to elect to defer the Consulting Payment under the terms and conditions of the Company’s Deferred Compensation Plan.  Any such deferral election shall be made in accordance with Section 18(b) hereof.

(e)

Consulting.  If the Executive agrees to the covenants described in Section 14(d) above,  then the Executive shall have the obligation to provide consulting services to the Company as an independent contractor, commencing on the Date of Termination and ending on the second anniversary of the Date of Termination (the “Consulting Period”).  The Executive shall hold himself available at reasonable times and on reasonable notice to render such consulting services as may be so assigned to him by the Board or the Company’s then Chief Executive Officer; provided, however, that unless the parties otherwise agree, the consulting services rendered by the Executive during the Consulting Period shall not exceed twenty (20) hours each month; and, provided, further, that the consulting services rendered by the Executive during the Consulting Period shall in no event exceed twenty percent (20%) of the average level of services performed by the Executive for the Company over the thirty-six (36) month period immediately preceding the Executive’s Separation from Service (or the full period of services to the Company, if the Executive has been providing services to the Company for less than thirty-six (36) months).  The Company agrees to use its best efforts during the Consulting Period to secure the benefit of the Executive’s consulting services so as to minimize the interference with the Executive’s other activities, including requiring the performance of consulting services at the Company’s offices only when such services may not be reasonably performed off-site by the Executive.

Section 15.

Legal Fees.  

(a)

Reimbursement of Legal Fees.  Subject to subsection (b), in the event of the Executive’s Separation from Service either (1) prior to a Change in Control, or (2) on or within two (2) years following a Change in Control, the Company shall reimburse the Executive for all legal fees and expenses (including but not limited to fees and expenses in connection with any arbitration) incurred by the Executive in disputing any issue arising under this Agreement relating to the Executive’s Separation from Service or in seeking to obtain or enforce any benefit or right provided by this Agreement.  

(b)

Requirements for Reimbursement.  The Company shall reimburse the Executive’s legal fees and expenses pursuant to subsection (a) above only to the extent the arbitrator or court determines the following:  (i) the Executive disputed such issue, or sought to obtain or enforce such benefit or right, in good faith, (ii) the Executive had a reasonable basis for such claim, and (iii) in the case of subsection (a)(1) above, the Executive is the prevailing party.  In addition, the Company shall reimburse such legal fees and expenses, only if such legal fees and expenses are incurred during the twenty (20) year period beginning on the date of the Executive’s Separation from Service.   The legal fees and expenses paid to the Executive for any taxable year of the Executive shall not affect the legal fees and expenses paid to the Executive for any other taxable year of the Executive.  The legal fees and expenses shall be paid to the Executive on or before the last day of the Executive’s taxable year following the taxable year in which the fees or expenses are incurred.  The Executive’s right to reimbursement of legal fees and expenses shall not be subject to liquidation or exchange for any other benefit.  Such right to reimbursement of legal fees and expenses shall be provided in a manner that complies with Treasury Regulation Section 1.409A-3(i)(1)(iv).  If the Executive is a Specified Employee on the date of the Executive’s Separation from Service, such right to reimbursement of legal fees and expenses shall be paid as provided in Section 10 hereof.

Section 16.

Successors.

(a)

Assignment by the Executive.  This Agreement is personal to the Executive and without the prior written consent of Sempra Energy shall not be assignable by the Executive otherwise than by will or the laws of descent and distribution.  This Agreement shall inure to the benefit of and be enforceable by the Executive’s legal representatives.

(b)

Successors and Assigns of Sempra Energy.  This Agreement shall inure to the benefit of and be binding upon Sempra Energy, its successors and assigns.  Sempra Energy may not assign this Agreement to any person or entity (except for a successor described in Section 16(c), (d) or (e) below) without the Executive’s written consent.

(c)

Assumption.  Sempra Energy shall require any successor (whether direct or indirect, by purchase, merger, consolidation or otherwise) to all or substantially all of the business and/or assets of Sempra Energy to assume expressly and agree to perform the obligations and satisfy and discharge the liabilities of this Agreement in the same manner and to the same extent that Sempra Energy would have been required to perform the obligations and satisfy and discharge the liabilities under this Agreement if no such succession had taken place, and Sempra Energy shall have no further obligations and liabilities under this Agreement.  Upon such assumption, references to Sempra Energy in this Agreement shall be replaced with references to such successor.

(d)

Sale of Subsidiary.  In the event that (i) the Executive is employed by a direct or indirect subsidiary of Sempra Energy that is a member of the Sempra Energy Control Group, (ii) Sempra Energy, directly or indirectly through one or more intermediaries, sells or otherwise disposes of such subsidiary, and (iii) such subsidiary ceases to be a member of the Sempra Energy Control Group, then if, on the date such subsidiary ceases to be a member of the Sempra Energy Control Group, the Executive continues in employment with such subsidiary and the Executive does not have a Separation from Service, Sempra Energy shall require such subsidiary or any successor (whether direct or indirect, by purchase merger, consolidation or otherwise) to such subsidiary, or the parent thereof, to assume expressly and agree to perform the obligations and satisfy and discharge the liabilities under this Agreement in the same manner and to the same extent that Sempra Energy would have been required to perform the obligations and satisfy and discharge the liabilities under this Agreement, if such subsidiary had not ceased to be part of the Sempra Energy Control Group, and, upon such assumption, Sempra Energy shall have no further obligations and liabilities under the Agreement.  Upon such assumption, (i) references to Sempra Energy in this Agreement shall be replaced with references to such subsidiary, or such successor or parent thereof, assuming this Agreement, and (ii) subsection (b) of the definition of “Cause” and subsection (b) of the definition of “Good Reason” shall apply thereafter, as if a Change in Control had occurred on the date of such cessation.

(e)

Sale of Assets of Subsidiary.  In the event that (i) the Executive is employed by a direct or indirect subsidiary of Sempra Energy, and (ii) such subsidiary sells or otherwise disposes of substantial assets of such subsidiary to an unrelated service recipient, as determined under Treasury Regulation Section 1.409A-1(f)(2)(ii) (the “Asset Purchaser”), in a transaction described in Treasury Regulation Section 1.409A-1(h)(4) (an “Asset Sale”), then if, on the date of such Asset Sale, the Executive becomes employed by the Asset Purchaser, Sempra Energy and the Asset Purchaser shall specify, in accordance with Treasury Regulation Section 1.409A-1(h)(4), that the Executive shall not be treated as having a Separation from Service, and Sempra Energy shall require such Asset Purchaser, or the parent thereof, to assume expressly and agree to perform the obligations and satisfy and discharge the liabilities under this Agreement in the same manner and to the same extent that Sempra Energy would have been required to perform the obligations and satisfy and discharge the liabilities under this Agreement, if the Asset Sale had not taken place, and, upon such assumption, Sempra Energy shall have no further obligations and liabilities under the Agreement.  Upon such assumption, (i) references to Sempra Energy in this Agreement shall be replaced with references to the Asset Purchaser or the parent thereof, as applicable, and (ii) subsection (b) of the definition of “Cause” and subsection (b) of the definition of “Good Reason” shall apply thereafter, as if a Change in Control had occurred on the date of the Asset Sale.

Section 17.

Administration Prior to Change in Control.  Prior to a Change in Control, the Compensation Committee shall have full and complete authority to construe and interpret the provisions of this Agreement, to determine an individual’s entitlement to benefits under this Agreement, to make in its sole and absolute discretion all determinations contemplated under this Agreement, to investigate and make factual determinations necessary or advisable to administer or implement this Agreement, and to adopt such rules and procedures as it deems necessary or advisable for the administration or implementation of this Agreement.  All determinations made under this Agreement by the Compensation Committee shall be final and binding on all interested persons.  Prior to a Change in Control, the Compensation Committee may delegate responsibilities for the operation and administration of this Agreement to one or more officers or employees of the Company.  The provisions of this Section 17 shall terminate and be of no further force and effect upon the occurrence of a Change in Control.   

Section 18.

Section 409A of the Code.

(a)

Compliance with and Exemption from Section 409A of the Code.  Certain payments and benefits payable under this Agreement (including, without limitation, the Section 409A Payments) are intended to comply with the requirements of Section 409A of the Code.  Certain payments and benefits payable under this Agreement are intended to be exempt from the requirements of Section 409A of the Code.  This Agreement shall be interpreted in accordance with the applicable requirements of, and exemptions from, Section 409A of the Code and the Treasury Regulations thereunder.  To the extent the payments and benefits under this Agreement are subject to Section 409A of the Code, this Agreement shall be interpreted, construed and administered in a manner that satisfies the requirements of Sections 409A(a)(2), (3) and (4) of the Code and the Treasury Regulations thereunder (subject to the transitional relief under Internal Revenue Service Notice 2005-1, the Proposed Regulations under Section 409A of the Code, Internal Revenue Service Notice 2006-79, Internal Revenue Service Notice 2007-78, Internal Revenue Service Notice 2007-86 and other applicable authority issued by the Internal Revenue Service).  As provided in Internal Revenue Notice 2007-86, notwithstanding any other provision of this Agreement, with respect to an election or amendment to change a time or form of payment under this Agreement made on or after January 1, 2008 and on or before December 31, 2008, the election or amendment shall apply only with respect to payments that would not otherwise be payable in 2008, and shall not cause payments to be made in 2008 that would not otherwise be payable in 2008.  If the Company and the Executive determine that any compensation, benefits or other payments that are payable under this Agreement and intended to comply with Sections 409A(a)(2), (3) and (4) of the Code do not comply with Section 409A of the Code, the Treasury Regulations thereunder and other applicable authority issued by the Internal Revenue Service, to the extent permitted under Section 409A of the Code, the Treasury Regulations thereunder and any applicable authority issued by the Internal Revenue Service, the Company and the Executive agree to amend this Agreement, or take such other actions as the Company and the Executive deem reasonably necessary or appropriate, to cause such compensation, benefits and other payments to comply with the requirements of Section 409A of the Code, the Treasury Regulations thereunder and other applicable authority issued by the Internal Revenue Service, while providing compensation, benefits and other payments that are, in the aggregate, no less favorable than the compensation, benefits and other payments provided under this Agreement.  In the case of any compensation, benefits or other payments that are payable under this Agreement and intended to comply with Sections 409A(a)(2), (3) and (4) of the Code, if any provision of the Agreement would cause such compensation, benefits or other payments to fail to so comply, such provision shall not be effective and shall be null and void with respect to such compensation, benefits or other payments to the extent such provision would cause a failure to comply, and such provision shall otherwise remain in full force and effect.

(b)

Deferral Elections.  As provided in Sections 5(f), 6(h) and 14(d), the Executive may elect to defer the Pre-Change in Control Severance Payment, the Post-Change in Control Severance Payment and the Consulting Payment as follows.    The Executive’s deferral election shall satisfy the requirements of Treasury Regulation Section 1.409A-2(b) and the terms and conditions of the Deferred Compensation Plan.  Such deferral election shall designate the whole percentage (up to a maximum of 100%) of the Pre-Change in Control Severance Payment, the Post-Change in Control Severance Payment and the Consulting Payment to be deferred, shall be irrevocable when made, and shall not take effect until at least twelve (12) months after the date on which the election is made.  Such deferral election shall provide that the amount deferred shall be deferred for a period of not less than five (5) years from the date the payment of the amount deferred would otherwise have been made, in accordance with Treasury Regulation Section 1.409A-2(b)(1)(ii).

Section 19.

Miscellaneous.

(a)

Governing Law.  This Agreement shall be governed by and construed in accordance with the laws of the State of California, without reference to its principles of conflict of laws.  The captions of this Agreement are not part of the provisions hereof and shall have no force or effect.  This Agreement may not be amended, modified, repealed, waived, extended or discharged except by an agreement in writing signed by the party against whom enforcement of such amendment, modification, repeal, waiver, extension or discharge is sought.  No person, other than pursuant to a resolution of the Board or a committee thereof, shall have authority on behalf of the Company to agree to amend, modify, repeal, waive, extend or discharge any provision of this Agreement or anything in reference thereto.

(b)

Notices.  All notices and other communications hereunder shall be in writing and shall be given by hand delivery to the other party or by registered or certified mail, return receipt requested, postage prepaid, addressed, in either case, to the Company’s headquarters or to such other address as either party shall have furnished to the other in writing in accordance herewith.  Notices and communications shall be effective when actually received by the addressee.

(c)

Severability.  The invalidity or unenforceability of any provision of this Agreement shall not affect the validity or enforceability of any other provision of this Agreement.

(d)

Taxes.  The Company may withhold from any amounts payable under this Agreement such federal, state or local taxes as shall be required to be withheld pursuant to any applicable law or regulation.

(e)

No Waiver.  The Executive’s or the Company’s failure to insist upon strict compliance with any provision hereof or any other provision of this Agreement or the failure to assert any right the Executive or the Company may have hereunder, including, without limitation, the right of the Executive to terminate employment for Good Reason pursuant to Section 1 hereof, or the right of the Company to terminate the Executive’s employment for Cause pursuant to Section 1 hereof shall not be deemed to be a waiver of such provision or right or any other provision or right of this Agreement.

(f)

Entire Agreement; Exclusive Benefit; Supersession of Prior Agreement.  This instrument contains the entire agreement of the Executive, the Company or any predecessor or subsidiary thereof with respect to any severance or termination pay.  The Pre-Change in Control Severance Payment, the Post-Change in Control Severance Payment and all other benefits provided hereunder shall be in lieu of any other severance payments to which the Executive is entitled under any other severance plan or program or arrangement sponsored by the Company, as well as pursuant to any individual employment or severance agreement that was entered into by the Executive and the Company, and, upon the Effective Date of this Agreement, all such plans, programs, arrangements and agreements are hereby automatically superseded and terminated.

(g)

No Right of Employment.  Nothing in this Agreement shall be construed as giving the Executive any right to be retained in the employ of the Company or shall interfere in any way with the right of the Company to terminate the Executive’s employment at any time, with or without Cause.

(h)

Unfunded Obligation.  The obligations under this Agreement shall be unfunded.  Benefits payable under this Agreement shall be paid from the general assets of the Company.  The Company shall have no obligation to establish any fund or to set aside any assets to provide benefits under this Agreement.

(i)

Termination upon Sale of Assets of Subsidiary.  Notwithstanding anything contained herein, this Agreement shall automatically terminate and be of no further force and effect and no benefits shall be payable hereunder in the event that (i) the Executive is employed by a direct or indirect subsidiary of Sempra Energy, and (ii) an Asset Sale (as defined in Section 16(e)) occurs (other than such a sale or disposition which is part of a transaction or series of transactions which would result in a Change in Control), and (iii) as a result of such Asset Sale, the Executive is offered employment by the Asset Purchaser in an executive position with reasonably comparable status, compensation, benefits and severance agreement (including the assumption of this Agreement in accordance with Section 16(e)) and which is consistent with the Executive’s experience and education, but the Executive declines to accept such offer and the Executive fails to become employed by the Asset Purchaser on the date of the Asset Sale.  

(j)

Term.  The term of this Agreement shall commence on the Effective Date and shall continue until the third (3rd) anniversary of the Effective Date; provided, however, that commencing on the second (2nd) anniversary of the Effective Date (and each anniversary of the Effective Date thereafter), the term of this Agreement shall automatically be extended for one (1) additional year, unless at least ninety (90) days prior to such date, the Company or the Executive shall give written notice to the other party that it or he, as the case may be, does not wish to so extend this Agreement.  Notwithstanding the foregoing, if the Company gives such written notice to the Executive less than two (2) years after a Change in Control, the term of this Agreement shall be automatically extended until the later of (A) the date that is one (1) year after the anniversary of the Effective Date that follows such written notice or (B) the second (2nd) anniversary of the Change in Control Date.

(k)

Counterparts.  This Agreement may be executed in several counterparts, each of which shall be deemed to be an original but all of which together shall constitute one and the same instrument.


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 OC\1202083.4


IN WITNESS WHEREOF, the Executive and, pursuant to due authorization from its Board of Directors, the Company have caused this Agreement to be executed as of the day and year first above written.

SEMPRA ENERGY


G. Joyce Rowland

Senior Vice President - Human Resources,
Diversity & Inclusion


_____________________________________

Date


EXECUTIVE




Jessie J. Knight, Jr.

Chief Executive Officer, San Diego Gas and Electric Company


_____________________________________

Date




 OC\1202083.4




EXHIBIT A


GENERAL RELEASE

This GENERAL RELEASE (the “Agreement”), dated ___________, is made by and between ______________________________, a California corporation (the “Company”) and  ___________________________ (“you” or “your”).

WHEREAS, you and the Company have previously entered into that certain Severance Pay Agreement dated ____________, 20___ (the “Severance Pay Agreement”); and

WHEREAS, Section 14(d) of the Severance Pay Agreement provides for the payment of a benefit to you by the Company in consideration for certain covenants, including your execution and non-revocation of a general release of claims by you against the Company and its subsidiaries and affiliates.

NOW, THEREFORE, in consideration of the premises and the mutual covenants herein contained, you and the Company hereby agree as follows:

ONE:  Your signing of this Agreement confirms that your employment with the Company shall terminate at the close of business on ____________, or earlier upon our mutual agreement.

TWO:  As a material inducement for the payment of the benefit under Section 14(d) of the Severance Pay Agreement, and except as otherwise provided in this Agreement, you and the Company hereby irrevocably and unconditionally release, acquit and forever discharge the other from any and all Claims either may have against the other.  For purposes of this Agreement and the preceding sentence, the words “Releasee” or “Releasees” and “Claim” or “Claims” shall have the meanings set forth below:

(a)

The words “Releasee” or “Releasees” shall refer to you and to the Company and each of the Company’s owners, stockholders, predecessors, successors, assigns, agents, directors, officers, employees, representatives, attorneys, advisors, parent companies, divisions, subsidiaries, affiliates (and agents, directors, officers, employees, representatives, attorneys and advisors of such parent companies, divisions, subsidiaries and affiliates) and all persons acting by, through, under or in concert with any of them.

(b)

The words “Claim” or “Claims” shall refer to any charges, complaints, claims, liabilities, obligations, promises, agreements, controversies, damages, actions, causes of action, suits, rights, demands, costs, losses, debts and expenses (including attorneys’ fees and costs actually incurred) of any nature whatsoever, known or unknown, suspected or unsuspected, which you or the Company now, in the past or, except as limited by law or regulation such as the Age Discrimination in Employment Act (ADEA), in the future may have, own or hold against any of the Releasees; provided, however, that the word “Claim” or “Claims” shall not refer to any charges, complaints, claims, liabilities, obligations, promises, agreements, controversies, damages, actions, causes of action, suits, rights, demands, costs, losses, debts and expenses (including attorneys’ fees and costs actually incurred) arising under [identify severance, employee benefits, stock option, indemnification and D&O  and other agreements containing duties, rights obligations etc. of either party that are to remain operative].  Claims released pursuant to this Agreement by you and the Company include, but are not limited to, rights arising out of alleged violations of any contracts, express or implied, any tort, any claim that you failed to perform or negligently performed or breached your duties during employment at the Company, any legal restrictions on the Company’s right to terminate employees or any federal, state or other governmental statute, regulation, or ordinance, including, without limitation:  (1) Title VII of the Civil Rights Act of 1964 (race, color, religion, sex and national origin discrimination); (2) 42 U.S.C. § 1981 (discrimination); (3) 29 U.S.C. §§ 621–634 (age discrimination); (4) 29 U.S.C. § 206(d)(l) (equal pay); (5) 42 U.S.C. §§ 12101, et seq. (disability); (6) the California Constitution, Article I, Section 8 (discrimination); (7) the California Fair Employment and Housing Act (discrimination, including race, color, national origin, ancestry, physical handicap, medical condition, marital status, religion, sex or age); (8) California Labor Code Section 1102.1 (sexual orientation discrimination); (9) the Executive Order 11246 (race, color, religion, sex and national origin discrimination); (10) the Executive Order 11141 (age discrimination); (11) §§ 503 and 504 of the Rehabilitation Act of 1973 (handicap discrimination); (12) The Worker Adjustment and Retraining Act (WARN Act); (13) the California Labor Code (wages, hours, working conditions, benefits and other matters); (14) the Fair Labor Standards Act (wages, hours, working conditions and other matters); the Federal Employee Polygraph Protection Act (prohibits employer from requiring employee to take polygraph test as condition of employment); and (15) any federal, state or other governmental statute, regulation or ordinance which is similar to any of the statutes described in clauses (1) through (14).

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

“A GENERAL RELEASE DOES NOT EXTEND TO CLAIMS WHICH THE CREDITOR DOES NOT KNOW OR SUSPECT TO EXIST IN HIS FAVOR AT THE TIME OF EXECUTING THE RELEASE, WHICH IF KNOWN BY HIM MUST HAVE MATERIALLY AFFECTED HIS SETTLEMENT WITH THE DEBTOR.”

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

FOUR:  The parties acknowledge that they might hereafter discover facts different from, or in addition to, those they now know or believe to be true with respect to a Claim or Claims released herein, and they expressly agree to assume the risk of possible discovery of additional or different facts, and agree that this Agreement shall be and remain effective, in all respects, regardless of such additional or different discovered facts.

FIVE:  You hereby represent and acknowledge that you have not filed any Claim of any kind against the Company or others released in this Agreement.  You further hereby expressly agree never to initiate against the Company or others released in this Agreement any administrative proceeding, lawsuit or any other legal or equitable proceeding of any kind asserting any Claims that are released in this Agreement.

The Company hereby represents and acknowledges that it has not filed any Claim of any kind against you or others released in this Agreement.  The Company further hereby expressly agrees never to initiate against you or others released in this Agreement any administrative proceeding, lawsuit or any other legal or equitable proceeding of any kind asserting any Claims that are released in this Agreement.

SIX:  You hereby represent and agree that you have not assigned or transferred, or attempted to have assigned or transfer, to any person or entity, any of the Claims that you are releasing in this Agreement.

The Company hereby represents and agrees that it has not assigned or transferred, or attempted to have assigned or transfer, to any person or entity, any of the Claims that it is releasing in this Agreement.

SEVEN:  As a further material inducement to the Company to enter into this Agreement, you hereby agree to indemnify and hold each of the Releasees harmless from all loss, costs, damages, or expenses, including without limitation, attorneys’ fees incurred by the Releasees, arising out of any breach of this Agreement by you or the fact that any representation made in this Agreement by you was false when made.

As a further material inducement to you to enter into this Agreement, the Company hereby agrees to indemnify and hold each of the Releasees harmless from all loss, costs, damages, or expenses, including without limitation, attorneys’ fees incurred by the Releasees, arising out of any breach of this Agreement by it or the fact that any representation made in this Agreement by it was knowingly false when made.

EIGHT:  You and the Company represent and acknowledge that in executing this Agreement, neither is relying upon any representation or statement not set forth in this Agreement or the Severance Agreement.

NINE:

(a)

This Agreement shall not in any way be construed as an admission by the Company that it has acted wrongfully with respect to you or any other person, or that you have any rights whatsoever against the Company, and the Company specifically disclaims any liability to or wrongful acts against you or any other person, on the part of itself, its employees or its agents.  This Agreement shall not in any way be construed as an admission by you that you have acted wrongfully with respect to the Company, or that you failed to perform your duties or negligently performed or breached your duties, or that the Company had good cause to terminate your employment.

(b)

If you are a party or are threatened to be made a party to any proceeding by reason of the fact that you were an officer or director of the Company, the Company shall indemnify you against any expenses (including reasonable attorneys’ fees; provided, that counsel has been approved by the Company prior to retention, which approval shall not be unreasonably withheld), judgments, fines, settlements and other amounts actually or reasonably incurred by you in connection with that proceeding; provided, that you acted in good faith and in a manner you reasonably believed to be in the best interest of the Company.  The limitations of California Corporations Code Section 317 shall apply to this assurance of indemnification.

(c)

You agree to cooperate with the Company and its designated attorneys, representatives and agents in connection with any actual or threatened judicial, administrative or other legal or equitable proceeding in which the Company is or may become involved.  Upon reasonable notice, you agree to meet with and provide to the Company or its designated attorneys, representatives or agents all information and knowledge you have relating to the subject matter of any such proceeding.  The Company agrees to reimburse you for any reasonable costs you incur in providing such cooperation.

TEN:  This Agreement is made and entered into in California.  This Agreement shall in all respects be interpreted, enforced and governed by and under the laws of the State of California and applicable Federal law.  Any dispute about the validity, interpretation, effect or alleged violation of this Agreement (an “arbitrable dispute”) must be submitted to arbitration in San Diego, California.  Arbitration shall take place before an experienced employment arbitrator licensed to practice law in such state and selected in accordance with the then existing JAMS arbitration rules applicable to employment disputes; provided, however, that in any event, the arbitrator shall allow reasonable discovery.  Arbitration shall be the exclusive remedy for any arbitrable dispute.  The arbitrator in any arbitrable dispute shall not have authority to modify or change the Agreement in any respect.  You and the Company shall each be responsible for payment of one-half (1/2) the amount of the arbitrator’s fee(s); provided, however, that in no event shall you be required to pay any fee or cost of arbitration that is unique to arbitration or exceeds the costs you would have incurred had any arbitrable dispute been pursued in a court of competent jurisdiction.  The Company shall make up any shortfall.  Should any party to this Agreement institute any legal action or administrative proceeding against the other with respect to any Claim waived by this Agreement or pursue any arbitrable dispute by any method other than arbitration, the prevailing party shall be entitled to recover from the non-prevailing party all damages, costs, expenses and attorneys’ fees incurred as a result of that action.  The arbitrator’s decision and/or award shall be rendered in writing and will be fully enforceable and subject to an entry of judgment by the Superior Court of the State of California for the County of San Diego, or any other court of competent jurisdiction.

ELEVEN:  Both you and the Company understand that this Agreement is final and binding eight (8) days after its execution and return.  Should you nevertheless attempt to challenge the enforceability of this Agreement as provided in Paragraph TEN or, in violation of that Paragraph, through litigation, as a further limitation on any right to make such a challenge, you shall initially tender to the Company, by certified check delivered to the Company, all monies received pursuant to Section 14(d) of the Severance Pay Agreement, plus interest, and invite the Company to retain such monies and agree with you to cancel this Agreement and void the Company’s obligations under Section 14(d) of the Severance Pay Agreement.  In the event the Company accepts this offer, the Company shall retain such monies and this Agreement shall be canceled and the Company shall have no obligation under Section 14(d) of the Severance Pay Agreement.  In the event the Company does not accept such offer, the Company shall so notify you and shall place such monies in an interest-bearing escrow account pending resolution of the dispute between you and the Company as to whether or not this Agreement and the Company’s obligations under Section 14(d) of the Severance Pay Agreement shall be set aside and/or otherwise rendered voidable or unenforceable.  Additionally, any consulting agreement then in effect between you and the Company shall be immediately rescinded with no requirement of notice.

TWELVE:  Any notices required to be given under this Agreement shall be delivered either personally or by first class United States mail, postage prepaid, addressed to the respective parties as follows:

To Company:

[TO COME]

Attn:  [TO COME]

To You:

______________________

______________________

______________________

THIRTEEN:  You understand and acknowledge that you have been given a period of forty-five (45) days to review and consider this Agreement (as well as statistical data on the persons eligible for similar benefits) before signing it and may use as much of this forty-five (45) day period as you wish prior to signing.  You are encouraged, at your personal expense, to consult with an attorney before signing this Agreement.  You understand and acknowledge that whether or not you do so is your decision.  You may revoke this Agreement within seven (7) days of signing it.  If you wish to revoke, the Company’s Vice President, Human Resources must receive written notice from you no later than the close of business on the seventh (7th) day after you have signed the Agreement.  If revoked, this Agreement shall not be effective and enforceable, and you will not receive payments or benefits under Section 14(d) of the Severance Pay Agreement.

FOURTEEN:  This Agreement constitutes the entire agreement of the parties hereto and supersedes any and all other agreements (except the Severance Pay Agreement) with respect to the subject matter of this Agreement, whether written or oral, between you and the Company.  All modifications and amendments to this Agreement must be in writing and signed by the parties.

FIFTEEN:  Each party agrees, without further consideration, to sign or cause to be signed, and to deliver to the other party, any other documents and to take any other action as may be necessary to fulfill the obligations under this Agreement.

SIXTEEN:  If any provision of this Agreement or the application thereof is held invalid, the invalidity shall not affect other provisions or applications of the Agreement which can be given effect without the invalid provisions or application; and to this end the provisions of this Agreement are declared to be severable.

SEVENTEEN:  This Agreement may be executed in counterparts.

I have read the foregoing General Release, and I accept and agree to the provisions it contains and hereby execute it voluntarily and with full understanding of its consequences.  I am aware it includes a release of all known or unknown claims.

DATED:  __________

__________________________________________

DATED:  __________

__________________________________________

You acknowledge that you first received this Agreement on [date].

_________________________





 OC\1202083.4


Exhibit 10.25


Exhibit 10.25


SEMPRA ENERGY
SEVERANCE PAY AGREEMENT

THIS AGREEMENT (this “Agreement”), dated as of December 31, 2011 (the “Effective Date”), is made by and between SEMPRA ENERGY, a California corporation (“Sempra Energy”), and MICHAEL W. ALLMAN (the “Executive”).

WHEREAS, the  Executive is currently employed by Sempra Energy or a direct or indirect subsidiary of Sempra Energy (Sempra Energy and its subsidiaries are hereinafter collectively referred to as the “Company”) as President & CEO – Southern California Gas Company; and

WHEREAS, Sempra Energy and the Executive desire to enter into this Agreement; and

WHEREAS, the Board of Directors of Sempra Energy (the “Board”) has authorized this Agreement.

NOW, THEREFORE, in consideration of the premises and mutual covenants herein contained, the Company and the  Executive hereby agree as follows:

Section 1.

Definitions.  For purposes of this Agreement, the following capitalized terms have the meanings set forth below:

Accounting Firm” has the meaning assigned thereto in Section 9(b) hereof.

Act” has the meaning assigned thereto in Section 2 hereof.

Additional Post-Change in Control Severance Payment” has the meaning assigned thereto in Section 6(a) hereof.

Affiliate” has the meaning set forth in Rule 12b-2 promulgated under the Exchange Act.

Annual Base Salary” means the  Executive’s annual base salary from the Company.

Asset Purchaser” has the meaning assigned thereto in Section 16(e).

Asset Sale” has the meaning assigned thereto in Section 16(e).

Average Annual Bonus” means the average of the annual bonuses from the Company earned by the Executive with respect to the three (3) fiscal years of the Company immediately preceding the Date of Termination (the “Bonus Fiscal Years”); provided, however, that, if the Executive was employed by the Company during all or any portion of one or two of the Bonus Fiscal Years (but not three of the Bonus Fiscal Years), “Average Annual Bonus” means the average of the annual bonuses (if any) from the Company earned by the Executive with respect to the Bonus Fiscal Years during all or any portion of which the Executive was employed by the Company; and, provided, further, that, if the Executive was not employed by the Company during all or any portion of any of the Bonus Fiscal Years, “Average Annual Bonus” means zero.

Beneficial Owner” has the meaning set forth in Rule 13d-3 promulgated under the Exchange Act.

Cause” means:  

(a)

Prior to a Change in Control, (i) the willful failure by the  Executive to substantially perform the  Executive’s duties with the Company (other than any such failure resulting from the  Executive’s incapacity due to physical or mental illness, (ii) the grossly negligent performance of such obligations referenced in clause (i) of this definition, (iii) the  Executive’s gross insubordination; and/or (iv) the  Executive’s commission of one or more acts of moral turpitude that constitute a violation of applicable law (including but not limited to a felony) which have or result in an adverse effect on the Company, monetarily or otherwise, or one or more significant acts of dishonesty.  For purposes of clause (i) of this subsection (a), no act, or failure to act, on the  Executive’s part shall be deemed “willful” unless done, or omitted to be done, by the  Executive not in good faith and without reasonable belief that the  Executive’s act, or failure to act, was in the best interests of the Company.  

(b)

From and after a Change in Control, (i) the willful and continued failure by the  Executive to substantially perform the  Executive’s duties with the Company (other than any such failure resulting from the  Executive’s incapacity due to physical or mental illness or any such actual or anticipated failure after the issuance of a Notice of Termination for Good Reason by the  Executive pursuant to Section 3 hereof) and/or (ii) the  Executive’s commission of one or more acts of moral turpitude that constitute a violation of applicable law (including but not limited to a felony) which have or result in an adverse effect on the Company, monetarily or otherwise, or one or more significant acts of dishonesty.  For purposes of clause (i) of this subsection (b), no act, or failure to act, on the  Executive’s part shall be deemed “willful” unless done, or omitted to be done, by the  Executive not in good faith and without reasonable belief that the  Executive’s act, or failure to act, was in the best interests of the Company.  Notwithstanding the foregoing, the  Executive shall not be deemed terminated for Cause pursuant to clause (i) of this subsection (b) unless and until the  Executive shall have been provided with reasonable notice of and, if possible, a reasonable opportunity to cure the facts and circumstances claimed to provide a basis for termination of the  Executive’s employment for Cause.

Change in Control” shall be deemed to have occurred on the date that a change in the ownership of Sempra Energy, a change in the effective control of Sempra Energy, or a change in the ownership of a substantial portion of assets of Sempra Energy occurs (each, as defined in subsection (a) below), except as otherwise provided in subsections (b), (c) and (d) below:

(a)

(i)

a “change in the ownership of Sempra Energy” occurs on the date that any one person, or more than one person acting as a group, acquires ownership of stock of Sempra Energy that, together with stock held by such person or group, constitutes more than fifty percent (50%) of the total fair market value or total voting power of the stock of Sempra Energy,

(ii)

a “change in the effective control of Sempra Energy” occurs only on either of the following dates:

(A)

the date any one person, or more than one person acting as a group, acquires (or has acquired during the twelve (12) month period ending on the date of the most recent acquisition by such person or persons) ownership of stock of Sempra Energy possessing thirty percent (30%) or more of the total voting power of the stock of Sempra Energy, or

(B)

the date a majority of the members of the Board is replaced during any twelve (12) month period by directors whose appointment or election is not endorsed by a majority of the members of the Board before the date of appointment or election, and

(iii)

a “change in the ownership of a substantial portion of assets of Sempra Energy” occurs on the date any one person, or more than one person acting as a group, acquires (or has acquired during the twelve (12) month period ending on the date of the most recent acquisition by such person or persons) assets from Sempra Energy that have a total gross fair market value equal to or more than eighty-five percent (85%) of the total gross fair market value of all of the assets of Sempra Energy immediately before such acquisition or acquisitions.

(b)

A “change in the ownership of Sempra Energy” or “a change in the effective control of Sempra Energy” shall not occur under clause (a)(i) or (a)(ii) by reason of any of the following:

(i)

an acquisition of ownership of stock of Sempra Energy directly from Sempra Energy or its Affiliates other than in connection with the acquisition by Sempra Energy or its Affiliates of a business,

(ii)

a merger or consolidation which would result in the voting securities of Sempra Energy outstanding immediately prior to such merger or consolidation continuing to represent (either by remaining outstanding or by being converted into voting securities of the surviving entity or any parent thereof), in combination with the ownership of any trustee or other fiduciary holding securities under an employee benefit plan of the Company, at least sixty percent (60%) of the combined voting power of the securities of Sempra Energy or such surviving entity or any parent thereof outstanding immediately after such merger or consolidation, or

(iii)

a merger or consolidation effected to implement a recapitalization of Sempra Energy (or similar transaction) in which no Person is or becomes the Beneficial Owner, directly or indirectly, of securities of Sempra Energy (not including the securities beneficially owned by such Person any securities acquired directly from Sempra Energy or its Affiliates other than in connection with the acquisition by Sempra Energy or its Affiliates of a business) representing twenty percent (20%) or more of the combined voting power of Sempra Energy’s then outstanding securities.

(c)

A “change in the ownership of a substantial portion of assets of Sempra Energy” shall not occur under clause (a)(iii) by reason of a sale or disposition by Sempra Energy of the assets of Sempra Energy to an entity, at least sixty percent (60%) of the combined voting power of the voting securities of which are owned by shareholders of Sempra Energy in substantially the same proportions as their ownership of Sempra Energy immediately prior to such sale.

(d)

This definition of “Change in Control” shall be limited to the definition of a “change in control event” relating to Sempra Energy under Treasury Regulation Section 1.409A-3(i)(5).  A “Change in Control” shall only occur if there is a “change in control event” relating to Sempra Energy under Treasury Regulation Section 1.409A-3(i)(5) with respect to the Executive.

Change in Control Date” means the date on which a Change in Control occurs.

Code” means the Internal Revenue Code of 1986, as amended.

Compensation Committee” means the compensation committee of the Board.

Consulting Period” has the meaning assigned thereto in Section 14(e) hereof.

Date of Termination” has the meaning assigned thereto in Section 3(b) hereof.

Deferred Compensation Plan” has the meaning assigned thereto in Section 5(f) hereof.

Disability” has the meaning set forth in the Company’s long-term disability plan or its successor; provided, however, that the Board may not terminate the  Executive’s employment hereunder by reason of Disability unless (i) at the time of such termination there is no reasonable expectation that the  Executive will return to work within the next ninety (90) day period and (ii) such termination is permitted by all applicable disability laws.  

Exchange Act” means the Securities Exchange Act of 1934, as amended, and the applicable rulings and regulations thereunder.

Excise Tax” has the meaning assigned thereto in Section 9(a) hereof.

Good Reason” means:

(a)

Prior to a Change in Control, the occurrence of any of the following without the prior written consent of the  Executive, unless such act or failure to act is corrected by the Company prior to the Date of Termination specified in the Notice of Termination (as required under Section 3 hereof):

(i)

the assignment to the  Executive of any duties materially inconsistent with the range of duties and responsibilities appropriate to a senior Executive within the Company (such range determined by reference to past, current and reasonable practices within the Company);

(ii)

a material reduction in the  Executive’s overall standing and responsibilities within the Company, but not including (A) a mere change in title or (B) a transfer within the Company, which, in the case of both (A) and (B), does not adversely affect the  Executive’s overall status within the Company;

(iii)

a material reduction by the Company in the  Executive’s aggregate annualized compensation and benefits opportunities, except for across-the-board reductions (or modifications of benefit plans) similarly affecting all similarly situated executives (both of the Company and of any Person then in control of the Company) of comparable rank with the  Executive;

(iv)

the failure by the Company to pay to the  Executive any portion of the  Executive’s current compensation and benefits or any portion of an installment of deferred compensation under any deferred compensation program of the Company within thirty (30) days of the date such compensation is due;

(v)

any purported termination of the  Executive’s employment that is not effected pursuant to a Notice of Termination satisfying the requirements of Section 3 hereof; for purposes of this Agreement, no such purported termination shall be effective;

(vi)

the failure by Sempra Energy to perform its obligations under Section 16(c), (d) or (e) hereof;

(vii)

the failure by the Company to provide the indemnification and D&O insurance protection Section 11 of this Agreement requires it to provide; or

(viii)

the failure by Sempra Energy to comply with any material provision of this Agreement.

(b)

From and after a Change in Control, the occurrence of any of the following without the prior written consent of the  Executive, unless such act or failure to act is corrected by the Company prior to the Date of Termination specified in the Notice of Termination (as required under Section 3 hereof):

(i)

an adverse change in the  Executive’s title, authority, duties, responsibilities or reporting lines as in effect immediately prior to the Change in Control;

(ii)

a reduction by the Company in the  Executive’s aggregate annualized compensation opportunities, except for across-the-board reductions in base salaries, annual bonus opportunities or long-term incentive compensation opportunities of less than ten percent (10%) similarly affecting all similarly situated executives (both of the Company and of any Person then in control of the Company) of comparable rank with the  Executive; or the failure by the Company to continue in effect any material benefit plan in which the  Executive participates immediately prior to the Change in Control, unless an equitable arrangement (embodied in an ongoing substitute or alternative plan) has been made with respect to such plan, or the failure by the Company to continue the  Executive's participation therein (or in such substitute or alternative plan) on a basis not materially less favorable, both in terms of the amount of benefits provided and the level of the  Executive's participation relative to other participants, as existed at the time of the Change in Control;

(iii)

the relocation of the  Executive’s principal place of employment immediately prior to the Change in Control Date (the “Principal Location”) to a location which is both further away from the  Executive’s residence and more than thirty (30) miles from such Principal Location, or the Company’s requiring the  Executive to be based anywhere other than such Principal Location (or permitted relocation thereof), or a substantial increase in the  Executive’s business travel obligations outside of the Southern California area as of the Effective Date other than any such increase that (A) arises in connection with extraordinary business activities of the Company of limited duration and (B) is understood not to be part of the  Executive’s regular duties with the Company;

(iv)

the failure by the Company to pay to the  Executive any portion of the  Executive’s current compensation and benefits or any portion of an installment of deferred compensation under any deferred compensation program of the Company within thirty (30) days of the date such compensation is due;

(v)

any purported termination of the  Executive’s employment that is not effected pursuant to a Notice of Termination satisfying the requirements of Section 3 hereof; for purposes of this Agreement, no such purported termination shall be effective;

(vi)

the failure by Sempra Energy to perform its obligations under Section 16(c), (d) or (e) hereof;

(vii)

the failure by the Company to provide the indemnification and D&O insurance protection Section 11 of this Agreement requires it to provide; or

(viii)

the failure by Sempra Energy to comply with any material provision of this Agreement.

Following a Change in Control, the  Executive’s determination that an act or failure to act constitutes Good Reason shall be presumed to be valid unless such determination is deemed to be unreasonable by an arbitrator pursuant to the procedure described in Section 13 hereof.  The  Executive’s right to terminate the  Executive’s employment for Good Reason shall not be affected by the  Executive’s incapacity due to physical or mental illness.  The  Executive’s continued employment shall not constitute consent to, or a waiver of rights with respect to, any act or failure to act constituting Good Reason hereunder.

Incentive Compensation Awards” means awards granted under Incentive Compensation Plans providing the  Executive with the opportunity to earn, on a year-by-year basis, annual and long-term incentive compensation.

Incentive Compensation Plans” means annual incentive compensation plans and long-term incentive compensation plans of the Company, which long-term incentive compensation plans may include plans offering stock options, restricted stock and other long-term incentive compensation.

Involuntary Termination” means (a) the  Executive’s Separation from Service by reason of a termination of employment by the Company other than for Cause, death, or Disability, or (b) the  Executive’s Separation from Service by reason of resignation of employment with the Company for Good Reason.    

JAMS Rules” has the meaning assigned thereto in Section 13 hereof.

Notice of Termination” has the meaning assigned thereto in Section 3(a) hereof.

Payment” has the meaning assigned thereto in Section 9(a) hereof.

Payment in Lieu of Notice” has the meaning assigned thereto in Section 3(b) hereof.

Person” has the meaning set forth in section 3(a)(9) of the Exchange Act, as modified and used in sections 13(d) and 14(d) thereof, except that such term shall not include (i) the Company or any of its Affiliates, (ii) a trustee or other fiduciary holding securities under an employee benefit plan of the Company or any of its Affiliates, (iii) an underwriter temporarily holding securities pursuant to an offering of such securities, (iv) a corporation owned, directly or indirectly, by the shareholders of the Company in substantially the same proportions as their ownership of stock of the Company, or (v) a person or group as used in Rule 13d-1(b) promulgated under the Exchange Act.

Post-Change in Control Accrued Obligations” has the meaning assigned thereto in Section 6(a) hereof.

Post-Change in Control Severance Payment” has the meaning assigned thereto in Section 6 hereof.

Pre-Change in Control Accrued Obligations” has the meaning assigned thereto in Section 5(a) hereof.

Pre-Change in Control Severance Payment” has the meaning assigned thereto in Section 5 hereof.

Principal Location” has the meaning assigned thereto in clause (b)(iii) of the definition of Good Reason, above.

Proprietary Information” has the meaning assigned thereto in Section 14(a) hereof.

Release” has the meaning assigned thereto in Section 14(d) hereof.

Section 409A Payments” means any of the following:  (a) the Payment in Lieu of Notice; (b) the Pre-Change in Control Severance Payment; (c) the Post-Change in Control Severance Payment; (d) the Additional Post-Change in Control Severance Payment; (e) the Consulting Payment; (f) the payment under Section 6(b) (but only to the extent such payment or portion thereof is subject to Section 409A of the Code); (g) the financial planning services and the related payments provided under Sections 5(e) and 6(f); and (h) the legal fees and expenses reimbursed under Section 15.

Sempra Energy Control Group” means Sempra Energy and all persons with whom Sempra Energy would be considered a single employer under Section 414(b) or 414(c) of the Code, as determined from time to time.

Separation from Service”, with respect to the  Executive (or another Service Provider), means the  Executive’s (or such Service Provider’s) (a) termination of employment or (b) other termination or reduction in services, provided that such termination or reduction in clause (a) or (b) constitutes a “separation from service,” as defined in Treasury Regulation Section 1.409A-1(h), with respect to the Service Recipient.

SERP” has the meaning assigned thereto in Section 6(b) hereof.

Service Provider” means the  Executive or any other “service provider,” as defined in Treasury Regulation Section 1.409A-1(f).

Service Recipient,” with respect to the  Executive, means Sempra Energy (if the Executive is employed by Sempra Energy), or the subsidiary of Sempra Energy employing the Executive, whichever is applicable, and all persons considered part of the “service recipient,” as defined in Treasury Regulation Section 1.409A-1(g), as determined from time to time.  As provided in Treasury Regulation Section 1.409A-1(g), the “Service Recipient” shall mean the person for whom the services are performed and with respect to whom the legally binding right to compensation arises, and all persons with whom such person would be considered a single employer under Section 414(b) or 414(c) of the Code.

Specified Employee” means a Service Provider who, as of the date of the Service Provider’s Separation from Service is a “Key Employee” of the Service Recipient any stock of which is publicly traded on an established securities market or otherwise.  For purposes of this definition, a Service Provider is a “Key Employee” if the Service Provider meets the requirements of Section 416(i)(1)(A)(i), (ii) or (iii) of the Code (applied in accordance with the Treasury Regulations thereunder and disregarding Section 416(i)(5) of the Code) at any time during the Testing Year.  If a Service Provider is a “Key Employee” (as defined above) as of a Specified Employee Identification Date, the Service Provider shall be treated as “Key Employee” for the entire twelve (12) month period beginning on the Specified Employee Effective Date.  For purposes of this definition, a Service Provider’s compensation for a Testing Year shall mean such Service Provider’s compensation, as determined under Treasury Regulation Section 1.415(c)-2(a) (and applied as if the Service Recipient were not using any safe harbor provided in Treasury Regulation Section 1.415(c)-2(d), were not using any of the elective special timing rules provided in Treasury Regulation Section 1.415(c)-2(e), and were not using any of the elective special rules provided in Treasury Regulation Section 1.415(c)-2(g)), from the Service Recipient for such Testing Year.  The “Specified Employees” shall be determined in accordance with Section 409A(a)(2)(B)(i) of the Code and Treasury Regulation Section 1.409A-1(i).

Specified Employee Effective Date” means the first day of the fourth month following the Specified Employee Identification Date.  The Specified Employee Effective Date may be changed by Sempra Energy, in its discretion, in accordance with Treasury Regulation Section 1.409A-1(i)(4).

Specified Employee Identification Date”, for purposes of Treasury Regulation Section 1.409A-1(i)(3), shall mean December 31.  The “Specified Employee Identification Date” shall apply to all “nonqualified deferred compensation plans” (as defined in Treasury Regulation Section 1.409A-1(a)) of the Service Recipient and all affected Service Providers.  The “Specified Employee Identification Date” may be changed by Sempra Energy, in its discretion, in accordance with Treasury Regulation Section 1.409A-1(i)(3).

Testing Year” shall mean the twelve (12) month period ending on the Specified Employee Identification Date, as determined from time to time.

Underpayment” has the meaning assigned thereto in Section 9(b) hereof.

For purposes of this Agreement, references to any “Treasury Regulation” shall mean such Treasury Regulation as in effect on the date hereof.

Section 2.

Sarbanes-Oxley Act of 2002.  Notwithstanding anything herein to the contrary, if the Company determines, in its good faith judgment, that any provision of this Agreement is likely to be interpreted as a personal loan prohibited by the Sarbanes-Oxley Act of 2002 and the rules and regulations promulgated thereunder (the “Act”), then such provision shall be modified as necessary or appropriate so as to not violate the Act; and if this cannot be accomplished, then the Company shall use its reasonable efforts to provide the  Executive with similar, but lawful, substitute benefit(s) at a cost to the Company not to significantly exceed the amount the Company would have otherwise paid to provide such benefit(s) to the  Executive.  In addition, if the  Executive is required to forfeit or to make any repayment of any compensation or benefit(s) to the Company under the Act or any other law, such forfeiture or repayment shall not constitute Good Reason.

Section 3.

Notice and Date of Termination.  

(a)

Any termination of the  Executive’s employment by the Company or by the  Executive shall be communicated by a written notice of termination to the other party (the “Notice of Termination”).  Where applicable, the Notice of Termination shall indicate the specific termination provision in this Agreement relied upon and shall set forth in reasonable detail the facts and circumstances claimed to provide a basis for termination of the  Executive’s employment under the provision so indicated.  Unless the Board determines otherwise, a Notice of Termination by the  Executive alleging a termination for Good Reason must be made within 180 days of the act or failure to act that the  Executive alleges to constitute Good Reason.  

(b)

The date of the  Executive’s termination of employment with the Company (the “Date of Termination”) shall be determined as follows:  (i) if the  Executive has a Separation from Service by reason of the Company terminating his or her employment, either with or without Cause, the Date of Termination shall be the date specified in the Notice of Termination (which, in the case of a termination by the Company other than for Cause, shall not be less than two (2) weeks from the date such Notice of Termination is given unless the Company elects to pay the  Executive, in addition to any other amounts payable hereunder, an amount (the “Payment in Lieu of Notice”) equal to two (2) weeks of the  Executive’s Annual Base Salary in effect on the Date of Termination), and (ii) if the basis for the  Executive’s Involuntary Termination is his resignation for Good Reason, the Date of Termination shall be determined by the  Executive and specified in the Notice of Termination, but shall not in any event be less than fifteen (15) days nor more than sixty (60) days after the date such Notice of Termination is given.   The Payment in Lieu of Notice shall be paid on such date as is determined by the Company within thirty (30) days after the date of the Executive’s Separation from Service; provided, however, that if the Executive is a Specified Employee on the date of his or her Separation from Service, such Payment in Lieu of Notice shall be paid as provided in Section 10 hereof.

Section 4.

Termination from the Board.  Upon the termination of the  Executive’s employment for any reason, the  Executive’s membership on the Board, the board of directors of any of the Company’s Affiliates, any committees of the Board and any committees of the board of directors of any of the Company’s Affiliates, if applicable, shall be automatically terminated.

Section 5.

Severance Benefits upon Involuntary Termination Prior to Change in Control.  Except as provided in Section 6 and Section 19(i) hereof, in the event of the Involuntary Termination of the  Executive prior to a Change in Control, the Company shall pay the  Executive, in one lump sum cash payment, an amount (the “Pre-Change in Control Severance Payment”) equal to one-half (0.5) times the greater of:  (X) 170% of the Executive’s Annual Base Salary as in effect on the Date of Termination, and (Y) the Executive’s Annual Base Salary as in effect on the Date of Termination, plus the Executive’s Average Annual Bonus.  In addition to the Pre-Change in Control Severance Payment, the  Executive shall be entitled to the following additional benefits specified in subsections (a) through (e).  Except as provided in Section 5(f), the Pre-Change in Control Severance Payment and the payment under Section 5(a) shall be paid on such date as is determined by the Company within thirty (30) days after the date of the Involuntary Termination; provided, however, that, if the  Executive is a Specified Employee on the date of the  Executive’s Involuntary Termination, the Pre-Change in Control Severance Payment and the financial planning services and the related payments provided under Section 5(e) shall be paid as provided in Section 10 hereof.  

(a)

Accrued Obligations.  The Company shall pay the  Executive a lump sum amount in cash equal to the sum of (A) the  Executive’s Annual Base Salary through the Date of Termination to the extent not theretofore paid, (B) an amount equal to any annual Incentive Compensation Awards earned with respect to fiscal years ended prior to the year that includes the Date of Termination to the extent not theretofore paid, (C) any accrued and unpaid vacation, if any, and (D) reimbursement for unreimbursed business expenses, if any, properly incurred by the  Executive in the performance of his duties in accordance with policies established from time to time by the Board, in each case to the extent not theretofore paid.  (The amounts specified in clauses (A), (B), (C) and (D) shall be hereinafter referred to as the “Pre-Change in Control Accrued Obligations”).

(b)

Equity Based Compensation.  The  Executive shall retain all rights to any equity-based compensation awards to the extent set forth in the applicable plan and/or award agreement.

(c)

Welfare Benefits.  Subject to Section 12 below, for a period of six (6) months following the date of the Involuntary Termination (and an additional twelve (12) months if the  Executive provides consulting services under Section 14(e) hereof), the  Executive and his dependents shall be provided with health insurance benefits substantially similar to those provided to the  Executive and his dependents immediately prior to the date of the Involuntary Termination; provided, however, that such benefits shall be provided on substantially the same terms and conditions and at the same cost to the  Executive as in effect immediately prior to the date of the Involuntary Termination.  Such benefits shall be provided through insurance maintained by the Company under the Company’s benefit plans.  Such benefits shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(a)(5).

(d)

Outplacement Services.  The  Executive shall receive reasonable outplacement services, on an in-kind basis, suitable to his position and directly related to the  Executive’s Involuntary Termination, for a period of eighteen (18) months following the date of the Involuntary Termination, in an aggregate amount of cost to the Company not to exceed $50,000.  Notwithstanding the foregoing, the  Executive shall cease to receive outplacement services on the date the  Executive accepts employment with a subsequent employer.  Such outplacement services shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(b)(9)(v)(A).

(e)

Financial Planning Services.  The  Executive shall receive financial planning services, on an in-kind basis, for a period of eighteen (18) months following the Date of Termination.  Such financial planning services shall include expert financial and legal resources to assist the Executive with financial planning needs and shall be limited to (i) current investment portfolio management, (ii) tax planning, (iii) tax return preparation, and (iv) estate planning advice and document preparation (including wills and trusts); provided, however, that the Company shall provide such financial planning services during any taxable year of the Executive only to the extent the cost to the Company for such taxable year does not exceed $25,000.  The Company shall provide such financial planning services through a financial planner selected by the Company, and shall pay the fees for such financial planning services.  The financial planning services provided during any taxable year of the  Executive shall not affect the financial planning services provided in any other taxable year of the  Executive.  The  Executive’s right to financial planning services shall not be subject to liquidation or exchange for any other benefit.  Such financial planning services shall be provided in a manner that complies with Treasury Regulation Section 1.409A-3(i)(1)(iv).  

(f)

Deferral of Payments.  The  Executive shall have the right to elect to defer the Pre-Change in Control Severance Payment to be received by the  Executive pursuant to this Section 5 under the terms and conditions of the Sempra Energy Employee and Director Savings Plan (the “Deferred Compensation Plan”).  Any such deferral election shall be made in accordance with Section 18(b) hereof.

Section 6.

Severance Benefits upon Involuntary Termination in Connection with and after Change in Control.  Notwithstanding the provisions of Section 5 above, and except as provided in Section 19(i) hereof, in the event of the Involuntary Termination of the  Executive on or within two (2) years following a Change in Control, in lieu of the payments described in Section 5 above, the Company shall pay the  Executive, in one lump sum cash payment, an amount (the “Post-Change in Control Severance Payment”) equal to the greater of:  (X)  170% of the Executive’s Annual Base Salary as in effect immediately prior to the Change in Control or the Date of Termination, whichever is greater, and (Y) the Executive’s Annual Base Salary as in effect immediately prior to the Change in Control or on the Date of Termination, whichever is greater, plus the Executive’s Average Annual Bonus.  In addition to the Post-Change in Control Severance Payment, the  Executive shall be entitled to the following additional benefits specified in subsections (a) through (f).  Except as provided in Sections 6(g) and 6(h), the Post-Change in Control Severance Payment and the payments under Sections 6(a) and (b) shall be paid on such date as is determined by the Company within thirty (30) days after the date of the Involuntary Termination; provided, however, that, if the  Executive is a Specified Employee on the date of the  Executive’s Involuntary Termination, the Post-Change in Control Severance Payment, the Additional Post-Change in Control Severance Payment under Section 6(a)(E), the payment under Section 6(b) (but only to the extent such payment or portion thereof is subject to Section 409A of the Code), and the financial planning services and the related payments provided under Section 6(f) shall be paid as provided in Section 10 hereof.

(a)

Accrued Obligations.  The Company shall pay the  Executive a lump sum amount in cash equal to the sum of (A) the  Executive’s Annual Base Salary through the Date of Termination to the extent not theretofore paid, (B) an amount equal to any annual Incentive Compensation Awards earned with respect to fiscal years ended prior to the year that includes the Date of Termination to the extent not theretofore paid, (C) any accrued and unpaid vacation, if any, (D) reimbursement for unreimbursed business expenses, if any, properly incurred by the  Executive in the performance of his duties in accordance with policies established from time to time by the Board, and (E) an amount (the “Additional Post-Change in Control Severance Payment”) equal to:  (i) the greater of:  (X) 70% of the Executive’s Annual Base Salary as in effect immediately prior to the Change in Control or on the Date of Termination, whichever is greater, or (Y) the Executive’s Average Annual Bonus, multiplied by (ii) a fraction, the numerator of which shall be the number of days from the beginning of such fiscal year to and including the Date of Termination and the denominator of which shall be 365, in the case of each amount described in clause (A), (B), (C) or (D) to the extent not theretofore paid.  (The amounts specified in clauses (A), (B), (C), (D) and (E) shall be hereinafter referred to as the “Post-Change in Control Accrued Obligations”).

(b)

Pension Supplement.  The  Executive shall be entitled to receive a Supplemental Retirement Benefit under the Sempra Energy Supplemental Executive Retirement Plan, as in effect from time to time (“SERP”), determined in accordance with this Section 6(b), in the event that the Executive is a “Participant” (as defined in the SERP) as of the Date of Termination.  Such Supplemental Retirement Benefit shall be determined by crediting the Executive with additional months of Service (if any) equal to the number of full calendar months



Tier 2A Agreement

 OC\1056247.3


from the Date of Termination to the date on which the Executive would have attained age 62.  The Executive shall be entitled to receive such Supplemental Retirement Benefit without regard to whether the Executive has attained age 55 or completed five years of “Service” (as defined in the SERP) as of the Date of Termination.  The Executive shall be treated as qualified for “Retirement” (as defined in the SERP) as of the Date of Termination, and the Executive’s Vesting Factor with respect to the Supplemental Retirement Benefit shall be 100%.  The Executive’s Supplemental Retirement Benefit shall be calculated based on the Executive’s actual age as of the date of commencement of payment of such Supplemental Retirement Benefit (the “SERP Distribution Date”), and by applying the applicable early retirement factors under the SERP, if the Executive has not attained age 62 but has attained age 55 as of the SERP Distribution Date.  If the Executive has not attained age 55 as of the SERP Distribution Date, the Executive’s Supplemental Retirement Benefit shall be calculated by applying the applicable early retirement factor under the SERP for age 55, and the Supplemental Retirement Benefit otherwise payable at age 55 shall be actuarially adjusted to the Executive’s actual age as of the SERP Distribution Date using the following actuarial assumptions:  (i) the applicable mortality table promulgated by the Internal Revenue Service under Section 417(e)(3) of the Code, as in effect on the first day of the calendar year in which the SERP Distribution Date occurs, and (ii) the applicable interest rate promulgated by the Internal Revenue Service under Section 417(a)(3) of the Code for the November next preceding the first day of the calendar year in which the SERP Distribution Date occurs.  The Executive’s Supplemental Retirement Benefit shall be determined in accordance with this Section 6(b), notwithstanding any contrary provisions of the SERP and, to the extent subject to Section 409A of the Code, shall be paid in accordance with Treasury Regulation Section 1.409A-3(c)(1).  The Supplemental Retirement Benefit paid to or on behalf of the Executive in accordance with this Section 6(b) shall be in full satisfaction of any and all of the benefits payable to or on behalf of the Executive under the SERP.  

(c)

Equity-Based Compensation.  Notwithstanding the provisions of any applicable equity-compensation plan or award agreement to the contrary, all equity-based Incentive Compensation Awards (including, without limitation, stock options, stock appreciation rights, restricted stock awards, restricted stock units, performance share awards, awards covered under Section 162(m) of the Code, and dividend equivalents) held by the  Executive shall immediately vest and become exercisable or payable, as the case may be, as of the Date of Termination, to be exercised or paid, as the case may be, in accordance with the terms of the applicable Incentive Compensation Plan and Incentive Compensation Award agreement, and any restrictions on any such Incentive Compensation Awards shall automatically lapse; provided, however, that any such stock option or stock appreciation rights awards granted on or after June 26, 1998 shall remain outstanding and exercisable until the earlier of (A) the later of eighteen (18) months following the Date of Termination or the period specified in the applicable Incentive Compensation Award agreements or (B) the expiration of the original term of such Incentive Compensation Award (or, if earlier, the tenth anniversary of the original date of grant) (it being understood that all Incentive Compensation Awards granted prior to or after June 26, 1998 shall remain outstanding and exercisable for a period that is no less than that provided for in the applicable agreement in effect as of the date of grant).

(d)

Welfare Benefits.  Subject to Section 12 below, for a period of twelve (12) months following the date of Involuntary Termination (and an additional twelve (12) months if the  Executive provides consulting services under Section 14(e) hereof), the  Executive and his dependents shall be provided with life, disability, accident and health insurance benefits substantially similar to those provided to the  Executive and his dependents immediately prior to the date of Involuntary Termination or the Change in Control Date, whichever is more favorable to the  Executive; provided, however, that such benefits shall be provided on substantially the same terms and conditions and at the same cost to the  Executive as in effect immediately prior to the date of Involuntary Termination or the Change in Control Date, whichever is more favorable to the  Executive.  Such benefits shall be provided through insurance maintained by the Company under the Company benefit plans.  Such benefits shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(a)(5).

(e)

Outplacement Services.  The  Executive shall receive reasonable outplacement services, on an in-kind basis, suitable to his position and directly related to the  Executive’s Involuntary Termination, for a period of twenty-four (24) months following the date of Involuntary Termination (but in no event beyond the last day of the  Executive’s second taxable year following the  Executive’s taxable year in which the Involuntary Termination occurs), in the aggregate amount of cost to the Company not to exceed $50,000.  Notwithstanding the foregoing, the  Executive shall cease to receive outplacement services on the date the  Executive accepts employment with a subsequent employer.  Such outplacement services shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(b)(9)(v)(A).

(f)

Financial Planning Services.  The  Executive shall receive financial planning services, on an in-kind basis, for a period of twenty-four (24) months following the date of Involuntary Termination.  Such financial planning services shall include expert financial and legal resources to assist the Executive with financial planning needs and shall be limited to (i) current investment portfolio management, (ii) tax planning, (iii) tax return preparation, and (iv) estate planning advice and document preparation (including wills and trusts); provided, however, that the Company shall provide such financial services during any taxable year of the Executive only to the extent the cost to the Company for such taxable year does not exceed $25,000.  The Company shall provide such financial planning services through a financial planner selected by the Company, and shall pay the fees for such financial planning services.  The financial planning services provided during any taxable year of the  Executive shall not affect the financial planning services provided in any other taxable year of the  Executive.  The  Executive’s right to financial planning services shall not be subject to liquidation or exchange for any other benefit.  Such financial planning services shall be provided in a manner that complies with Section 1.409A-3(i)(1)(iv).  

(g)

Involuntary Termination in Connection with a Change in Control.  Notwithstanding anything contained herein, in the event of an Involuntary Termination prior to a Change in Control, if the Involuntary Termination (1) was at the request of a third party who has taken steps reasonably calculated to effect such Change in Control or (2) otherwise arose in connection with or in anticipation of such Change in Control, then the  Executive shall, in lieu of the payments described in Section 5 hereof, be entitled to the Post-Change in Control Severance Payment and the additional benefits described in this Section 6 as if such Involuntary Termination had occurred within two (2) years following the Change in Control.  The amounts specified in Section 6 that are to be paid under this Section 6(g) shall be reduced by any amount previously paid under Section 5.  The amounts to be paid under this Section 6(g) shall be paid within thirty (30) days after the Change in Control Date of such Change in Control.

(h)

Deferral of Payments.  The  Executive shall have the right to elect to defer the Post-Change in Control Severance Payment to be received by the  Executive pursuant to this Section 6 under the terms and conditions of the Deferred Compensation Plan.  Any such deferral election shall be made in accordance with Section 18(b) hereof.

Section 7.

Severance Benefits upon Termination by the Company for Cause or by the  Executive Other than for Good Reason.  If the  Executive’s employment shall be terminated for Cause, or if the  Executive terminates employment other than for Good Reason, the Company shall have no further obligations to the  Executive under this Agreement other than the Pre-Change in Control Accrued Obligations and any amounts or benefits described in Section 11 hereof.

Section 8.

Severance Benefits upon Termination due to Death or Disability.  If the  Executive has a Separation from Service by reason of death or Disability, the Company shall pay the  Executive or his estate, as the case may be, the Post-Change in Control Accrued Obligations (without regard to whether a Change in Control has occurred) and any amounts or benefits described in Section 11 hereof.  Such payments shall be in addition to those rights and benefits to which the  Executive or his estate may be entitled under the relevant Company plans or programs.  Such payments shall be paid on such date as determined by the Company within thirty (30) days after the date of the Separation from Service; provided, however, that if the  Executive is a Specified Employee on the date of the  Executive’s Separation from Service by reason of Disability, the Additional Post-Change in Control Severance Payment under Section 6(a)(E) shall be paid as provided in Section 10 hereof.

Section 9.

Limitations on Payments by the Company.  

(a)

Anything in this Agreement to the contrary notwithstanding and except as set forth in this Section 9 below, in the event it shall be determined that any payment or distribution in the nature of compensation (within the meaning of Section 280G(b)(2) of the Code) to or for the benefit of the  Executive, whether paid or payable pursuant to this Agreement or otherwise (the “Payment”) would be subject (in whole or in part) to the excise tax imposed by Section 4999 of the Code, (the “Excise Tax”), then, subject to subsection (b), the Pre-Change in Control Severance Benefit or the Post-Change in Control Severance Payment (whichever is applicable) payable under this Agreement shall be reduced under this subsection (a) to the amount equal to the Reduced Payment.  For such Payment payable under this Agreement, the “Reduced Payment” shall be the amount equal to the greatest portion of the Payment (which may be zero)  that, if paid, would result in no portion of any Payment being subject to the Excise Tax.  

(b)

The Pre-Change in Control Severance Benefit or the Post-Change in Control Severance Payment (whichever is applicable) payable under this Agreement shall not be reduced under subsection (a) if:  

(i)

such reduction in such Payment is not sufficient to cause no portion of any Payment to be subject to the Excise Tax, or

(ii)

the Net After-Tax Unreduced Payments (as defined below) would equal or exceed one hundred and five percent (105%) of the Net After-Tax Reduced Payments (as defined below).  

For purposes of determining the amount of any Reduced Payment under subsection (a), and the Net-After Tax Reduced Payments and the Net After-Tax Unreduced Payments, the Executive shall be considered to pay federal, state and local income and employment taxes at the Executive’s applicable marginal rates taking into consideration any reduction in federal income taxes which could be obtained from the deduction of state and local income taxes, and any reduction or disallowance of itemized deductions and personal exemptions under applicable tax law).  The applicable federal, state and local income and employment taxes and the Excise Tax (to the extent applicable) are collectively referred to as the “Taxes”.

(c)

The following definitions shall apply for purposes of this Section 9:

(i)

“Net After-Tax Reduced Payments” shall mean the total amount of all Payments that the Executive would retain, on a Net After-Tax Basis, in the event that the Payments payable under this Agreement are reduced pursuant to subsection (a).

(ii)

“Net After-Tax Unreduced Payments” shall mean the total amount of all Payments that the Executive would retain, on a Net After-Tax Basis, in the event that the Payments payable under this Agreement are not reduced pursuant to subsection (a).

(iii)

“Net After-Tax Basis” shall mean, with respect to the Payments, either with or without reduction under subsection (a) (as applicable), the amount that would be retained by the Executive from such Payments after the payment of all Taxes.

(d)

All determinations required to be made under this Section 9 and the assumptions to be utilized in arriving at such determinations, shall be made by a nationally recognized accounting firm as may be agreed by the Company and the Executive (the “Accounting Firm”); provided, that the Accounting Firm’s determination shall be made based upon “substantial authority” within the meaning of Section 6662 of the Code.  The Accounting Firm shall provide detailed supporting calculations to both the Company and the Executive within fifteen (15) business days of the receipt of notice from the Executive that there has been a Payment or such earlier time as is requested by the Company.  All fees and expenses of the Accounting Firm shall be borne solely by the Company.  Any determination by the Accounting Firm shall be binding upon the Company and the Executive.  For purposes of determining whether and the extent to which the Payments will be subject to the Excise Tax, (i) no portion of the Payments the receipt or enjoyment of which the Executive shall have waived at such time and in such manner as not to constitute a “payment” within the meaning of Section 280G(b) of the Code shall be taken into account, (ii) no portion of the Payments shall be taken into account which, in the written opinion of the Accounting Firm, does not constitute a “parachute payment” within the meaning of Section 280G(b)(2) of the Code (including by reason of Section 280G(b)(4)(A) of the Code) and, in calculating the Excise Tax, no portion of such Payments shall be taken into account which, in the opinion of the Accounting Firm, constitutes reasonable compensation for services actually rendered, within the meaning of Section 280G(b)(4)(B) of the Code, in excess of the base amount (as defined in Section 280G(b)(3) of the Code) allocable to such reasonable compensation, and (iii) the value of any non-cash benefit or any deferred payment or benefit included in the Payments shall be determined by the Accounting Firm in accordance with the principles of Sections 280G(d)(3) and (4) of the Code.

Section 10.

Delayed Distribution under Section 409A of the Code.  If the  Executive is a Specified Employee on the date of the  Executive’s Involuntary Termination (or on the date of the Executive’s Separation from Service by reason of Disability), the Section 409A Payments, and any other payments or benefits under this Agreement subject to Section 409A of the Code, shall be delayed in order to avoid a prohibited distribution under Section 409A(a)(2)(B)(i) of the Code, and such payments or benefits shall be paid or distributed to the  Executive during the thirty (30) day period commencing on the earlier of (a) the expiration of the six-month period measured from the date of the  Executive’s Separation from Service or (b) the date of the Executive’s death.  Upon the expiration of the applicable six-month period under Section 409A(a)(2)(B)(i) of the Code, all payments deferred pursuant to this Section 10 (excluding in-kind benefits) shall be paid in a lump sum payment to the  Executive, plus interest thereon from the date of the  Executive’s Involuntary Termination through the payment date at an annual rate equal to Moody’s Rate.  The “Moody’s Rate” shall mean the average of the daily Moody’s Corporate Bond Yield Average – Monthly Average Corporates as published by Moody’s Investors Service, Inc. (or any successor) for the month next preceding the Date of Termination.  Any remaining payments due under the Agreement shall be paid as otherwise provided herein.

Section 11.

Nonexclusivity of Rights.  Nothing in this Agreement shall prevent or limit the  Executive’s continuing or future participation in any benefit, plan, program, policy or practice provided by the Company and for which the  Executive may qualify (except with respect to any benefit to which the  Executive has waived his rights in writing), including, without limitation, any and all indemnification arrangements in favor of the  Executive (whether under agreements or under the Company’s charter documents or otherwise), and insurance policies covering the  Executive, nor shall anything herein limit or otherwise affect such rights as the  Executive may have under any other contract or agreement entered into after the Effective Date with the Company.  Amounts which are vested benefits or which the  Executive is otherwise entitled to receive under any benefit, plan, policy, practice or program of, or any contract or agreement entered into with, the Company shall be payable in accordance with such benefit, plan, policy, practice or program or contract or agreement except as explicitly modified by this Agreement.  At all times during the  Executive’s employment with the Company and thereafter, the Company shall provide (to the extent permissible under applicable law) the  Executive with indemnification and D&O insurance insuring the  Executive against insurable events which occur or have occurred while the  Executive was a director or the Executive officer of the Company, on terms and conditions that are at least as generous as that then provided to any other current or former director or the Executive officer of the Company or any Affiliate.  Such indemnification and D&O insurance shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(b)(10).

Section 12.

Full Settlement; Mitigation.  The Company’s obligation to make the payments provided for in this Agreement and otherwise to perform its obligations hereunder shall not be affected by any set-off, counterclaim, recoupment, defense or other claim, right or action which the Company may have against the  Executive or others, provided that nothing herein shall preclude the Company from separately pursuing recovery from the  Executive based on any such claim.  In no event shall the  Executive be obligated to seek other employment or take any other action by way of mitigation of the amounts (including amounts for damages for breach) payable to the  Executive under any of the provisions of this Agreement, and such amounts shall not be reduced whether or not the  Executive obtains other employment.

Section 13.

Dispute Resolution.

Any disagreement, dispute, controversy or claim arising out of or relating to this Agreement or the interpretation of this Agreement or any arrangements relating to this Agreement or contemplated in this Agreement or the breach, termination or invalidity thereof shall be settled by final and binding arbitration administered by JAMS in San Diego, California in accordance with the then existing JAMS arbitration rules applicable to employment disputes (the “JAMS Rules”); provided that, notwithstanding any provision in such rules to the contrary, in all cases the parties shall be entitled to reasonable discovery.  In the event of such an arbitration proceeding, the  Executive and the Company shall select a mutually acceptable neutral arbitrator from among the JAMS panel of arbitrators.  In the event the  Executive and the Company cannot agree on an arbitrator, the arbitrator shall be selected in accordance with the then existing JAMS Rules.  Neither the  Executive nor the Company nor the arbitrator shall disclose the existence, content or results of any arbitration hereunder without the prior written consent of all parties, except to the extent necessary to enforce any arbitration award in a court of competent jurisdiction.  Except as provided herein, the Federal Arbitration Act shall govern the interpretation of, enforcement of and all proceedings under this agreement to arbitrate.  The arbitrator shall apply the substantive law (and the law of remedies, if applicable) of the state of California, or federal law, or both, as applicable, and the arbitrator is without jurisdiction to apply any different substantive law.  The arbitrator shall have the authority to entertain a motion to dismiss and/or a motion for summary judgment by any party and shall apply the standards governing such motions under the Federal Rules of Civil Procedure.  The arbitrator shall render an award and a written, reasoned opinion in support thereof.  Judgment upon the award may be entered in any court having jurisdiction thereof.  The  Executive shall not be required to pay any arbitration fee or cost that is unique to arbitration or greater than any amount he would be required to pay to pursue his claims in a court of competent jurisdiction.

Section 14.

Executive’s Covenants.    

(a)

Confidentiality.  The  Executive acknowledges that in the course of his employment with the Company, he has acquired non-public privileged or confidential information and trade secrets concerning the operations, future plans and methods of doing business (“Proprietary Information”) of the Company and its Affiliates; and the  Executive agrees that it would be extremely damaging to the Company and its Affiliates if such Proprietary Information were disclosed to a competitor of the Company and its Affiliates or to any other person or corporation.  The  Executive understands and agrees that all Proprietary Information has been divulged to the  Executive in confidence and further understands and agrees to keep all Proprietary Information secret and confidential (except for such information which is or becomes publicly available other than as a result of a breach by the  Executive of this provision or information the  Executive is required by any governmental, administrative or court order to disclose) without limitation in time.  In view of the nature of the  Executive’s employment and the Proprietary Information the  Executive has acquired during the course of such employment, the  Executive likewise agrees that the Company and its Affiliates would be irreparably harmed by any disclosure of Proprietary Information in violation of the terms of this paragraph and that the Company and its Affiliates shall therefore be entitled to preliminary and/or permanent injunctive relief prohibiting the  Executive from engaging in any activity or threatened activity in violation of the terms of this paragraph and to any other relief available to them.  Inquiries regarding whether specific information constitutes Proprietary Information shall be directed to the Company’s Senior Vice President, Public Policy (or, if such position is vacant, the Company’s then Chief Executive Officer); provided, that the Company shall not unreasonably classify information as Proprietary Information.

(b)

Non-Solicitation of Employees.  The  Executive recognizes that he possesses and will possess confidential information about other employees of the Company and its Affiliates relating to their education, experience, skills, abilities, compensation and benefits, and inter-personal relationships with customers of the Company and its Affiliates.  The  Executive recognizes that the information he possesses and will possess about these other employees is not generally known, is of substantial value to the Company and its Affiliates in developing their business and in securing and retaining customers, and has been and will be acquired by him because of his business position with the Company and its Affiliates.  The  Executive agrees that at all times during the  Executive’s employment with the Company and for a period of one (1) year thereafter, he will not, directly or indirectly, solicit or recruit any employee of the Company or its Affiliates for the purpose of being employed by him or by any competitor of the Company or its Affiliates on whose behalf he is acting as an agent, representative or employee and that he will not convey any such confidential information or trade secrets about other employees of the Company and its Affiliates to any other person; provided, however, that it shall not constitute a solicitation or recruitment of employment in violation of this paragraph to discuss employment opportunities with any employee of the Company or its Affiliates who has either first contacted the  Executive or regarding whose employment the  Executive has discussed with and received the written approval of the Company’s Vice President, Human Resources (or, if such position is vacant, the Company’s then Chief Executive Officer), prior to making such solicitation or recruitment.  In view of the nature of the  Executive’s employment with the Company, the  Executive likewise agrees that the Company and its Affiliates would be irreparably harmed by any solicitation or recruitment in violation of the terms of this paragraph and that the Company and its Affiliates shall therefore be entitled to preliminary and/or permanent injunctive relief prohibiting the  Executive from engaging in any activity or threatened activity in violation of the terms of this paragraph and to any other relief available to them.

(c)

Survival of Provisions.  The obligations contained in Section 14(a) and Section 14(b) above shall survive the termination of the  Executive’s employment within the Company and shall be fully enforceable thereafter.  If it is determined by a court of competent jurisdiction in any state that any restriction in Section 14(a) or Section 14(b) above is excessive in duration or scope or is unreasonable or unenforceable under the laws of that state, it is the intention of the parties that such restriction may be modified or amended by the court to render it enforceable to the maximum extent permitted by the law of that state.

(d)

Release; Lump Sum Payment.  In the event of the  Executive’s Involuntary Termination,  if the  Executive (i) agrees to the covenants described in Section 14(a) and Section 14(b) above, (ii) executes a release (the “Release”) of all claims substantially in the form attached hereto as Exhibit A within fifty (50) days after the date of Involuntary Termination and does not revoke such Release in accordance with the terms thereof, and (iii) agrees to provide the consulting services described in Section 14(e) below, then in consideration for such covenants, the Company shall pay the  Executive, in one cash lump sum, an amount (the “Consulting Payment”) in cash equal to the greater of:  (X) 170% of the Executive’s Annual Base Salary as in effect on the Date of Termination, and (Y) the Executive’s Annual Base Salary as in effect on the Date of Termination, plus the Executive’s Average Annual Bonus.  Except as provided in this subsection, the Consulting Payment shall be paid on such date as is determined by the Company within the ten (10) day period commencing on the 60th day after the date of the Executive’s Involuntary Termination; provided, however, that if the  Executive is a Specified Employee on the date of the  Executive’s Involuntary Termination, the Consulting Payment shall be paid as provided in Section 10 hereof.  The  Executive shall have the right to elect to defer the Consulting Payment under the terms and conditions of the Company’s Deferred Compensation Plan.  Any such deferral election shall be made in accordance with Section 18(b) hereof.

(e)

Consulting.  If the  Executive agrees to the covenants described in Section 14(d) above,  then the  Executive shall have the obligation to provide consulting services to the Company as an independent contractor, commencing on the Date of Termination and ending on the second anniversary of the Date of Termination (the “Consulting Period”).  The  Executive shall hold himself available at reasonable times and on reasonable notice to render such consulting services as may be so assigned to him by the Board or the Company’s then Chief Executive Officer; provided, however, that unless the parties otherwise agree, the consulting services rendered by the  Executive during the Consulting Period shall not exceed twenty (20) hours each month; and, provided, further, that the consulting services rendered by the  Executive during the Consulting Period shall in no event exceed twenty percent (20%) of the average level of services performed by the  Executive for the Company over the thirty-six (36) month period immediately preceding the  Executive’s Separation from Service (or the full period of services to the Company, if the  Executive has been providing services to the Company for less than thirty-six (36) months).  The Company agrees to use its best efforts during the Consulting Period to secure the benefit of the  Executive’s consulting services so as to minimize the interference with the  Executive’s other activities, including requiring the performance of consulting services at the Company’s offices only when such services may not be reasonably performed off-site by the  Executive.

Section 15.

Legal Fees.  

(a)

Reimbursement of Legal Fees.  Subject to subsection (b), in the event of the Executive’s Separation from Service either (1) prior to a Change in Control, or (2) on or within two (2) years following a Change in Control, the Company shall reimburse the  Executive for all legal fees and expenses (including but not limited to fees and expenses in connection with any arbitration) incurred by the  Executive in disputing any issue arising under this Agreement relating to the  Executive’s Separation from Service or in seeking to obtain or enforce any benefit or right provided by this Agreement.  

(b)

Requirements for Reimbursement.  The Company shall reimburse the  Executive’s legal fees and expenses pursuant to subsection (a) above only to the extent the arbitrator or court determines the following:  (i) the  Executive disputed such issue, or sought to obtain or enforce such benefit or right, in good faith, (ii) the  Executive had a reasonable basis for such claim, and (iii) in the case of subsection (a)(1) above, the  Executive is the prevailing party.  In addition, the Company shall reimburse such legal fees and expenses, only if such legal fees and expenses are incurred during the twenty (20) year period beginning on the date of the Executive’s Separation from Service.   The legal fees and expenses paid to the  Executive for any taxable year of the  Executive shall not affect the legal fees and expenses paid to the  Executive for any other taxable year of the  Executive.  The legal fees and expenses shall be paid to the Executive on or before the last day of the Executive’s taxable year following the taxable year in which the fees or expenses are incurred.  The  Executive’s right to reimbursement of legal fees and expenses shall not be subject to liquidation or exchange for any other benefit.  Such right to reimbursement of legal fees and expenses shall be provided in a manner that complies with Treasury Regulation Section 1.409A-3(i)(1)(iv).  If the Executive is a Specified Employee on the date of the Executive’s Separation from Service, such right to reimbursement of legal fees and expenses shall be paid as provided in Section 10 hereof.

Section 16.

Successors.

(a)

Assignment by the Executive.  This Agreement is personal to the  Executive and without the prior written consent of Sempra Energy shall not be assignable by the  Executive otherwise than by will or the laws of descent and distribution.  This Agreement shall inure to the benefit of and be enforceable by the  Executive’s legal representatives.

(b)

Successors and Assigns of Sempra Energy.  This Agreement shall inure to the benefit of and be binding upon Sempra Energy, its successors and assigns.  Sempra Energy may not assign this Agreement to any person or entity (except for a successor described in Section 16(c), (d) or (e) below) without the  Executive’s written consent.

(c)

Assumption.  Sempra Energy shall require any successor (whether direct or indirect, by purchase, merger, consolidation or otherwise) to all or substantially all of the business and/or assets of Sempra Energy to assume expressly and agree to perform the obligations and satisfy and discharge the liabilities of this Agreement in the same manner and to the same extent that Sempra Energy would have been required to perform the obligations and satisfy and discharge the liabilities under this Agreement if no such succession had taken place, and Sempra Energy shall have no further obligations and liabilities under this Agreement.  Upon such assumption, references to Sempra Energy in this Agreement shall be replaced with references to such successor.

(d)

Sale of Subsidiary.  In the event that (i) the Executive is employed by a direct or indirect subsidiary of Sempra Energy that is a member of the Sempra Energy Control Group, (ii) Sempra Energy, directly or indirectly through one or more intermediaries, sells or otherwise disposes of such subsidiary, and (iii) such subsidiary ceases to be a member of the Sempra Energy Control Group, then if, on the date such subsidiary ceases to be a member of the Sempra Energy Control Group, the Executive continues in employment with such subsidiary and the Executive does not have a Separation from Service, Sempra Energy shall require such subsidiary or any successor (whether direct or indirect, by purchase merger, consolidation or otherwise) to such subsidiary, or the parent thereof, to assume expressly and agree to perform the obligations and satisfy and discharge the liabilities under this Agreement in the same manner and to the same extent that Sempra Energy would have been required to perform the obligations and satisfy and discharge the liabilities under this Agreement, if such subsidiary had not ceased to be part of the Sempra Energy Control Group, and, upon such assumption, Sempra Energy shall have no further obligations and liabilities under the Agreement.  Upon such assumption, (i) references to Sempra Energy in this Agreement shall be replaced with references to such subsidiary, or such successor or parent thereof, assuming this Agreement, and (ii) subsection (b) of the definition of “Cause” and subsection (b) of the definition of “Good Reason” shall apply thereafter, as if a Change in Control had occurred on the date of such cessation.

(e)

Sale of Assets of Subsidiary.  In the event that (i) the Executive is employed by a direct or indirect subsidiary of Sempra Energy, and (ii) such subsidiary sells or otherwise disposes of substantial assets of such subsidiary to an unrelated service recipient, as determined under Treasury Regulation Section 1.409A-1(f)(2)(ii) (the “Asset Purchaser”), in a transaction described in Treasury Regulation Section 1.409A-1(h)(4) (an “Asset Sale”), then if, on the date of such Asset Sale, the Executive becomes employed by the Asset Purchaser, Sempra Energy and the Asset Purchaser shall specify, in accordance with Treasury Regulation Section 1.409A-1(h)(4), that the Executive shall not be treated as having a Separation from Service, and Sempra Energy shall require such Asset Purchaser, or the parent thereof, to assume expressly and agree to perform the obligations and satisfy and discharge the liabilities under this Agreement in the same manner and to the same extent that Sempra Energy would have been required to perform the obligations and satisfy and discharge the liabilities under this Agreement, if the Asset Sale had not taken place, and, upon such assumption, Sempra Energy shall have no further obligations and liabilities under the Agreement.  Upon such assumption, (i) references to Sempra Energy in this Agreement shall be replaced with references to the Asset Purchaser or the parent thereof, as applicable, and (ii) subsection (b) of the definition of “Cause” and subsection (b) of the definition of “Good Reason” shall apply thereafter, as if a Change in Control had occurred on the date of the Asset Sale.

Section 17.

Administration Prior to Change in Control.  Prior to a Change in Control, the Compensation Committee shall have full and complete authority to construe and interpret the provisions of this Agreement, to determine an individual’s entitlement to benefits under this Agreement, to make in its sole and absolute discretion all determinations contemplated under this Agreement, to investigate and make factual determinations necessary or advisable to administer or implement this Agreement, and to adopt such rules and procedures as it deems necessary or advisable for the administration or implementation of this Agreement.  All determinations made under this Agreement by the Compensation Committee shall be final and binding on all interested persons.  Prior to a Change in Control, the Compensation Committee may delegate responsibilities for the operation and administration of this Agreement to one or more officers or employees of the Company.  The provisions of this Section 17 shall terminate and be of no further force and effect upon the occurrence of a Change in Control.   

Section 18.

Section 409A of the Code.

(a)

Compliance with and Exemption from Section 409A of the Code.  Certain payments and benefits payable under this Agreement (including, without limitation, the Section 409A Payments) are intended to comply with the requirements of Section 409A of the Code.  Certain payments and benefits payable under this Agreement are intended to be exempt from the requirements of Section 409A of the Code.  This Agreement shall be interpreted in accordance with the applicable requirements of, and exemptions from, Section 409A of the Code and the Treasury Regulations thereunder.  To the extent the payments and benefits under this Agreement are subject to Section 409A of the Code, this Agreement shall be interpreted, construed and administered in a manner that satisfies the requirements of Sections 409A(a)(2), (3) and (4) of the Code and the Treasury Regulations thereunder (subject to the transitional relief under Internal Revenue Service Notice 2005-1, the Proposed Regulations under Section 409A of the Code, Internal Revenue Service Notice 2006-79, Internal Revenue Service Notice 2007-78, Internal Revenue Service Notice 2007-86 and other applicable authority issued by the Internal Revenue Service).  As provided in Internal Revenue Notice 2007-86, notwithstanding any other provision of this Agreement, with respect to an election or amendment to change a time or form of payment under this Agreement made on or after January 1, 2008 and on or before December 31, 2008, the election or amendment shall apply only with respect to payments that would not otherwise be payable in 2008, and shall not cause payments to be made in 2008 that would not otherwise be payable in 2008.  If the Company and the  Executive determine that any compensation, benefits or other payments that are payable under this Agreement and intended to comply with Sections 409A(a)(2), (3) and (4) of the Code do not comply with Section 409A of the Code, the Treasury Regulations thereunder and other applicable authority issued by the Internal Revenue Service, to the extent permitted under Section 409A of the Code, the Treasury Regulations thereunder and any applicable authority issued by the Internal Revenue Service, the Company and the  Executive agree to amend this Agreement, or take such other actions as the Company and the  Executive deem reasonably necessary or appropriate, to cause such compensation, benefits and other payments to comply with the requirements of Section 409A of the Code, the Treasury Regulations thereunder and other applicable authority issued by the Internal Revenue Service, while providing compensation, benefits and other payments that are, in the aggregate, no less favorable than the compensation, benefits and other payments provided under this Agreement.  In the case of any compensation, benefits or other payments that are payable under this Agreement and intended to comply with Sections 409A(a)(2), (3) and (4) of the Code, if any provision of the Agreement would cause such compensation, benefits or other payments to fail to so comply, such provision shall not be effective and shall be null and void with respect to such compensation, benefits or other payments to the extent such provision would cause a failure to comply, and such provision shall otherwise remain in full force and effect.

(b)

Deferral Elections.  As provided in Sections 5(f), 6(h) and 14(d), the  Executive may elect to defer the Pre-Change in Control Severance Payment, the Post-Change in Control Severance Payment and the Consulting Payment as follows.    The  Executive’s deferral election shall satisfy the requirements of Treasury Regulation Section 1.409A-2(b) and the terms and conditions of the Deferred Compensation Plan.  Such deferral election shall designate the whole percentage (up to a maximum of 100%) of the Pre-Change in Control Severance Payment, the Post-Change in Control Severance Payment and the Consulting Payment to be deferred, shall be irrevocable when made, and shall not take effect until at least twelve (12) months after the date on which the election is made.  Such deferral election shall provide that the amount deferred shall be deferred for a period of not less than five (5) years from the date the payment of the amount deferred would otherwise have been made, in accordance with Treasury Regulation Section 1.409A-2(b)(1)(ii).

Section 19.

Miscellaneous.

(a)

Governing Law.  This Agreement shall be governed by and construed in accordance with the laws of the State of California, without reference to its principles of conflict of laws.  The captions of this Agreement are not part of the provisions hereof and shall have no force or effect.  This Agreement may not be amended, modified, repealed, waived, extended or discharged except by an agreement in writing signed by the party against whom enforcement of such amendment, modification, repeal, waiver, extension or discharge is sought.  No person, other than pursuant to a resolution of the Board or a committee thereof, shall have authority on behalf of the Company to agree to amend, modify, repeal, waive, extend or discharge any provision of this Agreement or anything in reference thereto.

(b)

Notices.  All notices and other communications hereunder shall be in writing and shall be given by hand delivery to the other party or by registered or certified mail, return receipt requested, postage prepaid, addressed, in either case, to the Company’s headquarters or to such other address as either party shall have furnished to the other in writing in accordance herewith.  Notices and communications shall be effective when actually received by the addressee.

(c)

Severability.  The invalidity or unenforceability of any provision of this Agreement shall not affect the validity or enforceability of any other provision of this Agreement.

(d)

Taxes.  The Company may withhold from any amounts payable under this Agreement such federal, state or local taxes as shall be required to be withheld pursuant to any applicable law or regulation.

(e)

No Waiver.  The  Executive’s or the Company’s failure to insist upon strict compliance with any provision hereof or any other provision of this Agreement or the failure to assert any right the  Executive or the Company may have hereunder, including, without limitation, the right of the  Executive to terminate employment for Good Reason pursuant to Section 1 hereof, or the right of the Company to terminate the  Executive’s employment for Cause pursuant to Section 1 hereof shall not be deemed to be a waiver of such provision or right or any other provision or right of this Agreement.

(f)

Entire Agreement; Exclusive Benefit; Supersession of Prior Agreement.  This instrument contains the entire agreement of the  Executive, the Company or any predecessor or subsidiary thereof with respect to any severance or termination pay.  The Pre-Change in Control Severance Payment, the Post-Change in Control Severance Payment and all other benefits provided hereunder shall be in lieu of any other severance payments to which the  Executive is entitled under any other severance plan or program or arrangement sponsored by the Company, as well as pursuant to any individual employment or severance agreement that was entered into by the  Executive and the Company, and, upon the Effective Date of this Agreement, all such plans, programs, arrangements and agreements are hereby automatically superseded and terminated.  

(g)

No Right of Employment.  Nothing in this Agreement shall be construed as giving the  Executive any right to be retained in the employ of the Company or shall interfere in any way with the right of the Company to terminate the  Executive’s employment at any time, with or without Cause.

(h)

Unfunded Obligation.  The obligations under this Agreement shall be unfunded.  Benefits payable under this Agreement shall be paid from the general assets of the Company.  The Company shall have no obligation to establish any fund or to set aside any assets to provide benefits under this Agreement.

(i)

Termination upon Sale of Assets of Subsidiary.  Notwithstanding anything contained herein, this Agreement shall automatically terminate and be of no further force and effect and no benefits shall be payable hereunder in the event that (i) the Executive is employed by a direct or indirect subsidiary of Sempra Energy, and (ii) an Asset Sale (as defined in Section 16(e)) occurs (other than such a sale or disposition which is part of a transaction or series of transactions which would result in a Change in Control), and (iii) as a result of such Asset Sale, the  Executive is offered employment by the Asset Purchaser in an executive position with reasonably comparable status, compensation, benefits and severance agreement (including the assumption of this Agreement in accordance with Section 16(e)) and which is consistent with the  Executive’s experience and education, but the  Executive declines to accept such offer and the Executive fails to become employed by the Asset Purchaser on the date of the Asset Sale.  

(j)

Term.  The term of this Agreement shall commence on the Effective Date and shall continue until the third (3rd) anniversary of the Effective Date; provided, however, that commencing on the second (2nd) anniversary of the Effective Date (and each anniversary of the Effective Date thereafter), the term of this Agreement shall automatically be extended for one (1) additional year, unless at least ninety (90) days prior to such date, the Company or the  Executive shall give written notice to the other party that it or he, as the case may be, does not wish to so extend this Agreement.  Notwithstanding the foregoing, if the Company gives such written notice to the  Executive less than two (2) years after a Change in Control, the term of this Agreement shall be automatically extended until the later of (A) the date that is one (1) year after the anniversary of the Effective Date that follows such written notice or (B) the second (2nd) anniversary of the Change in Control Date.

(k)

Counterparts.  This Agreement may be executed in several counterparts, each of which shall be deemed to be an original but all of which together shall constitute one and the same instrument.


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 OC\1056247.3


IN WITNESS WHEREOF, the  Executive and, pursuant to due authorization from its Board of Directors, the Company have caused this Agreement to be executed as of the day and year first above written.

SEMPRA ENERGY


G. Joyce Rowland

Senior Vice President - Human Resources,
Diversity & Inclusion


_____________________________________

Date


EXECUTIVE




Michael W. Allman

President & CEO, Southern California Gas Company


_____________________________________

Date




 OC\1056247.3




EXHIBIT A


GENERAL RELEASE

This GENERAL RELEASE (the “Agreement”), dated ___________, is made by and between ______________________________, a California corporation (the “Company”) and  ___________________________ (“you” or “your”).

WHEREAS, you and the Company have previously entered into that certain Severance Pay Agreement dated ____________, 20___ (the “Severance Pay Agreement”); and

WHEREAS, Section 14(d) of the Severance Pay Agreement provides for the payment of a benefit to you by the Company in consideration for certain covenants, including your execution and non-revocation of a general release of claims by you against the Company and its subsidiaries and affiliates.

NOW, THEREFORE, in consideration of the premises and the mutual covenants herein contained, you and the Company hereby agree as follows:

ONE:  Your signing of this Agreement confirms that your employment with the Company shall terminate at the close of business on ____________, or earlier upon our mutual agreement.

TWO:  As a material inducement for the payment of the benefit under Section 14(d) of the Severance Pay Agreement, and except as otherwise provided in this Agreement, you and the Company hereby irrevocably and unconditionally release, acquit and forever discharge the other from any and all Claims either may have against the other.  For purposes of this Agreement and the preceding sentence, the words “Releasee” or “Releasees” and “Claim” or “Claims” shall have the meanings set forth below:

(a)

The words “Releasee” or “Releasees” shall refer to you and to the Company and each of the Company’s owners, stockholders, predecessors, successors, assigns, agents, directors, officers, employees, representatives, attorneys, advisors, parent companies, divisions, subsidiaries, affiliates (and agents, directors, officers, employees, representatives, attorneys and advisors of such parent companies, divisions, subsidiaries and affiliates) and all persons acting by, through, under or in concert with any of them.

(b)

The words “Claim” or “Claims” shall refer to any charges, complaints, claims, liabilities, obligations, promises, agreements, controversies, damages, actions, causes of action, suits, rights, demands, costs, losses, debts and expenses (including attorneys’ fees and costs actually incurred) of any nature whatsoever, known or unknown, suspected or unsuspected, which you or the Company now, in the past or, except as limited by law or regulation such as the Age Discrimination in Employment Act (ADEA), in the future may have, own or hold against any of the Releasees; provided, however, that the word “Claim” or “Claims” shall not refer to any charges, complaints, claims, liabilities, obligations, promises, agreements, controversies, damages, actions, causes of action, suits, rights, demands, costs, losses, debts and expenses (including attorneys’ fees and costs actually incurred) arising under [identify severance, employee benefits, stock option, indemnification and D&O  and other agreements containing duties, rights obligations etc. of either party that are to remain operative].  Claims released pursuant to this Agreement by you and the Company include, but are not limited to, rights arising out of alleged violations of any contracts, express or implied, any tort, any claim that you failed to perform or negligently performed or breached your duties during employment at the Company, any legal restrictions on the Company’s right to terminate employees or any federal, state or other governmental statute, regulation, or ordinance, including, without limitation:  (1) Title VII of the Civil Rights Act of 1964 (race, color, religion, sex and national origin discrimination); (2) 42 U.S.C. § 1981 (discrimination); (3) 29 U.S.C. §§ 621–634 (age discrimination); (4) 29 U.S.C. § 206(d)(l) (equal pay); (5) 42 U.S.C. §§ 12101, et seq. (disability); (6) the California Constitution, Article I, Section 8 (discrimination); (7) the California Fair Employment and Housing Act (discrimination, including race, color, national origin, ancestry, physical handicap, medical condition, marital status, religion, sex or age); (8) California Labor Code Section 1102.1 (sexual orientation discrimination); (9) the Executive Order 11246 (race, color, religion, sex and national origin discrimination); (10) the Executive Order 11141 (age discrimination); (11) §§ 503 and 504 of the Rehabilitation Act of 1973 (handicap discrimination); (12) The Worker Adjustment and Retraining Act (WARN Act); (13) the California Labor Code (wages, hours, working conditions, benefits and other matters); (14) the Fair Labor Standards Act (wages, hours, working conditions and other matters); the Federal Employee Polygraph Protection Act (prohibits employer from requiring employee to take polygraph test as condition of employment); and (15) any federal, state or other governmental statute, regulation or ordinance which is similar to any of the statutes described in clauses (1) through (14).

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

“A GENERAL RELEASE DOES NOT EXTEND TO CLAIMS WHICH THE CREDITOR DOES NOT KNOW OR SUSPECT TO EXIST IN HIS FAVOR AT THE TIME OF EXECUTING THE RELEASE, WHICH IF KNOWN BY HIM MUST HAVE MATERIALLY AFFECTED HIS SETTLEMENT WITH THE DEBTOR.”

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

FOUR:  The parties acknowledge that they might hereafter discover facts different from, or in addition to, those they now know or believe to be true with respect to a Claim or Claims released herein, and they expressly agree to assume the risk of possible discovery of additional or different facts, and agree that this Agreement shall be and remain effective, in all respects, regardless of such additional or different discovered facts.

FIVE:  You hereby represent and acknowledge that you have not filed any Claim of any kind against the Company or others released in this Agreement.  You further hereby expressly agree never to initiate against the Company or others released in this Agreement any administrative proceeding, lawsuit or any other legal or equitable proceeding of any kind asserting any Claims that are released in this Agreement.

The Company hereby represents and acknowledges that it has not filed any Claim of any kind against you or others released in this Agreement.  The Company further hereby expressly agrees never to initiate against you or others released in this Agreement any administrative proceeding, lawsuit or any other legal or equitable proceeding of any kind asserting any Claims that are released in this Agreement.

SIX:  You hereby represent and agree that you have not assigned or transferred, or attempted to have assigned or transfer, to any person or entity, any of the Claims that you are releasing in this Agreement.

The Company hereby represents and agrees that it has not assigned or transferred, or attempted to have assigned or transfer, to any person or entity, any of the Claims that it is releasing in this Agreement.

SEVEN:  As a further material inducement to the Company to enter into this Agreement, you hereby agree to indemnify and hold each of the Releasees harmless from all loss, costs, damages, or expenses, including without limitation, attorneys’ fees incurred by the Releasees, arising out of any breach of this Agreement by you or the fact that any representation made in this Agreement by you was false when made.

As a further material inducement to you to enter into this Agreement, the Company hereby agrees to indemnify and hold each of the Releasees harmless from all loss, costs, damages, or expenses, including without limitation, attorneys’ fees incurred by the Releasees, arising out of any breach of this Agreement by it or the fact that any representation made in this Agreement by it was knowingly false when made.

EIGHT:  You and the Company represent and acknowledge that in executing this Agreement, neither is relying upon any representation or statement not set forth in this Agreement or the Severance Agreement.

NINE:

(a)

This Agreement shall not in any way be construed as an admission by the Company that it has acted wrongfully with respect to you or any other person, or that you have any rights whatsoever against the Company, and the Company specifically disclaims any liability to or wrongful acts against you or any other person, on the part of itself, its employees or its agents.  This Agreement shall not in any way be construed as an admission by you that you have acted wrongfully with respect to the Company, or that you failed to perform your duties or negligently performed or breached your duties, or that the Company had good cause to terminate your employment.

(b)

If you are a party or are threatened to be made a party to any proceeding by reason of the fact that you were an officer or director of the Company, the Company shall indemnify you against any expenses (including reasonable attorneys’ fees; provided, that counsel has been approved by the Company prior to retention, which approval shall not be unreasonably withheld), judgments, fines, settlements and other amounts actually or reasonably incurred by you in connection with that proceeding; provided, that you acted in good faith and in a manner you reasonably believed to be in the best interest of the Company.  The limitations of California Corporations Code Section 317 shall apply to this assurance of indemnification.

(c)

You agree to cooperate with the Company and its designated attorneys, representatives and agents in connection with any actual or threatened judicial, administrative or other legal or equitable proceeding in which the Company is or may become involved.  Upon reasonable notice, you agree to meet with and provide to the Company or its designated attorneys, representatives or agents all information and knowledge you have relating to the subject matter of any such proceeding.  The Company agrees to reimburse you for any reasonable costs you incur in providing such cooperation.

TEN:  This Agreement is made and entered into in California.  This Agreement shall in all respects be interpreted, enforced and governed by and under the laws of the State of California and applicable Federal law.  Any dispute about the validity, interpretation, effect or alleged violation of this Agreement (an “arbitrable dispute”) must be submitted to arbitration in San Diego, California.  Arbitration shall take place before an experienced employment arbitrator licensed to practice law in such state and selected in accordance with the then existing JAMS arbitration rules applicable to employment disputes; provided, however, that in any event, the arbitrator shall allow reasonable discovery.  Arbitration shall be the exclusive remedy for any arbitrable dispute.  The arbitrator in any arbitrable dispute shall not have authority to modify or change the Agreement in any respect.  You and the Company shall each be responsible for payment of one-half (1/2) the amount of the arbitrator’s fee(s); provided, however, that in no event shall you be required to pay any fee or cost of arbitration that is unique to arbitration or exceeds the costs you would have incurred had any arbitrable dispute been pursued in a court of competent jurisdiction.  The Company shall make up any shortfall.  Should any party to this Agreement institute any legal action or administrative proceeding against the other with respect to any Claim waived by this Agreement or pursue any arbitrable dispute by any method other than arbitration, the prevailing party shall be entitled to recover from the non-prevailing party all damages, costs, expenses and attorneys’ fees incurred as a result of that action.  The arbitrator’s decision and/or award shall be rendered in writing and will be fully enforceable and subject to an entry of judgment by the Superior Court of the State of California for the County of San Diego, or any other court of competent jurisdiction.

ELEVEN:  Both you and the Company understand that this Agreement is final and binding eight (8) days after its execution and return.  Should you nevertheless attempt to challenge the enforceability of this Agreement as provided in Paragraph TEN or, in violation of that Paragraph, through litigation, as a further limitation on any right to make such a challenge, you shall initially tender to the Company, by certified check delivered to the Company, all monies received pursuant to Section 14(d) of the Severance Pay Agreement, plus interest, and invite the Company to retain such monies and agree with you to cancel this Agreement and void the Company’s obligations under Section 14(d) of the Severance Pay Agreement.  In the event the Company accepts this offer, the Company shall retain such monies and this Agreement shall be canceled and the Company shall have no obligation under Section 14(d) of the Severance Pay Agreement.  In the event the Company does not accept such offer, the Company shall so notify you and shall place such monies in an interest-bearing escrow account pending resolution of the dispute between you and the Company as to whether or not this Agreement and the Company’s obligations under Section 14(d) of the Severance Pay Agreement shall be set aside and/or otherwise rendered voidable or unenforceable.  Additionally, any consulting agreement then in effect between you and the Company shall be immediately rescinded with no requirement of notice.

TWELVE:  Any notices required to be given under this Agreement shall be delivered either personally or by first class United States mail, postage prepaid, addressed to the respective parties as follows:

To Company:

[TO COME]

Attn:  [TO COME]

To You:

______________________

______________________

______________________

THIRTEEN:  You understand and acknowledge that you have been given a period of forty-five (45) days to review and consider this Agreement (as well as statistical data on the persons eligible for similar benefits) before signing it and may use as much of this forty-five (45) day period as you wish prior to signing.  You are encouraged, at your personal expense, to consult with an attorney before signing this Agreement.  You understand and acknowledge that whether or not you do so is your decision.  You may revoke this Agreement within seven (7) days of signing it.  If you wish to revoke, the Company’s Vice President, Human Resources must receive written notice from you no later than the close of business on the seventh (7th) day after you have signed the Agreement.  If revoked, this Agreement shall not be effective and enforceable, and you will not receive payments or benefits under Section 14(d) of the Severance Pay Agreement.

FOURTEEN:  This Agreement constitutes the entire agreement of the parties hereto and supersedes any and all other agreements (except the Severance Pay Agreement) with respect to the subject matter of this Agreement, whether written or oral, between you and the Company.  All modifications and amendments to this Agreement must be in writing and signed by the parties.

FIFTEEN:  Each party agrees, without further consideration, to sign or cause to be signed, and to deliver to the other party, any other documents and to take any other action as may be necessary to fulfill the obligations under this Agreement.

SIXTEEN:  If any provision of this Agreement or the application thereof is held invalid, the invalidity shall not affect other provisions or applications of the Agreement which can be given effect without the invalid provisions or application; and to this end the provisions of this Agreement are declared to be severable.

SEVENTEEN:  This Agreement may be executed in counterparts.

I have read the foregoing General Release, and I accept and agree to the provisions it contains and hereby execute it voluntarily and with full understanding of its consequences.  I am aware it includes a release of all known or unknown claims.

DATED:  __________

__________________________________________

DATED:  __________

__________________________________________

You acknowledge that you first received this Agreement on [date].

_________________________







 OC\1056247.3


Exhibit 10.26


Exhibit 10.26


SEMPRA ENERGY
SEVERANCE PAY AGREEMENT

THIS AGREEMENT (this “Agreement”), dated as of December 31, 2011 (the “Effective Date”), is made by and between SEMPRA ENERGY, a California corporation (“Sempra Energy”), and G. JOYCE ROWLAND (the “Executive”).

WHEREAS, the  Executive is currently employed by Sempra Energy or a direct or indirect subsidiary of Sempra Energy (Sempra Energy and its subsidiaries are hereinafter collectively referred to as the “Company”) as Sr. Vice President – Human Resources, Diversity and Inclusion; and

WHEREAS, Sempra Energy and the Executive desire to enter into this Agreement; and

WHEREAS, the Board of Directors of Sempra Energy (the “Board”) has authorized this Agreement.

NOW, THEREFORE, in consideration of the premises and mutual covenants herein contained, the Company and the  Executive hereby agree as follows:

Section 1.

Definitions.  For purposes of this Agreement, the following capitalized terms have the meanings set forth below:

Accounting Firm” has the meaning assigned thereto in Section 9(b) hereof.

Act” has the meaning assigned thereto in Section 2 hereof.

Additional Post-Change in Control Severance Payment” has the meaning assigned thereto in Section 6(a) hereof.

Affiliate” has the meaning set forth in Rule 12b-2 promulgated under the Exchange Act.

Annual Base Salary” means the  Executive’s annual base salary from the Company.

Asset Purchaser” has the meaning assigned thereto in Section 16(e).

Asset Sale” has the meaning assigned thereto in Section 16(e).

Average Annual Bonus” means the average of the annual bonuses from the Company earned by the Executive with respect to the three (3) fiscal years of the Company immediately preceding the Date of Termination (the “Bonus Fiscal Years”); provided, however, that, if the Executive was employed by the Company during all or any portion of one or two of the Bonus Fiscal Years (but not three of the Bonus Fiscal Years), “Average Annual Bonus” means the average of the annual bonuses (if any) from the Company earned by the Executive with respect to the Bonus Fiscal Years during all or any portion of which the Executive was employed by the Company; and, provided, further, that, if the Executive was not employed by the Company during all or any portion of any of the Bonus Fiscal Years, “Average Annual Bonus” means zero.

Beneficial Owner” has the meaning set forth in Rule 13d-3 promulgated under the Exchange Act.

Cause” means:  

(a)

Prior to a Change in Control, (i) the willful failure by the  Executive to substantially perform the  Executive’s duties with the Company (other than any such failure resulting from the  Executive’s incapacity due to physical or mental illness, (ii) the grossly negligent performance of such obligations referenced in clause (i) of this definition, (iii) the  Executive’s gross insubordination; and/or (iv) the  Executive’s commission of one or more acts of moral turpitude that constitute a violation of applicable law (including but not limited to a felony) which have or result in an adverse effect on the Company, monetarily or otherwise, or one or more significant acts of dishonesty.  For purposes of clause (i) of this subsection (a), no act, or failure to act, on the  Executive’s part shall be deemed “willful” unless done, or omitted to be done, by the  Executive not in good faith and without reasonable belief that the  Executive’s act, or failure to act, was in the best interests of the Company.  

(b)

From and after a Change in Control, (i) the willful and continued failure by the  Executive to substantially perform the  Executive’s duties with the Company (other than any such failure resulting from the  Executive’s incapacity due to physical or mental illness or any such actual or anticipated failure after the issuance of a Notice of Termination for Good Reason by the  Executive pursuant to Section 3 hereof) and/or (ii) the  Executive’s commission of one or more acts of moral turpitude that constitute a violation of applicable law (including but not limited to a felony) which have or result in an adverse effect on the Company, monetarily or otherwise, or one or more significant acts of dishonesty.  For purposes of clause (i) of this subsection (b), no act, or failure to act, on the  Executive’s part shall be deemed “willful” unless done, or omitted to be done, by the  Executive not in good faith and without reasonable belief that the  Executive’s act, or failure to act, was in the best interests of the Company.  Notwithstanding the foregoing, the  Executive shall not be deemed terminated for Cause pursuant to clause (i) of this subsection (b) unless and until the  Executive shall have been provided with reasonable notice of and, if possible, a reasonable opportunity to cure the facts and circumstances claimed to provide a basis for termination of the  Executive’s employment for Cause.

Change in Control” shall be deemed to have occurred on the date that a change in the ownership of Sempra Energy, a change in the effective control of Sempra Energy, or a change in the ownership of a substantial portion of assets of Sempra Energy occurs (each, as defined in subsection (a) below), except as otherwise provided in subsections (b), (c) and (d) below:

(a)

(i)

a “change in the ownership of Sempra Energy” occurs on the date that any one person, or more than one person acting as a group, acquires ownership of stock of Sempra Energy that, together with stock held by such person or group, constitutes more than fifty percent (50%) of the total fair market value or total voting power of the stock of Sempra Energy,

(ii)

a “change in the effective control of Sempra Energy” occurs only on either of the following dates:

(A)

the date any one person, or more than one person acting as a group, acquires (or has acquired during the twelve (12) month period ending on the date of the most recent acquisition by such person or persons) ownership of stock of Sempra Energy possessing thirty percent (30%) or more of the total voting power of the stock of Sempra Energy, or

(B)

the date a majority of the members of the Board is replaced during any twelve (12) month period by directors whose appointment or election is not endorsed by a majority of the members of the Board before the date of appointment or election, and

(iii)

a “change in the ownership of a substantial portion of assets of Sempra Energy” occurs on the date any one person, or more than one person acting as a group, acquires (or has acquired during the twelve (12) month period ending on the date of the most recent acquisition by such person or persons) assets from Sempra Energy that have a total gross fair market value equal to or more than eighty-five percent (85%) of the total gross fair market value of all of the assets of Sempra Energy immediately before such acquisition or acquisitions.

(b)

A “change in the ownership of Sempra Energy” or “a change in the effective control of Sempra Energy” shall not occur under clause (a)(i) or (a)(ii) by reason of any of the following:

(i)

an acquisition of ownership of stock of Sempra Energy directly from Sempra Energy or its Affiliates other than in connection with the acquisition by Sempra Energy or its Affiliates of a business,

(ii)

a merger or consolidation which would result in the voting securities of Sempra Energy outstanding immediately prior to such merger or consolidation continuing to represent (either by remaining outstanding or by being converted into voting securities of the surviving entity or any parent thereof), in combination with the ownership of any trustee or other fiduciary holding securities under an employee benefit plan of the Company, at least sixty percent (60%) of the combined voting power of the securities of Sempra Energy or such surviving entity or any parent thereof outstanding immediately after such merger or consolidation, or

(iii)

a merger or consolidation effected to implement a recapitalization of Sempra Energy (or similar transaction) in which no Person is or becomes the Beneficial Owner, directly or indirectly, of securities of Sempra Energy (not including the securities beneficially owned by such Person any securities acquired directly from Sempra Energy or its Affiliates other than in connection with the acquisition by Sempra Energy or its Affiliates of a business) representing twenty percent (20%) or more of the combined voting power of Sempra Energy’s then outstanding securities.

(c)

A “change in the ownership of a substantial portion of assets of Sempra Energy” shall not occur under clause (a)(iii) by reason of a sale or disposition by Sempra Energy of the assets of Sempra Energy to an entity, at least sixty percent (60%) of the combined voting power of the voting securities of which are owned by shareholders of Sempra Energy in substantially the same proportions as their ownership of Sempra Energy immediately prior to such sale.

(d)

This definition of “Change in Control” shall be limited to the definition of a “change in control event” relating to Sempra Energy under Treasury Regulation Section 1.409A-3(i)(5).  A “Change in Control” shall only occur if there is a “change in control event” relating to Sempra Energy under Treasury Regulation Section 1.409A-3(i)(5) with respect to the Executive.

Change in Control Date” means the date on which a Change in Control occurs.

Code” means the Internal Revenue Code of 1986, as amended.

Compensation Committee” means the compensation committee of the Board.

Consulting Period” has the meaning assigned thereto in Section 14(e) hereof.

Date of Termination” has the meaning assigned thereto in Section 3(b) hereof.

Deferred Compensation Plan” has the meaning assigned thereto in Section 5(f) hereof.

Disability” has the meaning set forth in the Company’s long-term disability plan or its successor; provided, however, that the Board may not terminate the  Executive’s employment hereunder by reason of Disability unless (i) at the time of such termination there is no reasonable expectation that the  Executive will return to work within the next ninety (90) day period and (ii) such termination is permitted by all applicable disability laws.  

Exchange Act” means the Securities Exchange Act of 1934, as amended, and the applicable rulings and regulations thereunder.

Excise Tax” has the meaning assigned thereto in Section 9(a) hereof.

Good Reason” means:

(a)

Prior to a Change in Control, the occurrence of any of the following without the prior written consent of the  Executive, unless such act or failure to act is corrected by the Company prior to the Date of Termination specified in the Notice of Termination (as required under Section 3 hereof):

(i)

the assignment to the  Executive of any duties materially inconsistent with the range of duties and responsibilities appropriate to a senior Executive within the Company (such range determined by reference to past, current and reasonable practices within the Company);

(ii)

a material reduction in the  Executive’s overall standing and responsibilities within the Company, but not including (A) a mere change in title or (B) a transfer within the Company, which, in the case of both (A) and (B), does not adversely affect the  Executive’s overall status within the Company;

(iii)

a material reduction by the Company in the  Executive’s aggregate annualized compensation and benefits opportunities, except for across-the-board reductions (or modifications of benefit plans) similarly affecting all similarly situated executives (both of the Company and of any Person then in control of the Company) of comparable rank with the  Executive;

(iv)

the failure by the Company to pay to the  Executive any portion of the  Executive’s current compensation and benefits or any portion of an installment of deferred compensation under any deferred compensation program of the Company within thirty (30) days of the date such compensation is due;

(v)

any purported termination of the  Executive’s employment that is not effected pursuant to a Notice of Termination satisfying the requirements of Section 3 hereof; for purposes of this Agreement, no such purported termination shall be effective;

(vi)

the failure by Sempra Energy to perform its obligations under Section 16(c), (d) or (e) hereof;

(vii)

the failure by the Company to provide the indemnification and D&O insurance protection Section 11 of this Agreement requires it to provide; or

(viii)

the failure by Sempra Energy to comply with any material provision of this Agreement.

(b)

From and after a Change in Control, the occurrence of any of the following without the prior written consent of the  Executive, unless such act or failure to act is corrected by the Company prior to the Date of Termination specified in the Notice of Termination (as required under Section 3 hereof):

(i)

an adverse change in the  Executive’s title, authority, duties, responsibilities or reporting lines as in effect immediately prior to the Change in Control;

(ii)

a reduction by the Company in the  Executive’s aggregate annualized compensation opportunities, except for across-the-board reductions in base salaries, annual bonus opportunities or long-term incentive compensation opportunities of less than ten percent (10%) similarly affecting all similarly situated executives (both of the Company and of any Person then in control of the Company) of comparable rank with the  Executive; or the failure by the Company to continue in effect any material benefit plan in which the  Executive participates immediately prior to the Change in Control, unless an equitable arrangement (embodied in an ongoing substitute or alternative plan) has been made with respect to such plan, or the failure by the Company to continue the  Executive's participation therein (or in such substitute or alternative plan) on a basis not materially less favorable, both in terms of the amount of benefits provided and the level of the  Executive's participation relative to other participants, as existed at the time of the Change in Control;

(iii)

the relocation of the  Executive’s principal place of employment immediately prior to the Change in Control Date (the “Principal Location”) to a location which is both further away from the  Executive’s residence and more than thirty (30) miles from such Principal Location, or the Company’s requiring the  Executive to be based anywhere other than such Principal Location (or permitted relocation thereof), or a substantial increase in the  Executive’s business travel obligations outside of the Southern California area as of the Effective Date other than any such increase that (A) arises in connection with extraordinary business activities of the Company of limited duration and (B) is understood not to be part of the  Executive’s regular duties with the Company;

(iv)

the failure by the Company to pay to the  Executive any portion of the  Executive’s current compensation and benefits or any portion of an installment of deferred compensation under any deferred compensation program of the Company within thirty (30) days of the date such compensation is due;

(v)

any purported termination of the  Executive’s employment that is not effected pursuant to a Notice of Termination satisfying the requirements of Section 3 hereof; for purposes of this Agreement, no such purported termination shall be effective;

(vi)

the failure by Sempra Energy to perform its obligations under Section 16(c), (d) or (e) hereof;

(vii)

the failure by the Company to provide the indemnification and D&O insurance protection Section 11 of this Agreement requires it to provide; or

(viii)

the failure by Sempra Energy to comply with any material provision of this Agreement.

Following a Change in Control, the  Executive’s determination that an act or failure to act constitutes Good Reason shall be presumed to be valid unless such determination is deemed to be unreasonable by an arbitrator pursuant to the procedure described in Section 13 hereof.  The  Executive’s right to terminate the  Executive’s employment for Good Reason shall not be affected by the  Executive’s incapacity due to physical or mental illness.  The  Executive’s continued employment shall not constitute consent to, or a waiver of rights with respect to, any act or failure to act constituting Good Reason hereunder.

Incentive Compensation Awards” means awards granted under Incentive Compensation Plans providing the  Executive with the opportunity to earn, on a year-by-year basis, annual and long-term incentive compensation.

Incentive Compensation Plans” means annual incentive compensation plans and long-term incentive compensation plans of the Company, which long-term incentive compensation plans may include plans offering stock options, restricted stock and other long-term incentive compensation.

Involuntary Termination” means (a) the  Executive’s Separation from Service by reason of a termination of employment by the Company other than for Cause, death, or Disability, or (b) the  Executive’s Separation from Service by reason of resignation of employment with the Company for Good Reason.    

JAMS Rules” has the meaning assigned thereto in Section 13 hereof.

Notice of Termination” has the meaning assigned thereto in Section 3(a) hereof.

Payment” has the meaning assigned thereto in Section 9(a) hereof.

Payment in Lieu of Notice” has the meaning assigned thereto in Section 3(b) hereof.

Person” has the meaning set forth in section 3(a)(9) of the Exchange Act, as modified and used in sections 13(d) and 14(d) thereof, except that such term shall not include (i) the Company or any of its Affiliates, (ii) a trustee or other fiduciary holding securities under an employee benefit plan of the Company or any of its Affiliates, (iii) an underwriter temporarily holding securities pursuant to an offering of such securities, (iv) a corporation owned, directly or indirectly, by the shareholders of the Company in substantially the same proportions as their ownership of stock of the Company, or (v) a person or group as used in Rule 13d-1(b) promulgated under the Exchange Act.

Post-Change in Control Accrued Obligations” has the meaning assigned thereto in Section 6(a) hereof.

Post-Change in Control Severance Payment” has the meaning assigned thereto in Section 6 hereof.

Pre-Change in Control Accrued Obligations” has the meaning assigned thereto in Section 5(a) hereof.

Pre-Change in Control Severance Payment” has the meaning assigned thereto in Section 5 hereof.

Principal Location” has the meaning assigned thereto in clause (b)(iii) of the definition of Good Reason, above.

Proprietary Information” has the meaning assigned thereto in Section 14(a) hereof.

Release” has the meaning assigned thereto in Section 14(d) hereof.

Section 409A Payments” means any of the following:  (a) the Payment in Lieu of Notice; (b) the Pre-Change in Control Severance Payment; (c) the Post-Change in Control Severance Payment; (d) the Additional Post-Change in Control Severance Payment; (e) the Consulting Payment; (f) the payment under Section 6(b) (but only to the extent such payment or portion thereof is subject to Section 409A of the Code); (g) the financial planning services and the related payments provided under Sections 5(e) and 6(f); and (h) the legal fees and expenses reimbursed under Section 15.

Sempra Energy Control Group” means Sempra Energy and all persons with whom Sempra Energy would be considered a single employer under Section 414(b) or 414(c) of the Code, as determined from time to time.

Separation from Service”, with respect to the  Executive (or another Service Provider), means the  Executive’s (or such Service Provider’s) (a) termination of employment or (b) other termination or reduction in services, provided that such termination or reduction in clause (a) or (b) constitutes a “separation from service,” as defined in Treasury Regulation Section 1.409A-1(h), with respect to the Service Recipient.

SERP” has the meaning assigned thereto in Section 6(b) hereof.

Service Provider” means the  Executive or any other “service provider,” as defined in Treasury Regulation Section 1.409A-1(f).

Service Recipient,” with respect to the  Executive, means Sempra Energy (if the Executive is employed by Sempra Energy), or the subsidiary of Sempra Energy employing the Executive, whichever is applicable, and all persons considered part of the “service recipient,” as defined in Treasury Regulation Section 1.409A-1(g), as determined from time to time.  As provided in Treasury Regulation Section 1.409A-1(g), the “Service Recipient” shall mean the person for whom the services are performed and with respect to whom the legally binding right to compensation arises, and all persons with whom such person would be considered a single employer under Section 414(b) or 414(c) of the Code.

Specified Employee” means a Service Provider who, as of the date of the Service Provider’s Separation from Service is a “Key Employee” of the Service Recipient any stock of which is publicly traded on an established securities market or otherwise.  For purposes of this definition, a Service Provider is a “Key Employee” if the Service Provider meets the requirements of Section 416(i)(1)(A)(i), (ii) or (iii) of the Code (applied in accordance with the Treasury Regulations thereunder and disregarding Section 416(i)(5) of the Code) at any time during the Testing Year.  If a Service Provider is a “Key Employee” (as defined above) as of a Specified Employee Identification Date, the Service Provider shall be treated as “Key Employee” for the entire twelve (12) month period beginning on the Specified Employee Effective Date.  For purposes of this definition, a Service Provider’s compensation for a Testing Year shall mean such Service Provider’s compensation, as determined under Treasury Regulation Section 1.415(c)-2(a) (and applied as if the Service Recipient were not using any safe harbor provided in Treasury Regulation Section 1.415(c)-2(d), were not using any of the elective special timing rules provided in Treasury Regulation Section 1.415(c)-2(e), and were not using any of the elective special rules provided in Treasury Regulation Section 1.415(c)-2(g)), from the Service Recipient for such Testing Year.  The “Specified Employees” shall be determined in accordance with Section 409A(a)(2)(B)(i) of the Code and Treasury Regulation Section 1.409A-1(i).

Specified Employee Effective Date” means the first day of the fourth month following the Specified Employee Identification Date.  The Specified Employee Effective Date may be changed by Sempra Energy, in its discretion, in accordance with Treasury Regulation Section 1.409A-1(i)(4).

Specified Employee Identification Date”, for purposes of Treasury Regulation Section 1.409A-1(i)(3), shall mean December 31.  The “Specified Employee Identification Date” shall apply to all “nonqualified deferred compensation plans” (as defined in Treasury Regulation Section 1.409A-1(a)) of the Service Recipient and all affected Service Providers.  The “Specified Employee Identification Date” may be changed by Sempra Energy, in its discretion, in accordance with Treasury Regulation Section 1.409A-1(i)(3).

Testing Year” shall mean the twelve (12) month period ending on the Specified Employee Identification Date, as determined from time to time.

Underpayment” has the meaning assigned thereto in Section 9(b) hereof.

For purposes of this Agreement, references to any “Treasury Regulation” shall mean such Treasury Regulation as in effect on the date hereof.

Section 2.

Sarbanes-Oxley Act of 2002.  Notwithstanding anything herein to the contrary, if the Company determines, in its good faith judgment, that any provision of this Agreement is likely to be interpreted as a personal loan prohibited by the Sarbanes-Oxley Act of 2002 and the rules and regulations promulgated thereunder (the “Act”), then such provision shall be modified as necessary or appropriate so as to not violate the Act; and if this cannot be accomplished, then the Company shall use its reasonable efforts to provide the  Executive with similar, but lawful, substitute benefit(s) at a cost to the Company not to significantly exceed the amount the Company would have otherwise paid to provide such benefit(s) to the  Executive.  In addition, if the  Executive is required to forfeit or to make any repayment of any compensation or benefit(s) to the Company under the Act or any other law, such forfeiture or repayment shall not constitute Good Reason.

Section 3.

Notice and Date of Termination.  

(a)

Any termination of the  Executive’s employment by the Company or by the  Executive shall be communicated by a written notice of termination to the other party (the “Notice of Termination”).  Where applicable, the Notice of Termination shall indicate the specific termination provision in this Agreement relied upon and shall set forth in reasonable detail the facts and circumstances claimed to provide a basis for termination of the  Executive’s employment under the provision so indicated.  Unless the Board determines otherwise, a Notice of Termination by the  Executive alleging a termination for Good Reason must be made within 180 days of the act or failure to act that the  Executive alleges to constitute Good Reason.  

(b)

The date of the  Executive’s termination of employment with the Company (the “Date of Termination”) shall be determined as follows:  (i) if the  Executive has a Separation from Service by reason of the Company terminating his or her employment, either with or without Cause, the Date of Termination shall be the date specified in the Notice of Termination (which, in the case of a termination by the Company other than for Cause, shall not be less than two (2) weeks from the date such Notice of Termination is given unless the Company elects to pay the  Executive, in addition to any other amounts payable hereunder, an amount (the “Payment in Lieu of Notice”) equal to two (2) weeks of the  Executive’s Annual Base Salary in effect on the Date of Termination), and (ii) if the basis for the  Executive’s Involuntary Termination is his resignation for Good Reason, the Date of Termination shall be determined by the  Executive and specified in the Notice of Termination, but shall not in any event be less than fifteen (15) days nor more than sixty (60) days after the date such Notice of Termination is given.   The Payment in Lieu of Notice shall be paid on such date as is determined by the Company within thirty (30) days after the date of the Executive’s Separation from Service; provided, however, that if the Executive is a Specified Employee on the date of his or her Separation from Service, such Payment in Lieu of Notice shall be paid as provided in Section 10 hereof.

Section 4.

Termination from the Board.  Upon the termination of the  Executive’s employment for any reason, the  Executive’s membership on the Board, the board of directors of any of the Company’s Affiliates, any committees of the Board and any committees of the board of directors of any of the Company’s Affiliates, if applicable, shall be automatically terminated.

Section 5.

Severance Benefits upon Involuntary Termination Prior to Change in Control.  Except as provided in Section 6 and Section 19(i) hereof, in the event of the Involuntary Termination of the  Executive prior to a Change in Control, the Company shall pay the  Executive, in one lump sum cash payment, an amount (the “Pre-Change in Control Severance Payment”) equal to one-half (0.5) times the greater of:  (X) 150% of the Executive’s Annual Base Salary as in effect on the Date of Termination, and (Y) the Executive’s Annual Base Salary as in effect on the Date of Termination, plus the Executive’s Average Annual Bonus.  In addition to the Pre-Change in Control Severance Payment, the  Executive shall be entitled to the following additional benefits specified in subsections (a) through (e).  Except as provided in Section 5(f), the Pre-Change in Control Severance Payment and the payment under Section 5(a) shall be paid on such date as is determined by the Company within thirty (30) days after the date of the Involuntary Termination; provided, however, that, if the  Executive is a Specified Employee on the date of the  Executive’s Involuntary Termination, the Pre-Change in Control Severance Payment and the financial planning services and the related payments provided under Section 5(e) shall be paid as provided in Section 10 hereof.  

(a)

Accrued Obligations.  The Company shall pay the  Executive a lump sum amount in cash equal to the sum of (A) the  Executive’s Annual Base Salary through the Date of Termination to the extent not theretofore paid, (B) an amount equal to any annual Incentive Compensation Awards earned with respect to fiscal years ended prior to the year that includes the Date of Termination to the extent not theretofore paid, (C) any accrued and unpaid vacation, if any, and (D) reimbursement for unreimbursed business expenses, if any, properly incurred by the  Executive in the performance of his duties in accordance with policies established from time to time by the Board, in each case to the extent not theretofore paid.  (The amounts specified in clauses (A), (B), (C) and (D) shall be hereinafter referred to as the “Pre-Change in Control Accrued Obligations”).

(b)

Equity Based Compensation.  The  Executive shall retain all rights to any equity-based compensation awards to the extent set forth in the applicable plan and/or award agreement.

(c)

Welfare Benefits.  Subject to Section 12 below, for a period of six (6) months following the date of the Involuntary Termination (and an additional twelve (12) months if the  Executive provides consulting services under Section 14(e) hereof), the  Executive and his dependents shall be provided with health insurance benefits substantially similar to those provided to the  Executive and his dependents immediately prior to the date of the Involuntary Termination; provided, however, that such benefits shall be provided on substantially the same terms and conditions and at the same cost to the  Executive as in effect immediately prior to the date of the Involuntary Termination.  Such benefits shall be provided through insurance maintained by the Company under the Company’s benefit plans.  Such benefits shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(a)(5).

(d)

Outplacement Services.  The  Executive shall receive reasonable outplacement services, on an in-kind basis, suitable to his position and directly related to the  Executive’s Involuntary Termination, for a period of eighteen (18) months following the date of the Involuntary Termination, in an aggregate amount of cost to the Company not to exceed $50,000.  Notwithstanding the foregoing, the  Executive shall cease to receive outplacement services on the date the  Executive accepts employment with a subsequent employer.  Such outplacement services shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(b)(9)(v)(A).

(e)

Financial Planning Services.  The  Executive shall receive financial planning services, on an in-kind basis, for a period of eighteen (18) months following the Date of Termination.  Such financial planning services shall include expert financial and legal resources to assist the Executive with financial planning needs and shall be limited to (i) current investment portfolio management, (ii) tax planning, (iii) tax return preparation, and (iv) estate planning advice and document preparation (including wills and trusts); provided, however, that the Company shall provide such financial planning services during any taxable year of the Executive only to the extent the cost to the Company for such taxable year does not exceed $25,000.  The Company shall provide such financial planning services through a financial planner selected by the Company, and shall pay the fees for such financial planning services.  The financial planning services provided during any taxable year of the  Executive shall not affect the financial planning services provided in any other taxable year of the  Executive.  The  Executive’s right to financial planning services shall not be subject to liquidation or exchange for any other benefit.  Such financial planning services shall be provided in a manner that complies with Treasury Regulation Section 1.409A-3(i)(1)(iv).  

(f)

Deferral of Payments.  The  Executive shall have the right to elect to defer the Pre-Change in Control Severance Payment to be received by the  Executive pursuant to this Section 5 under the terms and conditions of the Sempra Energy Employee and Director Savings Plan (the “Deferred Compensation Plan”).  Any such deferral election shall be made in accordance with Section 18(b) hereof.

Section 6.

Severance Benefits upon Involuntary Termination in Connection with and after Change in Control.  Notwithstanding the provisions of Section 5 above, and except as provided in Section 19(i) hereof, in the event of the Involuntary Termination of the  Executive on or within two (2) years following a Change in Control, in lieu of the payments described in Section 5 above, the Company shall pay the  Executive, in one lump sum cash payment, an amount (the “Post-Change in Control Severance Payment”) equal to the greater of:  (X)  150% of the Executive’s Annual Base Salary as in effect immediately prior to the Change in Control or the Date of Termination, whichever is greater, and (Y) the Executive’s Annual Base Salary as in effect immediately prior to the Change in Control or on the Date of Termination, whichever is greater, plus the Executive’s Average Annual Bonus.  In addition to the Post-Change in Control Severance Payment, the  Executive shall be entitled to the following additional benefits specified in subsections (a) through (f).  Except as provided in Sections 6(g) and 6(h), the Post-Change in Control Severance Payment and the payments under Sections 6(a) and (b) shall be paid on such date as is determined by the Company within thirty (30) days after the date of the Involuntary Termination; provided, however, that, if the  Executive is a Specified Employee on the date of the  Executive’s Involuntary Termination, the Post-Change in Control Severance Payment, the Additional Post-Change in Control Severance Payment under Section 6(a)(E), the payment under Section 6(b) (but only to the extent such payment or portion thereof is subject to Section 409A of the Code), and the financial planning services and the related payments provided under Section 6(f) shall be paid as provided in Section 10 hereof.

(a)

Accrued Obligations.  The Company shall pay the  Executive a lump sum amount in cash equal to the sum of (A) the  Executive’s Annual Base Salary through the Date of Termination to the extent not theretofore paid, (B) an amount equal to any annual Incentive Compensation Awards earned with respect to fiscal years ended prior to the year that includes the Date of Termination to the extent not theretofore paid, (C) any accrued and unpaid vacation, if any, (D) reimbursement for unreimbursed business expenses, if any, properly incurred by the  Executive in the performance of his duties in accordance with policies established from time to time by the Board, and (E) an amount (the “Additional Post-Change in Control Severance Payment”) equal to:  (i) the greater of:  (X) 50% of the Executive’s Annual Base Salary as in effect immediately prior to the Change in Control or on the Date of Termination, whichever is greater, or (Y) the Executive’s Average Annual Bonus, multiplied by (ii) a fraction, the numerator of which shall be the number of days from the beginning of such fiscal year to and including the Date of Termination and the denominator of which shall be 365, in the case of each amount described in clause (A), (B), (C) or (D) to the extent not theretofore paid.  (The amounts specified in clauses (A), (B), (C), (D) and (E) shall be hereinafter referred to as the “Post-Change in Control Accrued Obligations”).

(b)

Pension Supplement.  The  Executive shall be entitled to receive a Supplemental Retirement Benefit under the Sempra Energy Supplemental Executive Retirement Plan, as in effect from time to time (“SERP”), determined in accordance with this Section 6(b), in the event that the Executive is a “Participant” (as defined in the SERP) as of the Date of Termination.  Such Supplemental Retirement Benefit shall be determined by crediting the Executive with additional months of Service (if any) equal to the number of full calendar months from the Date of Termination to the date on which the Executive would have attained age 62.  The Executive shall be entitled to receive such Supplemental Retirement Benefit without regard to whether the Executive has attained age 55 or completed five years of “Service” (as defined in the SERP) as of the Date of Termination.  The Executive shall be treated as qualified for “Retirement” (as defined in the SERP) as of the Date of Termination, and the Executive’s Vesting Factor with respect to the Supplemental Retirement Benefit shall be 100%.  The Executive’s Supplemental Retirement Benefit shall be calculated based on the Executive’s actual age as of the date of commencement of payment of such Supplemental Retirement Benefit (the “SERP Distribution Date”), and by applying the applicable early retirement factors under the SERP, if the Executive has not attained age 62 but has attained age 55 as of the SERP Distribution Date.  If the Executive has not attained age 55 as of the SERP Distribution Date, the Executive’s Supplemental Retirement Benefit shall be calculated by applying the applicable early retirement factor under the SERP for age 55, and the Supplemental Retirement Benefit otherwise payable at age 55 shall be actuarially adjusted to the Executive’s actual age as of the SERP Distribution Date using the following actuarial assumptions:  (i) the applicable mortality table promulgated by the Internal Revenue Service under Section 417(e)(3) of the Code, as in effect on the first day of the calendar year in which the SERP Distribution Date occurs, and (ii) the applicable interest rate promulgated by the Internal Revenue Service under Section 417(a)(3) of the Code for the November next preceding the first day of the calendar year in which the SERP Distribution Date occurs.  The Executive’s Supplemental Retirement Benefit shall be determined in accordance with this Section 6(b), notwithstanding any contrary provisions of the SERP and, to the extent subject to Section 409A of the Code, shall be paid in accordance with Treasury Regulation Section 1.409A-3(c)(1).  The Supplemental Retirement Benefit paid to or on behalf of the Executive in accordance with this Section 6(b) shall be in full satisfaction of any and all of the benefits payable to or on behalf of the Executive under the SERP.  

(c)

Equity-Based Compensation.  Notwithstanding the provisions of any applicable equity-compensation plan or award agreement to the contrary, all equity-based Incentive Compensation Awards (including, without limitation, stock options, stock appreciation rights, restricted stock awards, restricted stock units, performance share awards, awards covered under Section 162(m) of the Code, and dividend equivalents) held by the  Executive shall immediately vest and become exercisable or payable, as the case may be, as of the Date of Termination, to be exercised or paid, as the case may be, in accordance with the terms of the applicable Incentive Compensation Plan and Incentive Compensation Award agreement, and any restrictions on any such Incentive Compensation Awards shall automatically lapse; provided, however, that any such stock option or stock appreciation rights awards granted on or after June 26, 1998 shall remain outstanding and exercisable until the earlier of (A) the later of eighteen  (18) months following the Date of Termination or the period specified in the applicable Incentive Compensation Award agreements or (B) the expiration of the original term of such Incentive Compensation Award (or, if earlier, the tenth anniversary of the original date of grant) (it being understood that all Incentive Compensation Awards granted prior to or after June 26, 1998 shall remain outstanding and exercisable for a period that is no less than that provided for in the applicable agreement in effect as of the date of grant).

(d)

Welfare Benefits.  Subject to Section 12 below, for a period of twelve (12) months following the date of Involuntary Termination (and an additional twelve (12) months if the Executive provides consulting services under Section 14(e) hereof), the  Executive and his dependents shall be provided with life, disability, accident and health insurance benefits substantially similar to those provided to the  Executive and his dependents immediately prior to the date of Involuntary Termination or the Change in Control Date, whichever is more favorable to the  Executive; provided, however, that such benefits shall be provided on substantially the same terms and conditions and at the same cost to the  Executive as in effect immediately prior to the date of Involuntary Termination or the Change in Control Date, whichever is more favorable to the  Executive.  Such benefits shall be provided through insurance maintained by the Company under the Company benefit plans.  Such benefits shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(a)(5).

(e)

Outplacement Services.  The  Executive shall receive reasonable outplacement services, on an in-kind basis, suitable to his position and directly related to the  Executive’s Involuntary Termination, for a period of twenty-four (24) months following the date of Involuntary Termination (but in no event beyond the last day of the  Executive’s second taxable year following the  Executive’s taxable year in which the Involuntary Termination occurs), in the aggregate amount of cost to the Company not to exceed $50,000.  Notwithstanding the foregoing, the  Executive shall cease to receive outplacement services on the date the  Executive accepts employment with a subsequent employer.  Such outplacement services shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(b)(9)(v)(A).

(f)

Financial Planning Services.  The  Executive shall receive financial planning services, on an in-kind basis, for a period of twenty-four (24) months following the date of Involuntary Termination.  Such financial planning services shall include expert financial and legal resources to assist the Executive with financial planning needs and shall be limited to (i) current investment portfolio management, (ii) tax planning, (iii) tax return preparation, and (iv) estate planning advice and document preparation (including wills and trusts); provided, however, that the Company shall provide such financial services during any taxable year of the Executive only to the extent the cost to the Company for such taxable year does not exceed $25,000.  The Company shall provide such financial planning services through a financial planner selected by the Company, and shall pay the fees for such financial planning services.  The financial planning services provided during any taxable year of the  Executive shall not affect the financial planning services provided in any other taxable year of the  Executive.  The  Executive’s right to financial planning services shall not be subject to liquidation or exchange for any other benefit.  Such financial planning services shall be provided in a manner that complies with Section 1.409A-3(i)(1)(iv).  

(g)

Involuntary Termination in Connection with a Change in Control.  Notwithstanding anything contained herein, in the event of an Involuntary Termination prior to a Change in Control, if the Involuntary Termination (1) was at the request of a third party who has taken steps reasonably calculated to effect such Change in Control or (2) otherwise arose in connection with or in anticipation of such Change in Control, then the  Executive shall, in lieu of the payments described in Section 5 hereof, be entitled to the Post-Change in Control Severance Payment and the additional benefits described in this Section 6 as if such Involuntary Termination had occurred within two (2) years following the Change in Control.  The amounts specified in Section 6 that are to be paid under this Section 6(g) shall be reduced by any amount previously paid under Section 5.  The amounts to be paid under this Section 6(g) shall be paid within thirty (30) days after the Change in Control Date of such Change in Control.

(h)

Deferral of Payments.  The  Executive shall have the right to elect to defer the Post-Change in Control Severance Payment to be received by the  Executive pursuant to this Section 6 under the terms and conditions of the Deferred Compensation Plan.  Any such deferral election shall be made in accordance with Section 18(b) hereof.

Section 7.

Severance Benefits upon Termination by the Company for Cause or by the  Executive Other than for Good Reason.  If the  Executive’s employment shall be terminated for Cause, or if the  Executive terminates employment other than for Good Reason, the Company shall have no further obligations to the  Executive under this Agreement other than the Pre-Change in Control Accrued Obligations and any amounts or benefits described in Section 11 hereof.

Section 8.

Severance Benefits upon Termination due to Death or Disability.  If the  Executive has a Separation from Service by reason of death or Disability, the Company shall pay the  Executive or his estate, as the case may be, the Post-Change in Control Accrued Obligations (without regard to whether a Change in Control has occurred) and any amounts or benefits described in Section 11 hereof.  Such payments shall be in addition to those rights and benefits to which the  Executive or his estate may be entitled under the relevant Company plans or programs.  Such payments shall be paid on such date as determined by the Company within thirty (30) days after the date of the Separation from Service; provided, however, that if the  Executive is a Specified Employee on the date of the  Executive’s Separation from Service by reason of Disability, the Additional Post-Change in Control Severance Payment under Section 6(a)(E) shall be paid as provided in Section 10 hereof.

Section 9.

Limitations on Payments by the Company.  

(a)

Anything in this Agreement to the contrary notwithstanding and except as set forth in this Section 9 below, in the event it shall be determined that any payment or distribution in the nature of compensation (within the meaning of Section 280G(b)(2) of the Code) to or for the benefit of the  Executive, whether paid or payable pursuant to this Agreement or otherwise (the “Payment”) would be subject (in whole or in part) to the excise tax imposed by Section 4999 of the Code, (the “Excise Tax”), then, subject to subsection (b), the Pre-Change in Control Severance Benefit or the Post-Change in Control Severance Payment (whichever is applicable) payable under this Agreement shall be reduced under this subsection (a) to the amount equal to the Reduced Payment.  For such Payment payable under this Agreement, the “Reduced Payment” shall be the amount equal to the greatest portion of the Payment (which may be zero)  that, if paid, would result in no portion of any Payment being subject to the Excise Tax.  

(b)

The Pre-Change in Control Severance Benefit or the Post-Change in Control Severance Payment (whichever is applicable) payable under this Agreement shall not be reduced under subsection (a) if:  

(i)

such reduction in such Payment is not sufficient to cause no portion of any Payment to be subject to the Excise Tax, or

(ii)

the Net After-Tax Unreduced Payments (as defined below) would equal or exceed one hundred and five percent (105%) of the Net After-Tax Reduced Payments (as defined below).  

For purposes of determining the amount of any Reduced Payment under subsection (a), and the Net-After Tax Reduced Payments and the Net After-Tax Unreduced Payments, the Executive shall be considered to pay federal, state and local income and employment taxes at the Executive’s applicable marginal rates taking into consideration any reduction in federal income taxes which could be obtained from the deduction of state and local income taxes, and any reduction or disallowance of itemized deductions and personal exemptions under applicable tax law).  The applicable federal, state and local income and employment taxes and the Excise Tax (to the extent applicable) are collectively referred to as the “Taxes”.

(c)

The following definitions shall apply for purposes of this Section 9:

(i)

“Net After-Tax Reduced Payments” shall mean the total amount of all Payments that the Executive would retain, on a Net After-Tax Basis, in the event that the Payments payable under this Agreement are reduced pursuant to subsection (a).

(ii)

“Net After-Tax Unreduced Payments” shall mean the total amount of all Payments that the Executive would retain, on a Net After-Tax Basis, in the event that the Payments payable under this Agreement are not reduced pursuant to subsection (a).

(iii)

“Net After-Tax Basis” shall mean, with respect to the Payments, either with or without reduction under subsection (a) (as applicable), the amount that would be retained by the Executive from such Payments after the payment of all Taxes.

(d)

All determinations required to be made under this Section 9 and the assumptions to be utilized in arriving at such determinations, shall be made by a nationally recognized accounting firm as may be agreed by the Company and the Executive (the “Accounting Firm”); provided, that the Accounting Firm’s determination shall be made based upon “substantial authority” within the meaning of Section 6662 of the Code.  The Accounting Firm shall provide detailed supporting calculations to both the Company and the Executive within fifteen (15) business days of the receipt of notice from the Executive that there has been a Payment or such earlier time as is requested by the Company.  All fees and expenses of the Accounting Firm shall be borne solely by the Company.  Any determination by the Accounting Firm shall be binding upon the Company and the Executive.  For purposes of determining whether and the extent to which the Payments will be subject to the Excise Tax, (i) no portion of the Payments the receipt or enjoyment of which the Executive shall have waived at such time and in such manner as not to constitute a “payment” within the meaning of Section 280G(b) of the Code shall be taken into account, (ii) no portion of the Payments shall be taken into account which, in the written opinion of the Accounting Firm, does not constitute a “parachute payment” within the meaning of Section 280G(b)(2) of the Code (including by reason of Section 280G(b)(4)(A) of the Code) and, in calculating the Excise Tax, no portion of such Payments shall be taken into account which, in the opinion of the Accounting Firm, constitutes reasonable compensation for services actually rendered, within the meaning of Section 280G(b)(4)(B) of the Code, in excess of the base amount (as defined in Section 280G(b)(3) of the Code) allocable to such reasonable compensation, and (iii) the value of any non-cash benefit or any deferred payment or benefit included in the Payments shall be determined by the Accounting Firm in accordance with the principles of Sections 280G(d)(3) and (4) of the Code.

Section 10.

Delayed Distribution under Section 409A of the Code.  If the  Executive is a Specified Employee on the date of the  Executive’s Involuntary Termination (or on the date of the Executive’s Separation from Service by reason of Disability), the Section 409A Payments, and any other payments or benefits under this Agreement subject to Section 409A of the Code, shall be delayed in order to avoid a prohibited distribution under Section 409A(a)(2)(B)(i) of the Code, and such payments or benefits shall be paid or distributed to the  Executive during the thirty (30) day period commencing on the earlier of (a) the expiration of the six-month period measured from the date of the  Executive’s Separation from Service or (b) the date of the Executive’s death.  Upon the expiration of the applicable six-month period under Section 409A(a)(2)(B)(i) of the Code, all payments deferred pursuant to this Section 10 (excluding in-kind benefits) shall be paid in a lump sum payment to the  Executive, plus interest thereon from the date of the  Executive’s Involuntary Termination through the payment date at an annual rate equal to Moody’s Rate.  The “Moody’s Rate” shall mean the average of the daily Moody’s Corporate Bond Yield Average – Monthly Average Corporates as published by Moody’s Investors Service, Inc. (or any successor) for the month next preceding the Date of Termination.  Any remaining payments due under the Agreement shall be paid as otherwise provided herein.

Section 11.

Nonexclusivity of Rights.  Nothing in this Agreement shall prevent or limit the  Executive’s continuing or future participation in any benefit, plan, program, policy or practice provided by the Company and for which the  Executive may qualify (except with respect to any benefit to which the  Executive has waived his rights in writing), including, without limitation, any and all indemnification arrangements in favor of the  Executive (whether under agreements or under the Company’s charter documents or otherwise), and insurance policies covering the  Executive, nor shall anything herein limit or otherwise affect such rights as the  Executive may have under any other contract or agreement entered into after the Effective Date with the Company.  Amounts which are vested benefits or which the  Executive is otherwise entitled to receive under any benefit, plan, policy, practice or program of, or any contract or agreement entered into with, the Company shall be payable in accordance with such benefit, plan, policy, practice or program or contract or agreement except as explicitly modified by this Agreement.  At all times during the  Executive’s employment with the Company and thereafter, the Company shall provide (to the extent permissible under applicable law) the  Executive with indemnification and D&O insurance insuring the  Executive against insurable events which occur or have occurred while the  Executive was a director or the Executive officer of the Company, on terms and conditions that are at least as generous as that then provided to any other current or former director or the Executive officer of the Company or any Affiliate.  Such indemnification and D&O insurance shall be provided in a manner that complies with Treasury Regulation Section 1.409A-1(b)(10).

Section 12.

Full Settlement; Mitigation.  The Company’s obligation to make the payments provided for in this Agreement and otherwise to perform its obligations hereunder shall not be affected by any set-off, counterclaim, recoupment, defense or other claim, right or action which the Company may have against the  Executive or others, provided that nothing herein shall preclude the Company from separately pursuing recovery from the  Executive based on any such claim.  In no event shall the  Executive be obligated to seek other employment or take any other action by way of mitigation of the amounts (including amounts for damages for breach) payable to the  Executive under any of the provisions of this Agreement, and such amounts shall not be reduced whether or not the  Executive obtains other employment.

Section 13.

Dispute Resolution.

Any disagreement, dispute, controversy or claim arising out of or relating to this Agreement or the interpretation of this Agreement or any arrangements relating to this Agreement or contemplated in this Agreement or the breach, termination or invalidity thereof shall be settled by final and binding arbitration administered by JAMS in San Diego, California in accordance with the then existing JAMS arbitration rules applicable to employment disputes (the “JAMS Rules”); provided that, notwithstanding any provision in such rules to the contrary, in all cases the parties shall be entitled to reasonable discovery.  In the event of such an arbitration proceeding, the  Executive and the Company shall select a mutually acceptable neutral arbitrator from among the JAMS panel of arbitrators.  In the event the  Executive and the Company cannot agree on an arbitrator, the arbitrator shall be selected in accordance with the then existing JAMS Rules.  Neither the  Executive nor the Company nor the arbitrator shall disclose the existence, content or results of any arbitration hereunder without the prior written consent of all parties, except to the extent necessary to enforce any arbitration award in a court of competent jurisdiction.  Except as provided herein, the Federal Arbitration Act shall govern the interpretation of, enforcement of and all proceedings under this agreement to arbitrate.  The arbitrator shall apply the substantive law (and the law of remedies, if applicable) of the state of California, or federal law, or both, as applicable, and the arbitrator is without jurisdiction to apply any different substantive law.  The arbitrator shall have the authority to entertain a motion to dismiss and/or a motion for summary judgment by any party and shall apply the standards governing such motions under the Federal Rules of Civil Procedure.  The arbitrator shall render an award and a written, reasoned opinion in support thereof.  Judgment upon the award may be entered in any court having jurisdiction thereof.  The  Executive shall not be required to pay any arbitration fee or cost that is unique to arbitration or greater than any amount he would be required to pay to pursue his claims in a court of competent jurisdiction.

Section 14.

Executive’s Covenants.    

(a)

Confidentiality.  The  Executive acknowledges that in the course of his employment with the Company, he has acquired non-public privileged or confidential information and trade secrets concerning the operations, future plans and methods of doing business (“Proprietary Information”) of the Company and its Affiliates; and the  Executive agrees that it would be extremely damaging to the Company and its Affiliates if such Proprietary Information were disclosed to a competitor of the Company and its Affiliates or to any other person or corporation.  The  Executive understands and agrees that all Proprietary Information has been divulged to the  Executive in confidence and further understands and agrees to keep all Proprietary Information secret and confidential (except for such information which is or becomes publicly available other than as a result of a breach by the  Executive of this provision or information the  Executive is required by any governmental, administrative or court order to disclose) without limitation in time.  In view of the nature of the  Executive’s employment and the Proprietary Information the  Executive has acquired during the course of such employment, the  Executive likewise agrees that the Company and its Affiliates would be irreparably harmed by any disclosure of Proprietary Information in violation of the terms of this paragraph and that the Company and its Affiliates shall therefore be entitled to preliminary and/or permanent injunctive relief prohibiting the  Executive from engaging in any activity or threatened activity in violation of the terms of this paragraph and to any other relief available to them.  Inquiries regarding whether specific information constitutes Proprietary Information shall be directed to the Company’s Senior Vice President, Public Policy (or, if such position is vacant, the Company’s then Chief Executive Officer); provided, that the Company shall not unreasonably classify information as Proprietary Information.

(b)

Non-Solicitation of Employees.  The  Executive recognizes that he possesses and will possess confidential information about other employees of the Company and its Affiliates relating to their education, experience, skills, abilities, compensation and benefits, and inter-personal relationships with customers of the Company and its Affiliates.  The  Executive recognizes that the information he possesses and will possess about these other employees is not generally known, is of substantial value to the Company and its Affiliates in developing their business and in securing and retaining customers, and has been and will be acquired by him because of his business position with the Company and its Affiliates.  The  Executive agrees that at all times during the  Executive’s employment with the Company and for a period of one (1) year thereafter, he will not, directly or indirectly, solicit or recruit any employee of the Company or its Affiliates for the purpose of being employed by him or by any competitor of the Company or its Affiliates on whose behalf he is acting as an agent, representative or employee and that he will not convey any such confidential information or trade secrets about other employees of the Company and its Affiliates to any other person; provided, however, that it shall not constitute a solicitation or recruitment of employment in violation of this paragraph to discuss employment opportunities with any employee of the Company or its Affiliates who has either first contacted the  Executive or regarding whose employment the  Executive has discussed with and received the written approval of the Company’s Vice President, Human Resources (or, if such position is vacant, the Company’s then Chief Executive Officer), prior to making such solicitation or recruitment.  In view of the nature of the  Executive’s employment with the Company, the  Executive likewise agrees that the Company and its Affiliates would be irreparably harmed by any solicitation or recruitment in violation of the terms of this paragraph and that the Company and its Affiliates shall therefore be entitled to preliminary and/or permanent injunctive relief prohibiting the  Executive from engaging in any activity or threatened activity in violation of the terms of this paragraph and to any other relief available to them.

(c)

Survival of Provisions.  The obligations contained in Section 14(a) and Section 14(b) above shall survive the termination of the  Executive’s employment within the Company and shall be fully enforceable thereafter.  If it is determined by a court of competent jurisdiction in any state that any restriction in Section 14(a) or Section 14(b) above is excessive in duration or scope or is unreasonable or unenforceable under the laws of that state, it is the intention of the parties that such restriction may be modified or amended by the court to render it enforceable to the maximum extent permitted by the law of that state.

(d)

Release; Lump Sum Payment.  In the event of the  Executive’s Involuntary Termination,  if the  Executive (i) agrees to the covenants described in Section 14(a) and Section 14(b) above, (ii) executes a release (the “Release”) of all claims substantially in the form attached hereto as Exhibit A within fifty (50) days after the date of Involuntary Termination and does not revoke such Release in accordance with the terms thereof, and (iii) agrees to provide the consulting services described in Section 14(e) below, then in consideration for such covenants, the Company shall pay the  Executive, in one cash lump sum, an amount (the “Consulting Payment”) in cash equal to the greater of:  (X) 150% of the Executive’s Annual Base Salary as in effect on the Date of Termination, and (Y) the Executive’s Annual Base Salary as in effect on the Date of Termination, plus the Executive’s Average Annual Bonus.  Except as provided in this subsection, the Consulting Payment shall be paid on such date as is determined by the Company within the ten (10) day period commencing on the 60th day after the date of the Executive’s Involuntary Termination; provided, however, that if the  Executive is a Specified Employee on the date of the  Executive’s Involuntary Termination, the Consulting Payment shall be paid as provided in Section 10 hereof.  The  Executive shall have the right to elect to defer the Consulting Payment under the terms and conditions of the Company’s Deferred Compensation Plan.  Any such deferral election shall be made in accordance with Section 18(b) hereof.

(e)

Consulting.  If the  Executive agrees to the covenants described in Section 14(d) above,  then the  Executive shall have the obligation to provide consulting services to the Company as an independent contractor, commencing on the Date of Termination and ending on the second anniversary of the Date of Termination (the “Consulting Period”).  The  Executive shall hold himself available at reasonable times and on reasonable notice to render such consulting services as may be so assigned to him by the Board or the Company’s then Chief Executive Officer; provided, however, that unless the parties otherwise agree, the consulting services rendered by the  Executive during the Consulting Period shall not exceed twenty (20) hours each month; and, provided, further, that the consulting services rendered by the  Executive during the Consulting Period shall in no event exceed twenty percent (20%) of the average level of services performed by the  Executive for the Company over the thirty-six (36) month period immediately preceding the  Executive’s Separation from Service (or the full period of services to the Company, if the  Executive has been providing services to the Company for less than thirty-six (36) months).  The Company agrees to use its best efforts during the Consulting Period to secure the benefit of the  Executive’s consulting services so as to minimize the interference with the  Executive’s other activities, including requiring the performance of consulting services at the Company’s offices only when such services may not be reasonably performed off-site by the  Executive.

Section 15.

Legal Fees.  

(a)

Reimbursement of Legal Fees.  Subject to subsection (b), in the event of the Executive’s Separation from Service either (1) prior to a Change in Control, or (2) on or within two (2) years following a Change in Control, the Company shall reimburse the  Executive for all legal fees and expenses (including but not limited to fees and expenses in connection with any arbitration) incurred by the  Executive in disputing any issue arising under this Agreement relating to the  Executive’s Separation from Service or in seeking to obtain or enforce any benefit or right provided by this Agreement.  

(b)

Requirements for Reimbursement.  The Company shall reimburse the  Executive’s legal fees and expenses pursuant to subsection (a) above only to the extent the arbitrator or court determines the following:  (i) the  Executive disputed such issue, or sought to obtain or enforce such benefit or right, in good faith, (ii) the  Executive had a reasonable basis for such claim, and (iii) in the case of subsection (a)(1) above, the  Executive is the prevailing party.  In addition, the Company shall reimburse such legal fees and expenses, only if such legal fees and expenses are incurred during the twenty (20) year period beginning on the date of the Executive’s Separation from Service.   The legal fees and expenses paid to the  Executive for any taxable year of the  Executive shall not affect the legal fees and expenses paid to the  Executive for any other taxable year of the  Executive.  The legal fees and expenses shall be paid to the Executive on or before the last day of the Executive’s taxable year following the taxable year in which the fees or expenses are incurred.  The  Executive’s right to reimbursement of legal fees and expenses shall not be subject to liquidation or exchange for any other benefit.  Such right to reimbursement of legal fees and expenses shall be provided in a manner that complies with Treasury Regulation Section 1.409A-3(i)(1)(iv).  If the Executive is a Specified Employee on the date of the Executive’s Separation from Service, such right to reimbursement of legal fees and expenses shall be paid as provided in Section 10 hereof.

Section 16.

Successors.

(a)

Assignment by the Executive.  This Agreement is personal to the  Executive and without the prior written consent of Sempra Energy shall not be assignable by the  Executive otherwise than by will or the laws of descent and distribution.  This Agreement shall inure to the benefit of and be enforceable by the  Executive’s legal representatives.

(b)

Successors and Assigns of Sempra Energy.  This Agreement shall inure to the benefit of and be binding upon Sempra Energy, its successors and assigns.  Sempra Energy may not assign this Agreement to any person or entity (except for a successor described in Section 16(c), (d) or (e) below) without the  Executive’s written consent.

(c)

Assumption.  Sempra Energy shall require any successor (whether direct or indirect, by purchase, merger, consolidation or otherwise) to all or substantially all of the business and/or assets of Sempra Energy to assume expressly and agree to perform the obligations and satisfy and discharge the liabilities of this Agreement in the same manner and to the same extent that Sempra Energy would have been required to perform the obligations and satisfy and discharge the liabilities under this Agreement if no such succession had taken place, and Sempra Energy shall have no further obligations and liabilities under this Agreement.  Upon such assumption, references to Sempra Energy in this Agreement shall be replaced with references to such successor.

(d)

Sale of Subsidiary.  In the event that (i) the Executive is employed by a direct or indirect subsidiary of Sempra Energy that is a member of the Sempra Energy Control Group, (ii) Sempra Energy, directly or indirectly through one or more intermediaries, sells or otherwise disposes of such subsidiary, and (iii) such subsidiary ceases to be a member of the Sempra Energy Control Group, then if, on the date such subsidiary ceases to be a member of the Sempra Energy Control Group, the Executive continues in employment with such subsidiary and the Executive does not have a Separation from Service, Sempra Energy shall require such subsidiary or any successor (whether direct or indirect, by purchase merger, consolidation or otherwise) to such subsidiary, or the parent thereof, to assume expressly and agree to perform the obligations and satisfy and discharge the liabilities under this Agreement in the same manner and to the same extent that Sempra Energy would have been required to perform the obligations and satisfy and discharge the liabilities under this Agreement, if such subsidiary had not ceased to be part of the Sempra Energy Control Group, and, upon such assumption, Sempra Energy shall have no further obligations and liabilities under the Agreement.  Upon such assumption, (i) references to Sempra Energy in this Agreement shall be replaced with references to such subsidiary, or such successor or parent thereof, assuming this Agreement, and (ii) subsection (b) of the definition of “Cause” and subsection (b) of the definition of “Good Reason” shall apply thereafter, as if a Change in Control had occurred on the date of such cessation.

(e)

Sale of Assets of Subsidiary.  In the event that (i) the Executive is employed by a direct or indirect subsidiary of Sempra Energy, and (ii) such subsidiary sells or otherwise disposes of substantial assets of such subsidiary to an unrelated service recipient, as determined under Treasury Regulation Section 1.409A-1(f)(2)(ii) (the “Asset Purchaser”), in a transaction described in Treasury Regulation Section 1.409A-1(h)(4) (an “Asset Sale”), then if, on the date of such Asset Sale, the Executive becomes employed by the Asset Purchaser, Sempra Energy and the Asset Purchaser shall specify, in accordance with Treasury Regulation Section 1.409A-1(h)(4), that the Executive shall not be treated as having a Separation from Service, and Sempra Energy shall require such Asset Purchaser, or the parent thereof, to assume expressly and agree to perform the obligations and satisfy and discharge the liabilities under this Agreement in the same manner and to the same extent that Sempra Energy would have been required to perform the obligations and satisfy and discharge the liabilities under this Agreement, if the Asset Sale had not taken place, and, upon such assumption, Sempra Energy shall have no further obligations and liabilities under the Agreement.  Upon such assumption, (i) references to Sempra Energy in this Agreement shall be replaced with references to the Asset Purchaser or the parent thereof, as applicable, and (ii) subsection (b) of the definition of “Cause” and subsection (b) of the definition of “Good Reason” shall apply thereafter, as if a Change in Control had occurred on the date of the Asset Sale.

Section 17.

Administration Prior to Change in Control.  Prior to a Change in Control, the Compensation Committee shall have full and complete authority to construe and interpret the provisions of this Agreement, to determine an individual’s entitlement to benefits under this Agreement, to make in its sole and absolute discretion all determinations contemplated under this Agreement, to investigate and make factual determinations necessary or advisable to administer or implement this Agreement, and to adopt such rules and procedures as it deems necessary or advisable for the administration or implementation of this Agreement.  All determinations made under this Agreement by the Compensation Committee shall be final and binding on all interested persons.  Prior to a Change in Control, the Compensation Committee may delegate responsibilities for the operation and administration of this Agreement to one or more officers or employees of the Company.  The provisions of this Section 17 shall terminate and be of no further force and effect upon the occurrence of a Change in Control.   

Section 18.

Section 409A of the Code.

(a)

Compliance with and Exemption from Section 409A of the Code.  Certain payments and benefits payable under this Agreement (including, without limitation, the Section 409A Payments) are intended to comply with the requirements of Section 409A of the Code.  Certain payments and benefits payable under this Agreement are intended to be exempt from the requirements of Section 409A of the Code.  This Agreement shall be interpreted in accordance with the applicable requirements of, and exemptions from, Section 409A of the Code and the Treasury Regulations thereunder.  To the extent the payments and benefits under this Agreement are subject to Section 409A of the Code, this Agreement shall be interpreted, construed and administered in a manner that satisfies the requirements of Sections 409A(a)(2), (3) and (4) of the Code and the Treasury Regulations thereunder (subject to the transitional relief under Internal Revenue Service Notice 2005-1, the Proposed Regulations under Section 409A of the Code, Internal Revenue Service Notice 2006-79, Internal Revenue Service Notice 2007-78, Internal Revenue Service Notice 2007-86 and other applicable authority issued by the Internal Revenue Service).  As provided in Internal Revenue Notice 2007-86, notwithstanding any other provision of this Agreement, with respect to an election or amendment to change a time or form of payment under this Agreement made on or after January 1, 2008 and on or before December 31, 2008, the election or amendment shall apply only with respect to payments that would not otherwise be payable in 2008, and shall not cause payments to be made in 2008 that would not otherwise be payable in 2008.  If the Company and the  Executive determine that any compensation, benefits or other payments that are payable under this Agreement and intended to comply with Sections 409A(a)(2), (3) and (4) of the Code do not comply with Section 409A of the Code, the Treasury Regulations thereunder and other applicable authority issued by the Internal Revenue Service, to the extent permitted under Section 409A of the Code, the Treasury Regulations thereunder and any applicable authority issued by the Internal Revenue Service, the Company and the  Executive agree to amend this Agreement, or take such other actions as the Company and the  Executive deem reasonably necessary or appropriate, to cause such compensation, benefits and other payments to comply with the requirements of Section 409A of the Code, the Treasury Regulations thereunder and other applicable authority issued by the Internal Revenue Service, while providing compensation, benefits and other payments that are, in the aggregate, no less favorable than the compensation, benefits and other payments provided under this Agreement.  In the case of any compensation, benefits or other payments that are payable under this Agreement and intended to comply with Sections 409A(a)(2), (3) and (4) of the Code, if any provision of the Agreement would cause such compensation, benefits or other payments to fail to so comply, such provision shall not be effective and shall be null and void with respect to such compensation, benefits or other payments to the extent such provision would cause a failure to comply, and such provision shall otherwise remain in full force and effect.

(b)

Deferral Elections.  As provided in Sections 5(f), 6(h) and 14(d), the  Executive may elect to defer the Pre-Change in Control Severance Payment, the Post-Change in Control Severance Payment and the Consulting Payment as follows.    The  Executive’s deferral election shall satisfy the requirements of Treasury Regulation Section 1.409A-2(b) and the terms and conditions of the Deferred Compensation Plan.  Such deferral election shall designate the whole percentage (up to a maximum of 100%) of the Pre-Change in Control Severance Payment, the Post-Change in Control Severance Payment and the Consulting Payment to be deferred, shall be irrevocable when made, and shall not take effect until at least twelve (12) months after the date on which the election is made.  Such deferral election shall provide that the amount deferred shall be deferred for a period of not less than five (5) years from the date the payment of the amount deferred would otherwise have been made, in accordance with Treasury Regulation Section 1.409A-2(b)(1)(ii).

Section 19.

Miscellaneous.

(a)

Governing Law.  This Agreement shall be governed by and construed in accordance with the laws of the State of California, without reference to its principles of conflict of laws.  The captions of this Agreement are not part of the provisions hereof and shall have no force or effect.  This Agreement may not be amended, modified, repealed, waived, extended or discharged except by an agreement in writing signed by the party against whom enforcement of such amendment, modification, repeal, waiver, extension or discharge is sought.  No person, other than pursuant to a resolution of the Board or a committee thereof, shall have authority on behalf of the Company to agree to amend, modify, repeal, waive, extend or discharge any provision of this Agreement or anything in reference thereto.

(b)

Notices.  All notices and other communications hereunder shall be in writing and shall be given by hand delivery to the other party or by registered or certified mail, return receipt requested, postage prepaid, addressed, in either case, to the Company’s headquarters or to such other address as either party shall have furnished to the other in writing in accordance herewith.  Notices and communications shall be effective when actually received by the addressee.

(c)

Severability.  The invalidity or unenforceability of any provision of this Agreement shall not affect the validity or enforceability of any other provision of this Agreement.

(d)

Taxes.  The Company may withhold from any amounts payable under this Agreement such federal, state or local taxes as shall be required to be withheld pursuant to any applicable law or regulation.

(e)

No Waiver.  The  Executive’s or the Company’s failure to insist upon strict compliance with any provision hereof or any other provision of this Agreement or the failure to assert any right the  Executive or the Company may have hereunder, including, without limitation, the right of the  Executive to terminate employment for Good Reason pursuant to Section 1 hereof, or the right of the Company to terminate the  Executive’s employment for Cause pursuant to Section 1 hereof shall not be deemed to be a waiver of such provision or right or any other provision or right of this Agreement.

(f)

Entire Agreement; Exclusive Benefit; Supersession of Prior Agreement.  This instrument contains the entire agreement of the  Executive, the Company or any predecessor or subsidiary thereof with respect to any severance or termination pay.  The Pre-Change in Control Severance Payment, the Post-Change in Control Severance Payment and all other benefits provided hereunder shall be in lieu of any other severance payments to which the  Executive is entitled under any other severance plan or program or arrangement sponsored by the Company, as well as pursuant to any individual employment or severance agreement that was entered into by the  Executive and the Company, and, upon the Effective Date of this Agreement, all such plans, programs, arrangements and agreements are hereby automatically superseded and terminated.  

(g)

No Right of Employment.  Nothing in this Agreement shall be construed as giving the  Executive any right to be retained in the employ of the Company or shall interfere in any way with the right of the Company to terminate the  Executive’s employment at any time, with or without Cause.

(h)

Unfunded Obligation.  The obligations under this Agreement shall be unfunded.  Benefits payable under this Agreement shall be paid from the general assets of the Company.  The Company shall have no obligation to establish any fund or to set aside any assets to provide benefits under this Agreement.

(i)

Termination upon Sale of Assets of Subsidiary.  Notwithstanding anything contained herein, this Agreement shall automatically terminate and be of no further force and effect and no benefits shall be payable hereunder in the event that (i) the Executive is employed by a direct or indirect subsidiary of Sempra Energy, and (ii) an Asset Sale (as defined in Section 16(e)) occurs (other than such a sale or disposition which is part of a transaction or series of transactions which would result in a Change in Control), and (iii) as a result of such Asset Sale, the  Executive is offered employment by the Asset Purchaser in an executive position with reasonably comparable status, compensation, benefits and severance agreement (including the assumption of this Agreement in accordance with Section 16(e)) and which is consistent with the  Executive’s experience and education, but the  Executive declines to accept such offer and the Executive fails to become employed by the Asset Purchaser on the date of the Asset Sale.  

(j)

Term.  The term of this Agreement shall commence on the Effective Date and shall continue until the third (3rd) anniversary of the Effective Date; provided, however, that commencing on the second (2nd) anniversary of the Effective Date (and each anniversary of the Effective Date thereafter), the term of this Agreement shall automatically be extended for one (1) additional year, unless at least ninety (90) days prior to such date, the Company or the  Executive shall give written notice to the other party that it or he, as the case may be, does not wish to so extend this Agreement.  Notwithstanding the foregoing, if the Company gives such written notice to the  Executive less than two (2) years after a Change in Control, the term of this Agreement shall be automatically extended until the later of (A) the date that is one (1) year after the anniversary of the Effective Date that follows such written notice or (B) the second (2nd) anniversary of the Change in Control Date.

(k)

Counterparts.  This Agreement may be executed in several counterparts, each of which shall be deemed to be an original but all of which together shall constitute one and the same instrument.


[remainder of page intentionally left blank]



Tier 2A Agreement

 OC\1056247.3


IN WITNESS WHEREOF, the  Executive and, pursuant to due authorization from its Board of Directors, the Company have caused this Agreement to be executed as of the day and year first above written.

SEMPRA ENERGY


Debra L. Reed

Chief Executive Officer


_____________________________________

Date


EXECUTIVE




G. Joyce Rowland

Sr. Vice President – Human Resources, Diversity and Inclusion


_____________________________________

Date




 OC\1056247.3




EXHIBIT A


GENERAL RELEASE

This GENERAL RELEASE (the “Agreement”), dated ___________, is made by and between ______________________________, a California corporation (the “Company”) and  ___________________________ (“you” or “your”).

WHEREAS, you and the Company have previously entered into that certain Severance Pay Agreement dated ____________, 20___ (the “Severance Pay Agreement”); and

WHEREAS, Section 14(d) of the Severance Pay Agreement provides for the payment of a benefit to you by the Company in consideration for certain covenants, including your execution and non-revocation of a general release of claims by you against the Company and its subsidiaries and affiliates.

NOW, THEREFORE, in consideration of the premises and the mutual covenants herein contained, you and the Company hereby agree as follows:

ONE:  Your signing of this Agreement confirms that your employment with the Company shall terminate at the close of business on ____________, or earlier upon our mutual agreement.

TWO:  As a material inducement for the payment of the benefit under Section 14(d) of the Severance Pay Agreement, and except as otherwise provided in this Agreement, you and the Company hereby irrevocably and unconditionally release, acquit and forever discharge the other from any and all Claims either may have against the other.  For purposes of this Agreement and the preceding sentence, the words “Releasee” or “Releasees” and “Claim” or “Claims” shall have the meanings set forth below:

(a)

The words “Releasee” or “Releasees” shall refer to you and to the Company and each of the Company’s owners, stockholders, predecessors, successors, assigns, agents, directors, officers, employees, representatives, attorneys, advisors, parent companies, divisions, subsidiaries, affiliates (and agents, directors, officers, employees, representatives, attorneys and advisors of such parent companies, divisions, subsidiaries and affiliates) and all persons acting by, through, under or in concert with any of them.

(b)

The words “Claim” or “Claims” shall refer to any charges, complaints, claims, liabilities, obligations, promises, agreements, controversies, damages, actions, causes of action, suits, rights, demands, costs, losses, debts and expenses (including attorneys’ fees and costs actually incurred) of any nature whatsoever, known or unknown, suspected or unsuspected, which you or the Company now, in the past or, except as limited by law or regulation such as the Age Discrimination in Employment Act (ADEA), in the future may have, own or hold against any of the Releasees; provided, however, that the word “Claim” or “Claims” shall not refer to any charges, complaints, claims, liabilities, obligations, promises, agreements, controversies, damages, actions, causes of action, suits, rights, demands, costs, losses, debts and expenses (including attorneys’ fees and costs actually incurred) arising under [identify severance, employee benefits, stock option, indemnification and D&O  and other agreements containing duties, rights obligations etc. of either party that are to remain operative].  Claims released pursuant to this Agreement by you and the Company include, but are not limited to, rights arising out of alleged violations of any contracts, express or implied, any tort, any claim that you failed to perform or negligently performed or breached your duties during employment at the Company, any legal restrictions on the Company’s right to terminate employees or any federal, state or other governmental statute, regulation, or ordinance, including, without limitation:  (1) Title VII of the Civil Rights Act of 1964 (race, color, religion, sex and national origin discrimination); (2) 42 U.S.C. § 1981 (discrimination); (3) 29 U.S.C. §§ 621–634 (age discrimination); (4) 29 U.S.C. § 206(d)(l) (equal pay); (5) 42 U.S.C. §§ 12101, et seq. (disability); (6) the California Constitution, Article I, Section 8 (discrimination); (7) the California Fair Employment and Housing Act (discrimination, including race, color, national origin, ancestry, physical handicap, medical condition, marital status, religion, sex or age); (8) California Labor Code Section 1102.1 (sexual orientation discrimination); (9) the Executive Order 11246 (race, color, religion, sex and national origin discrimination); (10) the Executive Order 11141 (age discrimination); (11) §§ 503 and 504 of the Rehabilitation Act of 1973 (handicap discrimination); (12) The Worker Adjustment and Retraining Act (WARN Act); (13) the California Labor Code (wages, hours, working conditions, benefits and other matters); (14) the Fair Labor Standards Act (wages, hours, working conditions and other matters); the Federal Employee Polygraph Protection Act (prohibits employer from requiring employee to take polygraph test as condition of employment); and (15) any federal, state or other governmental statute, regulation or ordinance which is similar to any of the statutes described in clauses (1) through (14).

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

“A GENERAL RELEASE DOES NOT EXTEND TO CLAIMS WHICH THE CREDITOR DOES NOT KNOW OR SUSPECT TO EXIST IN HIS FAVOR AT THE TIME OF EXECUTING THE RELEASE, WHICH IF KNOWN BY HIM MUST HAVE MATERIALLY AFFECTED HIS SETTLEMENT WITH THE DEBTOR.”

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

FOUR:  The parties acknowledge that they might hereafter discover facts different from, or in addition to, those they now know or believe to be true with respect to a Claim or Claims released herein, and they expressly agree to assume the risk of possible discovery of additional or different facts, and agree that this Agreement shall be and remain effective, in all respects, regardless of such additional or different discovered facts.

FIVE:  You hereby represent and acknowledge that you have not filed any Claim of any kind against the Company or others released in this Agreement.  You further hereby expressly agree never to initiate against the Company or others released in this Agreement any administrative proceeding, lawsuit or any other legal or equitable proceeding of any kind asserting any Claims that are released in this Agreement.

The Company hereby represents and acknowledges that it has not filed any Claim of any kind against you or others released in this Agreement.  The Company further hereby expressly agrees never to initiate against you or others released in this Agreement any administrative proceeding, lawsuit or any other legal or equitable proceeding of any kind asserting any Claims that are released in this Agreement.

SIX:  You hereby represent and agree that you have not assigned or transferred, or attempted to have assigned or transfer, to any person or entity, any of the Claims that you are releasing in this Agreement.

The Company hereby represents and agrees that it has not assigned or transferred, or attempted to have assigned or transfer, to any person or entity, any of the Claims that it is releasing in this Agreement.

SEVEN:  As a further material inducement to the Company to enter into this Agreement, you hereby agree to indemnify and hold each of the Releasees harmless from all loss, costs, damages, or expenses, including without limitation, attorneys’ fees incurred by the Releasees, arising out of any breach of this Agreement by you or the fact that any representation made in this Agreement by you was false when made.

As a further material inducement to you to enter into this Agreement, the Company hereby agrees to indemnify and hold each of the Releasees harmless from all loss, costs, damages, or expenses, including without limitation, attorneys’ fees incurred by the Releasees, arising out of any breach of this Agreement by it or the fact that any representation made in this Agreement by it was knowingly false when made.

EIGHT:  You and the Company represent and acknowledge that in executing this Agreement, neither is relying upon any representation or statement not set forth in this Agreement or the Severance Agreement.

NINE:

(a)

This Agreement shall not in any way be construed as an admission by the Company that it has acted wrongfully with respect to you or any other person, or that you have any rights whatsoever against the Company, and the Company specifically disclaims any liability to or wrongful acts against you or any other person, on the part of itself, its employees or its agents.  This Agreement shall not in any way be construed as an admission by you that you have acted wrongfully with respect to the Company, or that you failed to perform your duties or negligently performed or breached your duties, or that the Company had good cause to terminate your employment.

(b)

If you are a party or are threatened to be made a party to any proceeding by reason of the fact that you were an officer or director of the Company, the Company shall indemnify you against any expenses (including reasonable attorneys’ fees; provided, that counsel has been approved by the Company prior to retention, which approval shall not be unreasonably withheld), judgments, fines, settlements and other amounts actually or reasonably incurred by you in connection with that proceeding; provided, that you acted in good faith and in a manner you reasonably believed to be in the best interest of the Company.  The limitations of California Corporations Code Section 317 shall apply to this assurance of indemnification.

(c)

You agree to cooperate with the Company and its designated attorneys, representatives and agents in connection with any actual or threatened judicial, administrative or other legal or equitable proceeding in which the Company is or may become involved.  Upon reasonable notice, you agree to meet with and provide to the Company or its designated attorneys, representatives or agents all information and knowledge you have relating to the subject matter of any such proceeding.  The Company agrees to reimburse you for any reasonable costs you incur in providing such cooperation.

TEN:  This Agreement is made and entered into in California.  This Agreement shall in all respects be interpreted, enforced and governed by and under the laws of the State of California and applicable Federal law.  Any dispute about the validity, interpretation, effect or alleged violation of this Agreement (an “arbitrable dispute”) must be submitted to arbitration in San Diego, California.  Arbitration shall take place before an experienced employment arbitrator licensed to practice law in such state and selected in accordance with the then existing JAMS arbitration rules applicable to employment disputes; provided, however, that in any event, the arbitrator shall allow reasonable discovery.  Arbitration shall be the exclusive remedy for any arbitrable dispute.  The arbitrator in any arbitrable dispute shall not have authority to modify or change the Agreement in any respect.  You and the Company shall each be responsible for payment of one-half (1/2) the amount of the arbitrator’s fee(s); provided, however, that in no event shall you be required to pay any fee or cost of arbitration that is unique to arbitration or exceeds the costs you would have incurred had any arbitrable dispute been pursued in a court of competent jurisdiction.  The Company shall make up any shortfall.  Should any party to this Agreement institute any legal action or administrative proceeding against the other with respect to any Claim waived by this Agreement or pursue any arbitrable dispute by any method other than arbitration, the prevailing party shall be entitled to recover from the non-prevailing party all damages, costs, expenses and attorneys’ fees incurred as a result of that action.  The arbitrator’s decision and/or award shall be rendered in writing and will be fully enforceable and subject to an entry of judgment by the Superior Court of the State of California for the County of San Diego, or any other court of competent jurisdiction.

ELEVEN:  Both you and the Company understand that this Agreement is final and binding eight (8) days after its execution and return.  Should you nevertheless attempt to challenge the enforceability of this Agreement as provided in Paragraph TEN or, in violation of that Paragraph, through litigation, as a further limitation on any right to make such a challenge, you shall initially tender to the Company, by certified check delivered to the Company, all monies received pursuant to Section 14(d) of the Severance Pay Agreement, plus interest, and invite the Company to retain such monies and agree with you to cancel this Agreement and void the Company’s obligations under Section 14(d) of the Severance Pay Agreement.  In the event the Company accepts this offer, the Company shall retain such monies and this Agreement shall be canceled and the Company shall have no obligation under Section 14(d) of the Severance Pay Agreement.  In the event the Company does not accept such offer, the Company shall so notify you and shall place such monies in an interest-bearing escrow account pending resolution of the dispute between you and the Company as to whether or not this Agreement and the Company’s obligations under Section 14(d) of the Severance Pay Agreement shall be set aside and/or otherwise rendered voidable or unenforceable.  Additionally, any consulting agreement then in effect between you and the Company shall be immediately rescinded with no requirement of notice.

TWELVE:  Any notices required to be given under this Agreement shall be delivered either personally or by first class United States mail, postage prepaid, addressed to the respective parties as follows:

To Company:

[TO COME]

Attn:  [TO COME]

To You:

______________________

______________________

______________________

THIRTEEN:  You understand and acknowledge that you have been given a period of forty-five (45) days to review and consider this Agreement (as well as statistical data on the persons eligible for similar benefits) before signing it and may use as much of this forty-five (45) day period as you wish prior to signing.  You are encouraged, at your personal expense, to consult with an attorney before signing this Agreement.  You understand and acknowledge that whether or not you do so is your decision.  You may revoke this Agreement within seven (7) days of signing it.  If you wish to revoke, the Company’s Vice President, Human Resources must receive written notice from you no later than the close of business on the seventh (7th) day after you have signed the Agreement.  If revoked, this Agreement shall not be effective and enforceable, and you will not receive payments or benefits under Section 14(d) of the Severance Pay Agreement.

FOURTEEN:  This Agreement constitutes the entire agreement of the parties hereto and supersedes any and all other agreements (except the Severance Pay Agreement) with respect to the subject matter of this Agreement, whether written or oral, between you and the Company.  All modifications and amendments to this Agreement must be in writing and signed by the parties.

FIFTEEN:  Each party agrees, without further consideration, to sign or cause to be signed, and to deliver to the other party, any other documents and to take any other action as may be necessary to fulfill the obligations under this Agreement.

SIXTEEN:  If any provision of this Agreement or the application thereof is held invalid, the invalidity shall not affect other provisions or applications of the Agreement which can be given effect without the invalid provisions or application; and to this end the provisions of this Agreement are declared to be severable.

SEVENTEEN:  This Agreement may be executed in counterparts.

I have read the foregoing General Release, and I accept and agree to the provisions it contains and hereby execute it voluntarily and with full understanding of its consequences.  I am aware it includes a release of all known or unknown claims.

DATED:  __________

__________________________________________

DATED:  __________

__________________________________________

You acknowledge that you first received this Agreement on [date].

_________________________







 OC\1056247.3


Exhibit 10.70


Exhibit 10.70


AMENDMENT NO. 8

TO THE

SAN DIEGO GAS & ELECTRIC COMPANY

NUCLEAR FACILITIES QUALIFIED CPUC DECOMMISSIONING

MASTER TRUST AGREEMENT

FOR

SAN ONOFRE NUCLEAR GENERATING STATIONS



This Amendment No. 8 made this _______ day of ____________, 2011, by and between San Diego Gas & Electric Company (“Company”) and The Bank of New York Mellon, a New York state bank, successor by operation of law to Mellon Bank, N.A (“Trustee”).

WHEREAS, pursuant to Section 2.12 of the Nuclear Facilities Qualified Decommissioning Master Trust for San Onofre Nuclear Generating Stations dated as of June 29, 1992, as amended (“Agreement”) between the Company and the Trustee, the parties specifically reserve the right to amend the Agreement;

NOW, THEREFORE, the Company and the Trustee agree as follows:

1.

Section 2.02 of the Agreement is hereby deleted in its entirety and restated to read as follows:

Additions to Master Trust.  From time to time after the initial contribution to the Master Trust and prior to the termination of this Master Trust, the Company may make, and the Trustee shall accept, additional contributions to the Master Trust of money and/or securities, to the extent permitted under Section 468A of the Code, to satisfy the purpose of this Master Trust as set forth in Section 1.03, which contributions may be made to the applicable Fund Account(s).  With respect to amounts received as a transfer from the San Diego Gas & Electric Company Nuclear Facilities Non-Qualified CPUC Decommissioning Master Trust for San Onofre Nuclear Generating Stations (the “Non-Qualified Master Trust”) to this Master Trust, such amounts attributable to a particular Unit or Fund under the Non-Qualified Master Trust shall be allocated to the same Unit or Fund under this Master Trust.”

2.

Section 2.03 of the Agreement is hereby deleted in its entirety and restated to read as follows:

Adjustments for Excess Contributions.  The Trustee and the Company understand and agree that the contributions made by the Company to any of the Funds from time to time may exceed the amount permitted to be paid into such funds(s) pursuant to Section 468A of the Code and any regulations thereunder based upon changes in estimates, subsequent developments, or any other event or occurrence which could not reasonably have been foreseen by the Company at the time such contribution was made (Excess Contribution).  With respect to any Excess Contribution, the Trustee shall make (i) transfers from the Master Trust to the San Diego Gas & Electric Company Nuclear Facilities Non-Qualified CPUC Decommissioning Master Trust for the San Onofre Nuclear Generating Stations or (ii) withdrawals from the Master Trust to the Company, as the case may be, upon a presentation of a certificate substantially in the form of Exhibit E, instructing the Trustee to make such payment from the Master Trust to the San Diego Gas & Electric Company Nuclear Facilities Non-Qualified CPUC Decommissioning Master Trust for the San Onofre Nuclear Generating Stations, or substantially in the form of Exhibit F, instructing the Trustee to make such payment from the Master Trust to the Company.  The Trustee shall be fully protected in relying upon such certificate.”

3.

Section 2.04 of the Agreement is amended by adding the following language to the end thereof:

“Notwithstanding the preceding sentence or anything else in this Master Trust to the contrary, monies or securities can be transferred from the Master Trust to the San Diego Gas & Electric Company Nuclear Facilities Non-Qualified CPUC Decommissioning Master Trust for the San Onofre Nuclear Generating Stations to the extent permitted by Section 468A of the Code and directed by the Company upon presentation of a certificate substantially in the form of Exhibit E.”

4.

Each Party hereby represents and warrants to the others that it has full authority to enter into this Amendment No. 8 upon the terms and conditions hereof and that the individual executing this Amendment No. 8 on its behalf has the requisite authority to bind that Party.

[Signatures to follow]







IN WITNESS WHEREOF, the Company, the Trustee, and the California Public Utilities Commission have set their hands and seals in agreement to these amendments effective as provided above.



SAN DIEGO GAS & ELECTRIC COMPANY



By:

________________________________________


Date:

________________________________________


Attest:

________________________________________





THE BANK OF NEW YORK MELLON



By:

________________________________________


Date:

________________________________________


Attest:

________________________________________





CALIFORNIA PUBLIC UTILITIES COMMISSION



By:

________________________________________


Date:

________________________________________


Attest:

________________________________________








Exhibit E

CERTIFICATE FOR TRANSFER FROM THE QUALIFIED FUND
TO THE NON-QUALIFIED FUND


The Bank of New York Mellon, as Trustee
[Address]

This Certificate is submitted pursuant to Section 2.03 and Section 2.04 of the San Diego Gas & Electric Company Nuclear Facilities Qualified CPUC Decommissioning Master Trust for San Onofre Nuclear Generating Stations, dated __________.  All capitalized terms used in this Certificate and not otherwise defined herein shall have the meanings assigned to such terms in the Master Trust.  In your capacity as Trustee, you are hereby authorized and instructed as follows (complete one):

To pay $______________ in cash and the securities identified on the schedule attached hereto from the [Unit name’s] qualified fund to that Unit’s nonqualified fund.

With respect to such payment, the undersigned, being an Authorized Representative of San Diego Gas & Electric Company (“Company”), a California corporation, and, in such capacity, being authorized and empowered to execute and deliver this certificate, hereby certifies to the Trustee of the San Diego Gas & Electric Company Nuclear Facilities Qualified CPUC Decommissioning Master Trust for San Onofre Nuclear Generating Stations, pursuant to Section 2.03 and Section 2.04 of the Master Trust, as follows:

1.

Any amount stated herein to be paid from the San Diego Gas & Electric Company Nuclear Facilities Qualified CPUC Decommissioning Master Trust to the San Diego Gas & Electric Company Nuclear Facilities Non-Qualified CPUC Decommissioning Master Trust is an Excess Contribution as set forth in Section 2.03 of the Master Trust.

[Signature to follow]





IN WITNESS WHEREOF, the undersigned have executed this Certificate in the capacity as shown below as of _______________, ________.


By: _____________________________________
     Authorized Representative






Exhibit F

CERTIFICATE FOR WITHDRAWAL OF EXCESS CONTRIBUTION


The Bank of New York Mellon, as Trustee
[Address]

This Certificate is submitted pursuant to Section 2.03 of the San Diego Gas & Electric Company Nuclear Facilities Qualified CPUC Decommissioning Master Trust for San Onofre Nuclear Generating Stations, dated _______.  All capitalized terms used in this Certificate and not otherwise defined herein shall have the meanings assigned to such terms in the Master Trust.  In your capacity as Trustee, you are hereby authorized and instructed to pay $_____________ in cash and the securities identified on the schedule attached hereto to the Company from the Master Trust.  

With respect to such payment, the undersigned, being an Authorized Representative of San Diego Gas & Electric Company (“Company”), a California corporation, and, in such capacity, being authorized and empowered to execute and deliver this certificate, hereby certifies to the Trustee of the San Diego Gas & Electric Company Nuclear Facilities Qualified CPUC Decommissioning Master Trust for San Onofre Nuclear Generating Stations, pursuant to Section 2.03 of the Master Trust, that withdrawal pursuant to Section 2.03 of the Master Trust is appropriate and that $___________ and securities constitutes an Excess Contribution pursuant to Section 2.03 of the Master Trust.

IN WITNESS WHEREOF, the undersigned have executed this Certificate in the capacity as shown below as of _______________, ________.


By: _____________________________________
     Authorized Representative






Exhibit 10.77


Exhibit 10.77


AMENDMENT NO. 6

TO THE

SAN DIEGO GAS & ELECTRIC COMPANY

NUCLEAR FACILITIES NON-QUALIFIED CPUC DECOMMISSIONING

MASTER TRUST AGREEMENT

FOR

SAN ONOFRE NUCLEAR GENERATING STATIONS



This Amendment No. 6 made this _______ day of ____________, 2011, by and between San Diego Gas & Electric Company (“Company”) and The Bank of New York Mellon, a New York state bank, successor by operation of law to Mellon Bank, N.A (“Trustee”).

WHEREAS, pursuant to Section 2.10 of the Nuclear Facilities Non-Qualified Decommissioning Master Trust for San Onofre Nuclear Generating Stations dated as of June 29, 1992, as amended (“Agreement”) between the Company and the Trustee, the parties specifically reserve the right to amend the Agreement;

NOW, THEREFORE, the Company and the Trustee agree as follows:

1.

Section 2.03 of the Agreement is hereby amended by adding the following language to the end thereof:

“Notwithstanding the preceding sentence or anything else in this Master Trust to the contrary, monies or securities can be transferred from the Master Trust to the San Diego Gas & Electric Company Nuclear Facilities Qualified CPUC Decommissioning Master Trust for the San Onofre Nuclear Generating Stations to the extent permitted by Section 468A of the Code and directed by the Company upon a presentation of a certificate substantially in the form of Exhibit E.  The Trustee shall be fully protected in relying upon such certificate.”

2.

Each Party hereby represents and warrants to the others that it has full authority to enter into this Amendment No. 6 upon the terms and conditions hereof and that the individual executing this Amendment No. 6 on its behalf has the requisite authority to bind that Party.

[Signatures to follow]






IN WITNESS WHEREOF, the Company, the Trustee, and the California Public Utilities Commission have set their hands and seals in agreement to these amendments effective as provided above.



SAN DIEGO GAS & ELECTRIC COMPANY



By:

________________________________________


Date:

________________________________________


Attest:

________________________________________





THE BANK OF NEW YORK MELLON



By:

________________________________________


Date:

________________________________________


Attest:

________________________________________





CALIFORNIA PUBLIC UTILITIES COMMISSION



By:

________________________________________


Date:

________________________________________


Attest:

________________________________________







Exhibit E

CERTIFICATE FOR TRANSFER  FROM THE NON-QUALIFIED FUND
TO THEQUALIFIED FUND


The Bank of New York Mellon, as Trustee
[Address]

This Certificate is submitted pursuant to Section 2.03 of the San Diego Gas & Electric Company Nuclear Facilities Non-Qualified CPUC Decommissioning Master Trust for San Onofre Nuclear Generating Stations, dated __________.  All capitalized terms used in this Certificate and not otherwise defined herein shall have the meanings assigned to such terms in the Master Trust.  In your capacity as Trustee, you are hereby authorized and instructed as follows (complete one):

To pay $______________ in cash and the securities identified on the schedule attached hereto from the [Unit name’s] nonqualified fund to that Unit’s qualified fund; or

With respect to such payment, the undersigned, being an Authorized Representative of San Diego Gas & Electric Company (“Company”), a California corporation, and, in such capacity, being authorized and empowered to execute and deliver this certificate, hereby certifies to the Trustee of the San Diego Gas & Electric Company Nuclear Facilities Non-Qualified CPUC Decommissioning Master Trust for San Onofre Nuclear Generating Stations, pursuant to Section 2.03 of the Master Trust, as follows:

1.

Any amount stated herein to be paid from the San Diego Gas & Electric Company Nuclear Facilities Non-Qualified CPUC Decommissioning Master Trust to the San Diego Gas & Electric Company Nuclear Facilities Qualified CPUC Decommissioning Master Trust is in accordance with the rules of section 468A of the Code and the regulations thereunder.

 [Signature to follow]





IN WITNESS WHEREOF, the undersigned have executed this Certificate in the capacity as shown below as of _______________, ________.


By: _____________________________________
     Authorized Representative








Exhibit 12.1




EXHIBIT 12.1

SEMPRA ENERGY

COMPUTATION OF RATIO OF EARNINGS TO COMBINED FIXED CHARGES

AND PREFERRED STOCK DIVIDENDS

(Dollars in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

2007 

 

2008 

 

2009

 

2010

 

2011

Fixed charges and preferred stock dividends:

 

 

 

 

 

 

 

 

 

 

Interest

 

$ 379

 

$ 353

 

$ 455

 

$ 492

 

$ 549

Interest portion of annual rentals

 

6

 

3

 

2

 

3

 

2

Preferred dividends of subsidiaries (1)

 

14

 

13

 

13

 

11

 

10

     Total fixed charges

 

399

 

369

 

470

 

506

 

561

Preferred dividends for purpose of ratio

 

-

 

-

 

-

 

-

 

-

Total fixed charges and preferred dividends for purpose of ratio                        

 

$ 399

 

$ 369

 

$ 470

 

$ 506

 

$ 561

Earnings:

 

 

 

 

 

 

 

 

 

 

Pretax income from continuing operations before adjustment for income or loss from equity investees

 

$ 1,538

 

$ 1,009

 

$ 977

 

$ 1,078

 

$ 1,745

Add:

 

 

 

 

 

 

 

 

 

 

  Total fixed charges (from above)

 

399

 

369

 

470

 

506

 

561

  Distributed income of equity investees

 

19

 

133

 

493

 

260

 

96

Less:

 

 

 

 

 

 

 

 

 

 

  Interest capitalized

 

100

 

100

 

73

 

74

 

27

  Preferred dividends of subsidiaries (1)

 

10

 

10

 

13

 

11

 

10

Total earnings for purpose of ratio

 

$ 1,846

 

$ 1,401

 

$ 1,854

 

$ 1,759

 

$ 2,365

 

 

 

 

 

 

 

 

 

 

 

Ratio of earnings to combined fixed charges and preferred stock dividends

 

4.63

 

3.80

 

3.94

 

3.48

 

4.22

 

 

 

 

 

 

 

 

 

 

 

Ratio of earnings to fixed charges

 

4.63

 

3.80

 

3.94

 

3.48

 

4.22

 

 

 

 

 

 

 

 

 

 

 

 

(1)

In computing this ratio, “Preferred dividends of subsidiaries” represents the before-tax earnings necessary to pay such dividends, computed at the effective tax rates for the applicable periods.











Exhibit 12.2




EXHIBIT 12.2

SAN DIEGO GAS & ELECTRIC COMPANY

COMPUTATION OF RATIO OF EARNINGS TO COMBINED FIXED CHARGES

AND PREFERRED STOCK DIVIDENDS

(Dollars in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

2007 

 

2008 

 

2009 

 

2010 

 

2011 

Fixed Charges and Preferred Stock Dividends:

 

 

 

 

 

 

 

 

 

 

Interest

 

$ 105

 

$ 107

 

$ 118

 

$ 153

 

$ 193

Interest portion of annual rentals

 

3

 

1

 

1

 

1

 

1

Total fixed charges

 

108

 

108

 

119

 

154

 

194

Preferred stock dividends (1)

 

7

 

7

 

7

 

7

 

7

Combined fixed charges and preferred stock dividends for purpose of ratio

 

$ 115

 

$ 115

 

$ 126

 

$ 161

 

$ 201

Earnings:

 

 

 

 

 

 

 

 

 

 

Pretax income from continuing operations

 

$ 406

 

$ 451

 

$ 550

 

$ 531

 

$ 692

Total fixed charges (from above)

 

108

 

108

 

119

 

154

 

194

Less: Interest capitalized

 

3

 

13

 

4

 

1

 

1

Total earnings for purpose of ratio

 

$ 511

 

$ 546

 

$ 665

 

$ 684

 

$ 885

Ratio of earnings to combined fixed charges and preferred stock dividends

 

4.44

 

4.75

 

5.28

 

4.25

 

4.40

Ratio of earnings to fixed charges

 

4.73

 

5.06

 

5.59

 

4.44

 

4.56

 

 

 

 

 

 

 

 

 

 

 

 

(1)

In computing this ratio, “Preferred stock dividends” represents the before-tax earnings necessary to pay such dividends, computed at the effective tax rates for the applicable periods.











Exhibit 12.3




EXHIBIT 12.3

SOUTHERN CALIFORNIA GAS COMPANY

COMPUTATION OF RATIO OF EARNINGS TO COMBINED FIXED CHARGES

AND PREFERRED STOCK DIVIDENDS

(Dollars in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

2007 

 

2008 

 

2009 

 

2010 

 

2011 

Fixed Charges:

 

 

 

 

 

 

 

 

 

 

Interest

 

$ 72

 

$ 65

 

$ 74

 

$ 72

 

$ 77

Interest portion of annual rentals

 

3

 

2

 

1

 

2

 

1

Total fixed charges

 

75

 

67

 

75

 

74

 

78

Preferred stock dividends (1)

 

2

 

2

 

2

 

2

 

2

Combined fixed charges and preferred stock dividends for purpose of ratio

 

$ 77

 

$ 69

 

$ 77

 

$ 76

 

$ 80

Earnings:

 

 

 

 

 

 

 

 

 

 

Pretax income from continuing operations

 

$ 391

 

$ 385

 

$ 418

 

$ 463

 

$ 431

Add: Total fixed charges (from above)

 

75

 

67

 

75

 

74

 

78

Less: Interest capitalized

 

1

 

-

 

1

 

1

 

1

Total earnings for purpose of ratio

 

$ 465

 

$ 452

 

$ 492

 

$ 536

 

$ 508

Ratio of earnings to combined fixed charges and preferred stock dividends

 

6.04

 

6.55

 

6.39

 

7.05

 

6.35

Ratio of earnings to fixed charges

 

6.20

 

6.75

 

6.56

 

7.24

 

6.51

 

 

 

 

 

 

 

 

 

 

 

 

(1)

In computing this ratio, “Preferred stock dividends” represents the before-tax earnings necessary to pay such dividends, computed at the effective tax rates for the applicable periods.











Sempra Energy 2011 Exhibit 13

SEMPRA ENERGY FINANCIAL REPORT
TABLE OF CONTENTS
 
 
Page
Management’s Discussion and Analysis of Financial Condition and Results of Operations
 
Our Business
2
Executive Summary
8
Business Strategy
8
Key Issues in 2011
9
Results of Operations
10
Overall Results of Operations of Sempra Energy and Factors Affecting the Results
10
Business Unit Results
12
Changes in Revenues, Costs and Earnings
16
Transactions with Affiliates
32
Book Value Per Share
32
Capital Resources and Liquidity
32
Overview
32
Cash Flows from Operating Activities
35
Cash Flows from Investing Activities
37
Cash Flows from Financing Activities
42
Credit Ratings
47
Factors Influencing Future Performance
48
Sempra Energy Overview
48
Financial Derivatives Reforms
51
Litigation
51
Sempra Utilities – Industry Developments and Capital Projects
51
Sempra Global Investments
51
Market Risk
53
Critical Accounting Policies and Estimates, and Key Noncash Performance Indicators
56
New Accounting Standards
62
Information Regarding Forward-Looking Statements
63
Common Stock Data
64
Performance Graph – Comparative Total Shareholder Returns
65
Five-Year Summaries
66
Controls and Procedures
 
Evaluation of Disclosure Controls and Procedures
68
Management’s Report on Internal Control over Financial Reporting
68
Changes In and Disagreements With Accountants on Accounting and Financial Disclosure
68
Reports of Independent Registered Public Accounting Firm
69
Consolidated Financial Statements
 
Sempra Energy
75
San Diego Gas & Electric Company
82
Southern California Gas Company
88
Notes to Consolidated Financial Statements
93
Glossary
204
 
This Financial Report is a combined report for the following separate companies (each a separate Securities and Exchange Commission registrant):
   
Sempra Energy
San Diego Gas & Electric Company
Southern California Gas Company
 




MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
 
The following section of the 2011 Annual Report includes
 
§  
A description of our business
 
§  
An executive summary
 
§  
A discussion and analysis of our operating results for 2009 through 2011
 
§  
Information about our capital resources and liquidity
 
§  
Major factors expected to influence our future operating results
 
§  
A discussion of market risk affecting our businesses
 
§  
A table of accounting policies that we consider critical to our financial condition and results of operations
 
You should read Management’s Discussion and Analysis of Financial Condition and Results of Operations in conjunction with the Consolidated Financial Statements included in this Annual Report.
 
 

OUR BUSINESS
 

Sempra Energy is a Fortune 500 energy-services holding company whose business units develop energy infrastructure, operate utilities and provide related services to their customers. Our operations are divided principally between the Sempra Utilities and Sempra Global. The Sempra Utilities consist of two California regulated public utility companies, (1) San Diego Gas & Electric Company (SDG&E) and (2) Southern California Gas Company (SoCalGas). Sempra Global’s businesses develop and operate energy infrastructure and provide related natural gas and electricity services, including utility companies. (See Figure 1.)
 





[a002.gif]

Figure 1: Sempra Energy’s Business Units



Effective January 1, 2012, in connection with several key executive appointments made in September 2011, management realigned some of the company’s major subsidiaries to better fit its strategic direction and to enhance the management and integration of our assets. This realignment will result in a change in reportable segments in 2012, primarily to regroup the Sempra Global business units under two new operating units, Sempra U.S. Gas & Power and Sempra International. These operating units will include the following reportable segments:
 
Sempra U.S. Gas & Power
 
§  
Sempra Natural Gas
 
§  
Sempra Renewables
 
Sempra International
 
§  
Sempra Mexico
 
§  
Sempra South American Utilities
 
SDG&E and SoCalGas will continue to be separate, reportable segments.
 
This report includes information for the following separate registrants:
 
§  
Sempra Energy and its consolidated entities
 
§  
SDG&E
 
§  
SoCalGas
 
References in this report to “we,” “our” and “Sempra Energy Consolidated” are to Sempra Energy and its consolidated entities, collectively, unless otherwise indicated by its context.
 
Below are summary descriptions of our operating business units, which are also our reportable segments, through December 31, 2011.
 
 
SEMPRA ENERGY BUSINESS UNITS
 

SEMPRA UTILITIES
   
 
MARKET
SERVICE TERRITORY
SAN DIEGO GAS & ELECTRIC COMPANY (SDG&E)
A regulated public utility; infrastructure supports electric generation, transmission and distribution, and natural gas distribution
§ Provides electricity to 3.4 million consumers (1.4 million meters)
 
§ Provides natural gas to 3.1 million consumers (855,000 meters)
 
Serves the county of San Diego, California and an adjacent portion of southern Orange County covering 4,100 square miles
SOUTHERN CALIFORNIA GAS COMPANY (SOCALGAS)
A regulated public utility; infrastructure supports natural gas distribution, transmission and storage
§ Residential, commercial, industrial, utility electric generation and wholesale customers
 
§ Covers a population of 21 million (5.8 million meters)
 
Southern California and portions of central California (excluding San Diego County, the city of Long Beach and the desert area of San Bernardino County) covering 20,000 square miles

 
We refer to SDG&E and SoCalGas collectively as the Sempra Utilities, which do not include the utilities in our Sempra Pipelines & Storage business unit described below.
 

SDG&E
 
SDG&E provides electricity to 3.4 million consumers and natural gas to 3.1 million consumers. It delivers the electricity through 1.4 million meters in San Diego County and an adjacent portion of southern Orange County, California. SDG&E’s electric energy is purchased from others or generated from its own electric generation facilities and its 20-percent ownership interest in the San Onofre Nuclear Generating Station (SONGS). SDG&E’s electric generation facilities include Palomar, Miramar I and II, Desert Star Energy Center (purchased from Sempra Generation in October 2011) and Cuyamaca Peak Energy Plant (purchased in January 2012). SDG&E also delivers natural gas through 855,000 meters in San Diego County and transports electricity and natural gas for others. SDG&E’s service territory encompasses 4,100 square miles.
 
Sempra Energy indirectly owns all of the common stock of SDG&E. SDG&E also has publicly held preferred stock. The preferred stock has liquidation preferences totaling $79 million and represents less than 3% of the ordinary voting power of SDG&E shares.
 
SDG&E’s financial statements include a variable interest entity (VIE), Otay Mesa Energy Center LLC (Otay Mesa VIE), of which SDG&E is the primary beneficiary. As we discuss in Note 1 of the Notes to Consolidated Financial Statements under “Variable Interest Entities,” SDG&E has a long-term power purchase agreement with Otay Mesa VIE.
 
 
SoCalGas
 
SoCalGas is the nation’s largest natural gas distribution utility. It owns and operates a natural gas distribution, transmission and storage system that supplies natural gas throughout its approximately 20,000 square miles of service territory.  Its service territory extends from San Luis Obispo, California in the north to the Mexican border in the south, excluding San Diego County, the city of Long Beach and the desert area of San Bernardino County. SoCalGas provides natural gas service to residential, commercial, industrial, utility electric generation and wholesale customers through 5.8 million meters, covering a population of 21 million.
 
Sempra Energy indirectly owns all of the common stock of SoCalGas. SoCalGas also has publicly held preferred stock. The preferred stock has liquidation preferences totaling $22 million and represents less than 1% of the ordinary voting power of SoCalGas shares.
 

SEMPRA GLOBAL
   
 
MARKET
GEOGRAPHIC REGION
SEMPRA GENERATION
Develops, owns and operates, or holds interests in, electric power plants and energy projects
§ Wholesale electricity
 
§ U.S.A.
 
§ Mexico
 
SEMPRA PIPELINES & STORAGE
Develops, owns and operates, or holds interests in, natural gas and propane pipelines, natural gas storage facilities, and natural gas and electric utilities
§ Natural gas
 
§ Electricity
 
§ U.S.A.
 
§ Mexico
 
§ Argentina
 
§ Chile
 
§ Peru
 
SEMPRA LNG
Develops, owns and operates terminals for importation and export of liquefied natural gas (LNG) and sale of natural gas
§ Liquefied natural gas
 
§ Natural gas
 
§ U.S.A.
 
§ Mexico
 
§ Global
 

 
Sempra Global is a holding company for most of our subsidiaries that are not subject to California utility regulation. Sempra Global’s principal business units, which provide energy-related services, are
 
§  
Sempra Generation
 
§  
Sempra Pipelines & Storage
 
§  
Sempra LNG
 
A description of each business unit follows. All references in this Annual Report to “Sempra Generation,” “Sempra Pipelines & Storage” and “Sempra LNG” are to the respective principal business units of Sempra Global and are not intended to refer to any legal entity with the same or similar name.
 
 
Sempra Generation
 
Our Sempra Generation business unit:
 
§  
develops, owns, operates and invests in renewable energy generation projects in the U.S. and Mexico under long-term contracts;
 
§  
develops, owns and operates natural gas-fired power plants serving wholesale electricity markets in North America; and
 
§  
includes the operating results of Sempra Rockies Marketing, which holds firm service capacity on the Rockies Express Pipeline.
 
Renewables Facilities
 
The following table provides information about each of Sempra Generation’s renewables facilities that were operational as of December 31, 2011. The generating capacity of these facilities is fully contracted under long-term contracts, as we discuss below.
 
SEMPRA GENERATION RENEWABLES FACILITIES
Capacity in Megawatts (MW)
Name
Maximum Generating Capacity
 
        First
In Service
 
Location
Cedar Creek 2 Wind Farm (50% owned)
125
(1)
2011
 
New Raymer, CO
Fowler Ridge 2 Wind Farm (50% owned)
100
(1)
2009
 
Benton County, IN
Copper Mountain Solar 1
58
(2)
2010
 
Boulder City, NV
Mesquite Solar 1
42
(3)
2011
 
Arlington, AZ
 
Total MW in operation
325
       
(1)
Sempra Generation’s share.
(2)
Includes the 10-MW facility previously referred to as El Dorado Solar, which was first placed in service in 2008.
(3)
Represents only the portion of the project that was completed in 2011. The entire 150-MW project is expected to be completed in early 2013.
 
In October 2010, Sempra Generation invested $209 million for a 50-percent ownership interest in Cedar Creek 2 Wind Farm (Cedar Creek 2), a joint venture with BP Wind Energy (a wholly owned subsidiary of BP p.l.c.) for the development of a 250-megawatt (MW) wind farm in northern Colorado, which was placed in service in June 2011. Public Service Company of Colorado, an Xcel Energy subsidiary, has contracted for all of the power from the facility for 25 years. Our investment in Cedar Creek 2 is accounted for as an equity method investment.
 
In 2009, Sempra Generation invested $235 million and became an equal partner with BP Wind Energy in the development of the 200-MW Fowler Ridge 2 Wind Farm (Fowler Ridge 2) northwest of Indianapolis, Indiana. Fowler Ridge 2 went into full commercial operation in December 2009. The project’s entire power output has been sold under four long-term contracts, each for 50 MW and 20-year terms. Our investment in Fowler Ridge 2 is accounted for as an equity method investment.
 
In December 2010, Sempra Generation completed the construction of Copper Mountain Solar, a 48-MW solar generation facility located in Boulder City, Nevada, on land adjacent to a 10-MW solar facility formerly referred to as El Dorado Solar. Pacific Gas and Electric Company (PG&E) has contracted for all of the power from these facilities, now combined and referred to as Copper Mountain Solar 1, under separate 20-year contracts.
 
Construction on the 150-MW Mesquite Solar 1 photovoltaic solar installation in Arlington, Arizona, began in June 2011.  In December 2011, 42 MW were placed in service and are now delivering renewable electricity to the power grid. Sempra Generation anticipates that the project will be completed in early 2013. Power from the facility is sold to PG&E under a 20-year contract. 
 
Natural Gas Plants
 
Sempra Generation sells electricity under short-term and long-term contracts and into the spot market and other competitive markets. While it may also purchase electricity in the open market to satisfy its contractual obligations, Sempra Generation generally purchases natural gas to fuel its natural gas-fired power plants, which at December 31, 2011 include
 
§  
Mesquite Power, a 1,250-MW facility in Arlington, Arizona, which first went into service in 2003
 
§  
Termoeléctrica de Mexicali, a 625-MW facility in Mexicali, Baja California, Mexico, which also went into service in 2003
 
Sempra Generation’s El Dorado natural gas-fired generation plant (excluding the solar facility) was sold to SDG&E on October 1, 2011. This sale, pursuant to an option to acquire the plant that was exercised by SDG&E in 2007, coincided with the end of a contract with the California Department of Water Resources (DWR). During the first three quarters of 2011, these 100%-owned natural gas-fueled facilities sold the majority of their output under this long-term purchased-power contract with the DWR that provided for 1,200 MW to be supplied during all hours and an additional 400 MW during on-peak hours, and that ended on September 30, 2011.
 
In June 2011, Sempra Generation entered into a 25-year contract with various members of Southwest Public Power Resources Group (SPPR Group), an association of 40 not-for-profit utilities in Arizona and southern Nevada, for 240 MW of electricity. Under the terms of the agreement, Sempra Generation will provide 21 participating SPPR Group members with firm, day-ahead dispatchable power delivered to the Palo Verde hub beginning in January 2015.
 
Sempra Generation also has other purchased-power transactions, primarily with RBS Sempra Commodities LLP (RBS Sempra Commodities), to sell varying amounts of power through 2012. In connection with the 2011 sale of businesses within RBS Sempra Commodities, substantially all of these transactions with RBS Sempra Commodities were assigned to J.P. Morgan Ventures Energy Corporation (J.P. Morgan Ventures) by May 1, 2011. The remaining output of our natural gas facilities is available to be sold into energy markets on a day-to-day basis.
 
From 2003 through 2010, Sempra Generation had a 50-percent equity interest in Elk Hills Power (Elk Hills), a 550-MW merchant plant located in Bakersfield, California. Elk Hills offered its output into the California market on a daily basis. Sempra Generation sold its interest in Elk Hills on December 31, 2010, as we discuss in Note 4 of the Notes to Consolidated Financial Statements.
 
 
Sempra Pipelines & Storage
 
Sempra Pipelines & Storage develops, owns and operates, or holds interests in, natural gas pipelines and storage facilities in the United States, and natural gas and propane pipelines in Mexico, and in companies that provide natural gas or electric services in Mexico, Argentina, Chile and Peru. On April 6, 2011, Sempra Pipelines & Storage completed the acquisition of AEI’s interests in Chilquinta Energía S.A. (Chilquinta Energía) in Chile and Luz del Sur S.A.A. (Luz del Sur) in Peru. Upon completion of the transaction, Sempra Pipelines & Storage owned 100 percent of Chilquinta Energía and approximately 76 percent of Luz del Sur, and the companies are now consolidated. Pursuant to a tender offer that was completed in September 2011, Sempra Pipelines & Storage now owns 79.82 percent of Luz del Sur, as we discuss in Note 3 of the Notes to Consolidated Financial Statements. The remaining shares of Luz del Sur are held by institutional investors and the general public.
 
Chilquinta Energía is an electric distribution utility serving more than 600,000 customers in the cities of Valparaiso and Viña del Mar in central Chile. Luz del Sur is an electric distribution utility that serves more than 900,000 customers in the southern zone of metropolitan Lima, Peru, and delivers approximately one-third of all power used in the country. As part of the transaction, Sempra Pipelines & Storage also acquired AEI’s interests in two energy-services companies, Tecnored S.A. (Tecnored) and Tecsur S.A. (Tecsur).
 
Sempra Pipelines & Storage also is currently pursuing the sale of its interests in the Argentine utilities, which we discuss further in Note 4 of the Notes to Consolidated Financial Statements.
 
Sempra Pipelines & Storage’s natural gas distribution utility, Ecogas Mexico, S de RL de CV (Ecogas), operates in three separate areas in Mexico, and had a customer count of 89,800 and sales volume of 60 million cubic feet per day in 2011. Sempra Pipelines & Storage’s natural gas pipeline systems in Mexico had a contracted capacity for up to 4,700 million cubic feet per day in 2011.
 
Sempra Pipelines & Storage also owns and operates, or holds interests in, natural gas underground storage and related pipeline facilities in Alabama and Mississippi (Sempra Midstream) and owns Mobile Gas Service Corporation (Mobile Gas), a regulated natural gas distribution utility in southwest Alabama. These businesses were formerly the operations of EnergySouth, Inc., which we acquired in October 2008. Sempra Midstream Services (Midstream Services) provides natural gas marketing, trading and risk management activities through the utilization and optimization of contracted natural gas supply, transportation and storage capacity, as well as optimizing Sempra Midstream assets in the short-term services market.
 
Sempra Pipelines & Storage, Kinder Morgan Energy Partners, L.P. (KMP) and ConocoPhillips jointly own, through Rockies Express Pipeline LLC (Rockies Express), the Rockies Express Pipeline (REX) that links producing areas in the Rocky Mountain region to the upper Midwest and the eastern United States. The 1,679-mile natural gas pipeline became fully operational in 2009. Our ownership interest in the pipeline is 25 percent. Sempra Rockies Marketing, part of our Sempra Generation segment, has an agreement with Rockies Express for 200 million cubic feet per day of capacity on REX, which has a total capacity of 1.8 billion cubic feet (Bcf) per day. Sempra Rockies Marketing has released a portion of its capacity to RBS Sempra Commodities, which capacity was assigned to J.P. Morgan Ventures effective January 1, 2011 in connection with the sale of businesses within RBS Sempra Commodities.
 
 
Sempra LNG
 
Sempra LNG develops, owns and operates terminals for importing and exporting LNG, and has supply and marketing agreements to purchase and sell LNG and natural gas. Sempra LNG utilizes its LNG terminals by entering into long-term firm capacity service agreements when able to do so. Under these agreements, customers pay Sempra LNG capacity reservation and usage fees to use its facilities to receive, store and regasify the customer’s LNG. Sempra LNG also may enter into short-term and/or long-term supply agreements to purchase LNG to be received, stored and regasified at its terminals for sale to other parties.
 
Sempra LNG’s Energía Costa Azul LNG terminal in Baja California, Mexico began commercial operations in May 2008 and is capable of processing 1 Bcf of natural gas per day. The Energía Costa Azul facility currently generates revenue under a capacity services agreement with Shell México Gas Natural (Shell), expiring in 2028, that permits Shell to use one-half of the terminal’s capacity. In April 2009, Shell assigned a portion of its terminal capacity at Energía Costa Azul to Gazprom Marketing & Trading Mexico (Gazprom), transferring all further rights and obligations with respect to the assigned capacity.
 
A nitrogen-injection facility at Energía Costa Azul placed in service by Sempra LNG in December 2009 allows the terminal to process LNG cargoes from a wider variety of sources and provides additional revenue from payments for capacity reservation and usage fees for nitrogen injection services for Shell and Gazprom.
 
Sempra LNG has an LNG purchase agreement with Tangguh PSC Contractors (Tangguh PSC) for the supply of the equivalent of 500 million cubic feet of natural gas per day from Tangguh PSC’s Indonesian liquefaction facility to the Energía Costa Azul receipt terminal at a price based on the Southern California border index for natural gas. Sempra LNG has a contract through 2022 to sell an average of approximately 150 million cubic feet per day of natural gas to Mexico’s national electric company, Federal Electricity Commission (Comisión Federal de Electricidad, or CFE) at prices that are based on the Southern California border index. If LNG volumes received from Tangguh PSC are not sufficient to satisfy the commitment to CFE, Sempra LNG may purchase natural gas from other suppliers.  Sempra LNG also had an agreement to sell to RBS Sempra Commodities any volumes purchased from Tangguh PSC that are not sold to the CFE. In connection with the 2010 sale of businesses within RBS Sempra Commodities, substantially all contracts with RBS Sempra Commodities were assigned to J.P. Morgan Ventures by May 1, 2011, as we discuss in Note 1 of the Notes to Consolidated Financial Statements.
 
Sempra LNG’s Cameron LNG terminal in Hackberry, Louisiana, began commercial operations in July 2009 and is capable of processing 1.5 Bcf of natural gas per day.  Cameron LNG generates revenue under a capacity services agreement for approximately 600 million cubic feet of natural gas per day through 2029. In January 2012, the U.S. Department of Energy (DOE) approved Cameron LNG’s application for an LNG export license.
 
Sempra LNG also owns property in Port Arthur, Texas, that it is evaluating for potential development.
 
 
RBS Sempra Commodities LLP
 
Prior to 2011, our Sempra Commodities segment contained our investment in RBS Sempra Commodities LLP (RBS Sempra Commodities), which held commodities-marketing businesses previously owned by us. Our investment in the partnership is reported on the equity method. We and The Royal Bank of Scotland plc (RBS), our partner in the joint venture, sold substantially all of the partnership’s businesses and assets in four separate transactions completed in July, November and December of 2010 and February of 2011. We discuss these transactions and other matters concerning the partnership in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report.
 
The activity in the partnership no longer meets the quantitative thresholds that require Sempra Commodities to be reported as a reportable segment under applicable accounting rules, and we do not consider the remaining wind-down activities of the partnership to be of continuing significance. As a result, effective January 1, 2011, we are reporting the former Sempra Commodities segment in Parent and Other, and have restated prior year information to be consistent with this treatment.
 

REGULATION OF SEMPRA UTILITIES AND OTHER UTILITIES
 
The Sempra Utilities are regulated by federal, state and local governmental agencies. The primary regulatory agency is the California Public Utilities Commission (CPUC). The CPUC regulates the Sempra Utilities’ rates and operations in California, except for SDG&E’s electric transmission operations. The Federal Energy Regulatory Commission (FERC) regulates SDG&E’s electric transmission operations. The FERC also regulates interstate transportation of natural gas and various related matters.
 
The Nuclear Regulatory Commission (NRC) regulates SONGS, in which SDG&E owns a 20-percent interest. Municipalities and other local authorities regulate the location of utility assets, including natural gas pipelines and electric lines. Sempra Energy’s other business units are also regulated by the FERC, various state commissions, local governmental entities, and other similar authorities in countries other than the United States.
 
The South American utilities are regulated by federal and local government agencies. The National Energy Commission (Comisión Nacional de Energía, or CNE) regulates Chilquinta Energía in Chile. The Energy and Mining Investment Supervisory Body (Organismo Supervisor de la Inversión en Energía y Minería, or OSINERGMIN) of the National Electricity Office under the Ministry of Energy and Mines regulates Luz del Sur in Peru.  
 
Ecogas, our natural gas distribution utility in Northern Mexico, is subject to regulation by the Energy Regulatory Commission (Comisión Reguladora de Energía, or CRE) and by the labor and environmental agencies of city, state and federal governments in Mexico.
 
Mobile Gas, our natural gas distribution utility serving southwest Alabama, is regulated by the Alabama Public Service Commission.
 

 

EXECUTIVE SUMMARY
 

 
BUSINESS STRATEGY
 
Our ongoing focus is to enhance shareholder value and meet customer needs by developing and operating a stable portfolio of integrated energy businesses with long-term, predictable cash flows.
 
The key components of our strategy include
 
§  
investment in our utilities; and
 
§  
development of natural gas and renewable-energy infrastructure.
 
We have based our strategy on a market view that recognizes emerging state and federal policies that point toward the following business priorities:
 
1.  
cleaner fuels
 
§  
natural gas
 
§  
renewables
 
2.  
enabling infrastructure
 
§  
natural gas pipelines, storage and LNG terminals
 
§  
electric transmission and advanced meters
 

KEY ISSUES IN 2011
 
Below are several key issues that affected our business in 2011; some of these issues may continue to affect our future results. Each issue includes the page number you may reference for additional details.
 
§  
In March 2011, we completed a $500 million repurchase of our common stock under a Collared Accelerated Share Acquisition Program (44).
 
§  
In April 2011, we completed the acquisition of AEI’s interests in two South American utilities, Chilquinta Energía and Luz del Sur (114).
 
§  
SDG&E is approximately 70 percent complete on the construction of the Sunrise Powerlink electric transmission line begun in the fall of 2010 and expects the transmission line to be completed and in-service in the second half of 2012 (189).
 
§  
The Cedar Creek 2 Wind Farm, which Sempra Generation jointly owns with BP Wind Energy, went into service in June 2011 (5).
 
§  
On June 30, 2011, Pacific Enterprises, the holding company for SoCalGas, redeemed all five series of its outstanding preferred stock for $80 million (177).
 
§  
In July 2011, the CPUC approved a settlement agreement filed by SDG&E in April 2011 regarding SDG&E’s request to make a tax equity investment in the holding company of a wind farm project (184).
 
§  
In July 2011, the Sempra Utilities filed revised applications to their original 2012 General Rate Case (GRC) applications, primarily to reflect the impact of the Tax Relief, Unemployment Insurance Reauthorization, and Job Creation Act of 2010. In February 2012, the Sempra Utilities filed amendments to update the July 2011 revision (49).
 
§  
In August 2011, the Sempra Utilities filed their Pipeline Safety Enhancement Plan to test or replace all natural gas transmission pipelines that have not been pressure tested. The first phase of the two-phase plan is expected to cost $3.1 billion ($2.5 billion for SoCalGas and $600 million for SDG&E) over the 10-year period of 2012 to 2022 (185).
 
§  
On September 30, 2011, Sempra Generation’s 10-year contract to provide energy to the DWR ended (5).
 
§  
Sempra Generation sold the El Dorado natural gas-fired generation plant to SDG&E on October 1, 2011 (181).
 
§  
In December 2011, the CPUC approved SDG&E’s request for revenue requirement for the recovery of the incremental increase in its general liability and wildfire liability insurance premium costs for the 2010/2011 policy period (185).
 
§  
SDG&E substantially completed the installation of approximately 1.4 million electric and 855,000 natural gas advanced meters in 2011 (184).
 
§  
In December 2011, Sempra Generation placed in service 42 MW of the 150-MW Mesquite Solar 1 photovoltaic solar installation project in Arizona (52).
 
§  
We received $623 million in distributions from RBS Sempra Commodities, reducing our remaining investment in the joint venture to $126 million (33).
 
§  
SDG&E continues to settle claims related to the 2007 California wildfire litigation; however, a substantial number of unresolved claims against SDG&E remain (187).
 


RESULTS OF OPERATIONS
 

We discuss the following in Results of Operations:
 
§  
Overall results of our operations and factors affecting those results
 
§  
Our business unit results
 
§  
Significant changes in revenues, costs and earnings between periods
 
 
OVERALL RESULTS OF OPERATIONS OF SEMPRA ENERGY AND FACTORS AFFECTING THE RESULTS
 
The graphs below show our overall operations from 2007 to 2011.
 

OVERALL OPERATIONS OF SEMPRA ENERGY FROM 2007 TO 2011
(Dollars and shares in millions, except per share amounts)

[a004.gif]


[a008.gif]


 


Our earnings increased by $618 million in 2011 to $1.4 billion primarily due to:
 
§  
before and after-tax gain of $277 million resulting from the remeasurement of our equity method investments at Sempra Pipelines & Storage related to its acquisition of additional interests in Chilquinta Energía and Luz del Sur;
 
§  
a $139 million after-tax write-down in 2010 of our investment in RBS Sempra Commodities;
 
§  
$93 million after-tax litigation expense in 2010 related to an agreement to settle certain energy crisis litigation ($87 million at Sempra Generation and $6 million at Parent and Other), as we discuss in Note 15 of the Notes to Consolidated Financial Statements;
 
§  
improved results at SDG&E and Sempra LNG; and
 
§  
higher earnings at Sempra Pipelines & Storage primarily related to the acquisition of additional interests in Chilquinta Energía and Luz del Sur; offset by
 
§  
lower earnings at Sempra Generation (excluding the energy crisis litigation expense), primarily due to the expiration of the DWR contract; and
 
§  
higher losses at Parent and Other (excluding the investment write-down and energy crisis litigation expense in 2010).
 
Diluted earnings per share for 2011 increased by $2.64 per share to $5.62 per share. Components of this increase include
 
§  
the remeasurement gain in 2011 ($1.15 per share);
 
§  
the investment write-down in 2010 ($0.56 per share);
 
§  
the settlement-related litigation expense in 2010 ($0.38 per share);
 
§  
higher earnings (excluding the impacts of the 2011 remeasurement gain and the investment write-down and litigation settlement charge in 2010); and
 
§  
a decrease in the number of shares outstanding primarily as a result of our $500 million share repurchase program initiated in September 2010 and completed in March 2011.
 
Our 2010 earnings decreased from 2009 due to:
 
§  
$327 million lower joint-venture earnings from RBS Sempra Commodities;
 
§  
the $139 million after-tax write-down of our investment in RBS Sempra Commodities; and
 
§  
$93 million after-tax litigation expense in 2010 related to the agreement to settle certain energy crisis litigation; offset by
 
§  
improved results at Sempra Pipelines & Storage, Sempra LNG, and the Sempra Utilities.
 
Operating results at Sempra Pipelines & Storage in 2009 were negatively impacted by an after-tax write-off of $64 million related to certain assets at one of its natural gas storage projects. Sempra Pipelines & Storage owns 75 percent of Liberty Gas Storage, LLC (Liberty), the partnership that owns the project.
 
Diluted earnings per share in 2010 compared to 2009 decreased by $1.54 per share due to decreased earnings. Components of this decrease include
 
§  
lower joint-venture earnings from RBS Sempra Commodities ($1.32 per share);
 
§  
the investment write-down in 2010 ($0.56 per share); and
 
§  
the settlement-related litigation expense in 2010 ($0.38 per share); offset by
 
§  
higher earnings (excluding the impacts of the lower joint-venture earnings and the investment write-down and litigation settlement charge in 2010, and the write-off of Liberty assets in 2009); and
 
§  
the write-off of assets at Liberty in 2009 ($0.26 per share).
 
The impact from reduced shares outstanding due to our 2010 share repurchase program was negligible.
 

The following table shows our earnings (losses) by business unit, which we discuss below in “Business Unit Results.”
 

SEMPRA ENERGY EARNINGS (LOSSES) BY BUSINESS UNIT 2009-2011
(Dollars in millions)
 
 
Years ended December 31,
 
 
2011 
2010 
2009 
Sempra Utilities:
 
 
 
 
 
 
 
 
 
 
 
 
    SDG&E(1)
$
 431 
 32 
%
$
 369 
 50 
%
$
 344 
 31 
%
    SoCalGas(1)
 
 287 
 21 
 
 
 286 
 39 
 
 
 273 
 25 
 
Sempra Global:
 
 
 
 
 
 
 
 
 
 
 
 
    Sempra Generation
 
 137 
 10 
 
 
 103 
 14 
 
 
 169 
 15 
 
    Sempra Pipelines & Storage
 
 527 
 39 
 
 
 159 
 21 
 
 
 101 
 9 
 
    Sempra LNG
 
 99 
 7 
 
 
 68 
 9 
 
 
 16 
 1 
 
Parent and other(2)
 
 (124)
 (9)
 
 
 (246)
 (33)
 
 
 216 
 19 
 
Earnings
$
 1,357 
 100 
%
$
 739 
 100 
%
$
 1,119 
 100 
%
(1)
After preferred dividends.
(2)
Includes after-tax corporate interest expense ($137 million in 2011, $148 million in 2010 and $141 million in 2009), results from our former Sempra Commodities segment (losses of $16 million and $155 million in 2011 and 2010, respectively, and earnings of $338 million in 2009), intercompany eliminations recorded in consolidation and certain corporate costs incurred at Sempra Global.
 
BUSINESS UNIT RESULTS
 
The following section is a discussion of earnings (losses) by Sempra Energy business unit, as presented in the table above. Variance amounts are the after-tax earnings impact, unless otherwise noted.
 

EARNINGS BY BUSINESS UNIT – SEMPRA UTILITIES
(Dollars in millions)

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SDG&E
 
Our SDG&E business unit recorded earnings of:
 
§  
$431 million in 2011 ($436 million before preferred dividends)
 
§  
$369 million in 2010 ($374 million before preferred dividends)
 
§  
$344 million in 2009 ($349 million before preferred dividends)
 

The increase of $62 million (17%) in 2011 was primarily due to:
 
§  
$31 million increase in allowance for funds used during construction (AFUDC) related to equity, net of higher interest expense;
 
§  
$28 million favorable earnings impact due to revenues for incremental wildfire insurance premiums exceeding premium expense in 2011 compared to the incremental expense for wildfire insurance premiums exceeding revenues for the incremental premiums in 2010. Revenues for the incremental premiums in 2011 were for the policy period July 2010 through December 2011 compared to revenues for the incremental premiums in 2010 for the period July 2009 through June 2010;
 
§  
$13 million higher authorized margin for CPUC-regulated operations, net of higher depreciation and operation and maintenance expenses (excluding insurance premiums for wildfire coverage and litigation);
 
§  
$7 million lower expenses associated with the settlement of 2007 wildfire claims; and
 
§  
$5 million higher regulatory incentive awards; offset by
 
§  
$10 million primarily from the favorable resolution of prior year’s tax matters in 2010; and
 
§  
$8 million lower favorable resolution of litigation matters in 2011.
 
The increase of $25 million (7%) in 2010 compared to 2009 was primarily due to:
 
§  
$28 million higher authorized margin for CPUC-regulated operations and lower operation and maintenance expenses (excluding insurance premiums for wildfire coverage and litigation related expenses), net of higher depreciation expense;
 
§  
$16 million from the CPUC decision in 2010 authorizing recovery of a portion of the incremental wildfire insurance premiums for the policy year July 2009 through June 2010; and
 
§  
$8 million higher electric transmission margin; offset by
 
§  
$20 million higher liability insurance premiums for wildfire coverage; and
 
§  
$13 million net unfavorable impact from an increase in litigation reserves in 2010, including $20 million in 2010 for settlement of 2007 wildfire claims, offset by $7 million higher favorable resolution of litigation matters in 2010 compared to 2009.
 
 
SoCalGas
 
Our SoCalGas business unit recorded earnings of:
 
§  
$287 million in 2011 ($288 million before preferred dividends)
 
§  
$286 million in 2010 ($287 million before preferred dividends)
 
§  
$273 million in 2009 ($274 million before preferred dividends)
 
The $1 million increase in earnings in 2011 was primarily due to:
 
§  
$13 million due to the write-off of deferred tax assets in 2010 as a result of the change in U.S. tax law regarding the Medicare Part D subsidy;
 
§  
$9 million higher authorized margin for CPUC-regulated operations, net of higher depreciation and operation and maintenance expenses; and
 
§  
$3 million higher equity-related AFUDC, net of higher interest expense; offset by
 
§  
$7 million lower regulatory incentive awards;
 
§  
$7 million due to the favorable resolution of a legal matter in 2010; and
 
§  
$6 million lower non-core natural gas storage revenue.
 
The increase of $13 million (5%) in 2010 compared to 2009 was due to:
 
§  
$11 million higher authorized margin for CPUC-regulated operations in excess of higher depreciation and operation and maintenance expenses;
 
§  
$8 million higher regulatory incentive awards; and
 
§  
$8 million net favorable impact from a favorable resolution of litigation matters in 2010 compared to litigation expense in 2009; offset by
 
§  
$13 million due to the write-off of deferred tax assets as a result of the change in U.S. tax law regarding the Medicare Part D subsidy.
 

EARNINGS (LOSSES) BY BUSINESS UNIT – SEMPRA GLOBAL
(Dollars in millions)

[a012.gif]


 
Sempra Generation
 
Sempra Generation recorded earnings of:
 
§  
$137 million in 2011
 
§  
$103 million in 2010
 
§  
$169 million in 2009
 
The increase in 2011 of $34 million (33%) was primarily due to:
 
§  
$85 million decreased litigation expense primarily related to a 2010 agreement to settle energy crisis litigation, as we discuss in Note 15 of the Notes to Consolidated Financial Statements; and
 
§  
$16 million decreased gas plant operation and maintenance expense primarily as a result of 2010 major maintenance at the Mexicali and Mesquite power plants, and from the sale of El Dorado to SDG&E as of October 1, 2011; offset by
 
§  
$57 million lower earnings from operations primarily due to the end of the DWR contract as of September 30, 2011, and less favorable pricing in 2011; and
 
§  
$15 million higher mark-to-market losses on forward contracts in 2011.
 
The decrease in 2010 of $66 million (39%) compared to 2009 was due to:
 
§  
$87 million in litigation expense related to an agreement to settle energy crisis litigation associated with the DWR contract; and
 
§  
$31 million lower earnings from operations, primarily from increased scheduled plant maintenance and associated down time in 2010, and expenses and associated down time from earthquake damage to our Mexicali power plant in the second quarter of 2010; offset by
 
§  
$48 million increased tax incentives from renewable energy investments in 2010.
 
 
Sempra Pipelines & Storage
 
Our Sempra Pipelines & Storage business unit recorded earnings of:
 
§  
$527 million in 2011
 
§  
$159 million in 2010
 
§  
$101 million in 2009
 

The increase of $368 million in 2011 was primarily due to:
 
§  
a $277 million gain related to the remeasurement of the Chilquinta Energía and Luz del Sur equity method investments;
 
§  
$55 million higher earnings primarily related to the acquisition of additional interests in Chilquinta Energía and Luz del Sur in April 2011;
 
§  
$44 million (pretax) write-down of our investment in Argentina in 2010, less a related income tax benefit of $15 million;
 
§  
$13 million higher earnings from pipeline assets in Mexico acquired in April 2010;
 
§  
$10 million higher earnings from foreign currency rate effect primarily for previously held net U.S. dollar monetary position in Chile;
 
§  
$8 million higher earnings primarily related to natural gas optimization activities at Midstream Services; and
 
§  
a $6 million release of a tax valuation allowance in Mexico; offset by
 
§  
$48 million (pretax) in proceeds received from a legal settlement in 2010, less a related income tax effect of $17 million.
 
The increase in 2010 of $58 million (57%) compared to 2009 was due to:
 
§  
$64 million lower earnings in 2009 from a write-off of assets at Liberty;
 
§  
$48 million (pretax) in proceeds received from a legal settlement in 2010, less a related income tax effect of $17 million;
 
§  
$20 million higher earnings related to a Mexican pipeline acquisition in April 2010; and
 
§  
$7 million higher operating results from its investments in Chile and Peru; offset by
 
§  
a $44 million (pretax) write-down of our investment in Argentina, less a related income tax benefit of $15 million;
 
§  
$13 million from the resolution of prior years’ income tax issues which favorably impacted 2009 earnings;
 
§  
$10 million lower earnings attributable to natural gas optimization activities at Midstream Services; and
 
§  
$7 million lower earnings in Mexico primarily due to the favorable impact of the adoption of regulatory accounting in 2009 and the expiration of a transportation service contract at the end of 2009.
 
 
Sempra LNG
 
Sempra LNG recorded earnings of:
 
§  
$99 million in 2011
 
§  
$68 million in 2010
 
§  
$16 million in 2009
 
The increase in 2011 was primarily due to higher earnings from contractual counterparty obligations for non-delivery of cargoes, and $18 million in gains in 2011 associated with marketing activities not expected to recur.
 
The increase in 2010 earnings of $52 million was due to higher earnings from operations, primarily due to a full year of operations of the Cameron LNG terminal and the nitrogen-injection facility at the Energía Costa Azul terminal and a full year of performance under the Tangguh LNG purchase agreement, compared to partial-year periods for such operations and agreement in 2009.
 
 
Parent and Other
 
(Losses) earnings for Parent and Other were
 
§  
$(124) million in 2011
 
§  
$(246) million in 2010
 
§  
$216 million in 2009
 

The decrease in losses of $122 million (50%) in 2011 was primarily due to:
 
§  
a $10 million write-down of our investment in the RBS Sempra Commodities joint venture in 2011 compared to $139 million in 2010; and
 
§  
other joint venture related expenses in 2010, including transaction costs related to the sales within RBS Sempra Commodities and litigation expense; offset by
 
§  
$5 million equity loss in 2011 from our former commodities-marketing businesses compared to equity earnings of $25 million in 2010.
 
Losses of $246 million in 2010 compared to earnings in 2009 of $216 million were primarily due to:
 
§  
$327 million lower equity earnings from RBS Sempra Commodities, which were adversely impacted by the sale on July 1, 2010 of the global metals and oil businesses and the European natural gas and power business; lower volatility in the U.S. natural gas and power business; and the disruptions caused by the process to sell the partnership’s businesses;
 
§  
a $139 million write-down in 2010 of our investment in the RBS Sempra Commodities joint venture; and
 
§  
other joint venture related expenses in 2010, including transaction costs related to the sales within RBS Sempra Commodities and litigation expense; offset by
 
§  
lower general and administrative expenses and higher income tax benefits, partially offset by higher net interest expense, excluding results related to our former Sempra Commodities segment.
 
 
CHANGES IN REVENUES, COSTS AND EARNINGS
 
This section contains a discussion of the differences between periods in the specific line items of the Consolidated Statements of Operations for Sempra Energy, SDG&E and SoCalGas.
 
 
Utilities Revenues
 
Our utilities revenues include
 
Natural gas revenues at:
 
§  
SDG&E
 
§  
SoCalGas
 
§  
Mobile Gas
 
§  
Ecogas
 
Electric revenues at:
 
§  
SDG&E
 
§  
Chilquinta Energía
 
§  
Luz del Sur
 
Intercompany revenues included in the separate revenues of each utility are eliminated in the Sempra Energy Consolidated Statements of Operations.
 
The Sempra Utilities
 
The current regulatory framework for SoCalGas and SDG&E permits the cost of natural gas purchased for core customers (primarily residential and small commercial and industrial customers) to be passed on to customers substantially as incurred. However, SoCalGas’ Gas Cost Incentive Mechanism provides SoCalGas the opportunity to share in the savings and/or costs from buying natural gas for its core customers at prices below or above monthly market-based benchmarks. This mechanism permits full recovery of costs incurred when average purchase costs are within a price range around the benchmark price. Any higher costs incurred or savings realized outside this range are shared between the core customers and SoCalGas. We provide further discussion in Notes 1 and 14 of the Notes to Consolidated Financial Statements.
 
The regulatory framework also permits SDG&E to recover the actual cost incurred to generate or procure electricity based on annual estimates of the cost of electricity supplied to customers. The differences in cost between estimates and actual are recovered in the next year through rates.
 
The table below summarizes Utilities Revenues and Cost of Sales for Sempra Energy, net of intercompany activity.
 

UTILITIES REVENUES AND COST OF SALES 2009-2011
(Dollars in millions)
 
 
Years ended December 31,
 
 
2011 
2010 
2009 
Electric revenues:
 
 
 
 
 
 
SDG&E
$
 2,830 
$
 2,535 
$
 2,426 
Sempra Pipelines & Storage
 
 1,009 
 
 ― 
 
 ― 
Eliminations and adjustments
 
 (6)
 
 (7)
 
 (7)
 
 
 
 3,833 
 
 2,528 
 
 2,419 
Natural gas revenues:
 
 
 
 
 
 
SoCalGas
 
 3,816 
 
 3,822 
 
 3,355 
SDG&E
 
 543 
 
 514 
 
 490 
Sempra Pipelines & Storage
 
 184 
 
 200 
 
 201 
Eliminations and adjustments
 
 (54)
 
 (45)
 
 (44)
 
 
 
 4,489 
 
 4,491 
 
 4,002 
 
Total
$
 8,322 
$
 7,019 
$
 6,421 
Cost of natural gas:
 
 
 
 
 
 
SoCalGas
$
 1,568 
$
 1,699 
$
 1,343 
SDG&E
 
 226 
 
 217 
 
 206 
Sempra Pipelines & Storage
 
 90 
 
 111 
 
 115 
Eliminations and adjustments
 
 (18)
 
 (15)
 
 (19)
 
Total
$
 1,866 
$
 2,012 
$
 1,645 
Cost of electric fuel and purchased power:
 
 
 
 
 
 
SDG&E
$
 715 
$
 637 
$
 672 
Sempra Pipelines & Storage
 
 682 
 
 ― 
 
 ― 
 
Total
$
 1,397 
$
 637 
$
 672 
 
Sempra Energy Consolidated
 
Electric Revenues
 
In 2011, electric revenues increased by $1.3 billion (52%) to $3.8 billion and our cost of electric fuel and purchased power increased by $760 million (119%) to $1.4 billion. The increase in electric revenues included
 
§  
$1.0 billion from the consolidation of electric revenues of Chilquinta Energía and Luz del Sur acquired in April 2011; and
 
§  
$295 million at SDG&E, which we discuss below.
 
The increase in our cost of electric fuel and purchased power included:
 
§  
$682 million from the consolidation of Chilquinta Energía and Luz del Sur acquired in April 2011; and
 
§  
$78 million at SDG&E, which we discuss below.
 
In 2010, our electric revenues increased by $109 million (5%) to $2.5 billion and our cost of electric fuel and purchased power decreased by $35 million (5%) to $637 million. The increases were attributable to SDG&E, which we discuss below.
 
Natural Gas Revenues
 
Our natural gas revenues in 2011 were essentially unchanged when compared to 2010 at $4.5 billion, while the cost of natural gas sold decreased by $146 million (7%) to $1.9 billion.  Natural gas revenues in 2011 compared to 2010 were impacted by:
 
§  
$131 million decrease in cost of natural gas sold at SoCalGas, which was caused primarily by lower natural gas prices, partially offset by higher volumes sold;
 
§  
$16 million lower revenues at Sempra Pipelines & Storage’s two natural gas utilities, Mobile Gas and Ecogas; and
 
§  
$12 million lower regulatory awards in 2011 at SoCalGas; offset by
 
§  
$105 million higher recovery of Sempra Utilities’ CPUC-authorized costs, which revenues are fully offset in operation and maintenance expenses; and
 
§  
$62 million higher authorized base margin at the Sempra Utilities.
 
In 2010, our natural gas revenues increased by $489 million (12%) to $4.5 billion, and the cost of natural gas increased by $367 million (22%) to $2.0 billion. The increase in revenues was primarily due to:
 
§  
an increase in cost of natural gas, which was caused primarily by higher natural gas prices;
 
§  
$58 million higher authorized base margin in accordance with the CPUC’s 2008 GRC decision;
 
§  
$47 million higher recovery of CPUC-authorized costs, which revenues are fully offset in operation and maintenance expenses; and
 
§  
$13 million higher regulatory awards in 2010 at SoCalGas.
 
We discuss the changes in revenues and cost of natural gas individually for SDG&E and SoCalGas below.
 
 
SDG&E: Electric Revenues and Cost of Electric Fuel and Purchased Power
 
The table below shows electric revenues for SDG&E. Because the cost of electricity is substantially recovered in rates, changes in the cost are reflected in the changes in revenues.
 

SDG&E: ELECTRIC DISTRIBUTION AND TRANSMISSION 2009-2011
(Volumes in millions of kilowatt-hours, dollars in millions)
 
2011 
2010 
2009 
Customer class
Volumes
Revenue
Volumes
Revenue
Volumes
Revenue
Residential
 7,374 
$
 1,215 
 7,304 
$
 1,039 
 7,536 
$
 1,041 
Commercial
 6,736 
 
 1,000 
 6,738 
 
 884 
 7,061 
 
 890 
Industrial
 2,037 
 
 247 
 2,131 
 
 229 
 2,285 
 
 238 
Direct access
 3,265 
 
 148 
 3,202 
 
 124 
 3,119 
 
 106 
Street and highway lighting
 100 
 
 14 
 108 
 
 13 
 110 
 
 12 
 
 19,512 
 
 2,624 
 19,483 
 
 2,289 
 20,111 
 
 2,287 
Other revenues
 
 
 117 
 
 
 108 
 
 
 137 
Balancing accounts
 
 
 89 
 
 
 138 
 
 
 2 
    Total(1)
 
$
 2,830 
 
$
 2,535 
 
$
 2,426 
(1) Includes sales to affiliates of $6 million in 2011, and $7 million in both 2010 and 2009.

In 2011, SDG&E’s electric revenues increased by $295 million (12%) to $2.8 billion, primarily due to:
 
§  
$81 million higher authorized base margin on electric generation and distribution, including $26 million due to the acquisition of the Desert Star generation facility on October 1, 2011;
 
§  
$78 million increase in the cost of electric fuel and purchased power due to higher prices;
 
§  
$57 million higher revenues associated with incremental wildfire insurance premiums;
 
§  
$29 million higher recoverable expenses that are fully offset in operation and maintenance expenses;
 
§  
$9 million higher authorized transmission margin; and
 
§  
$7 million higher regulatory awards.
 
In 2010, electric revenues increased by $109 million (4%) at SDG&E to $2.5 billion primarily due to:
 
§  
$57 million higher authorized base margin on electric generation and distribution;
 
§  
$28 million increase due to tolling payments and natural gas supply costs in 2010 associated with the power generated by Otay Mesa VIE in excess of purchased power costs in 2009 for the equivalent amount of power;
 
§  
$28 million from the recovery of a portion of the incremental wildfire insurance premiums for the policy year July 2009 through June 2010; and
 
§  
$18 million higher authorized transmission margin; offset by
 
§  
$31 million lower recoverable expenses that are fully offset in operation and maintenance expenses; and
 
§  
$3 million decrease in the cost of electric fuel and purchased power excluding Otay Mesa VIE.
 

SDG&E’s cost of electric fuel and purchased power decreased by $35 million (5%) to $637 million for 2010. This decrease was primarily due to a $32 million decrease in the cost of power purchased from third-party generators as a result of the start up of new power generation at Otay Mesa VIE, which commenced commercial operations in the fourth quarter of 2009, along with a $3 million decrease in other fuel and purchased power costs. Associated with this decrease, SDG&E’s operating costs increased by $32 million from Otay Mesa VIE’s operations.
 
We do not include in the Consolidated Statements of Operations the commodity costs (and the revenues to recover those costs) associated with long-term contracts that are allocated to SDG&E by the California DWR. However, we do include the associated volumes and distribution revenues in the table above. We provide further discussion of these contracts in Notes 1 and 14 of the Notes to Consolidated Financial Statements.
 
 
SDG&E and SoCalGas: Natural Gas Revenues and Cost of Natural Gas
 
The following tables show natural gas revenues for SDG&E and SoCalGas. Because the cost of natural gas is recovered in rates, changes in the cost are reflected in the changes in revenues. In addition to the change in market prices, natural gas revenues recorded during a period are impacted by the difference between customer billings and recorded or CPUC-authorized costs.  These differences are required to be balanced over time, resulting in over- and undercollected regulatory balancing accounts. We discuss balancing accounts and their effects further in Note 1 of the Notes to Consolidated Financial Statements.
 

SDG&E: NATURAL GAS SALES AND TRANSPORTATION 2009-2011
(Volumes in billion cubic feet, dollars in millions)
 
 
 
 
 
 
 
 
 
Natural Gas Sales
Transportation
Total
Customer class
Volumes
Revenue
Volumes
Revenue
Volumes
Revenue
2011:
 
 
 
 
 
 
 
 
 
    Residential
 32 
$
 341 
 ― 
$
 1 
 32 
$
 342 
    Commercial and industrial
 15 
 
 103 
 8 
 
 10 
 23 
 
 113 
    Electric generation plants
 ― 
 
 ― 
 25 
 
 8 
 25 
 
 8 
 
 47 
$
 444 
 33 
$
 19 
 80 
 
 463 
    Other revenues
 
 
 
 
 
 
 
 
 36 
    Balancing accounts
 
 
 
 
 
 
 
 
 44 
        Total(1)
 
 
 
 
 
 
 
$
 543 
2010:
 
 
 
 
 
 
 
 
 
    Residential
 31 
$
 340 
 ― 
$
 ― 
 31 
$
 340 
    Commercial and industrial
 14 
 
 106 
 8 
 
 12 
 22 
 
 118 
    Electric generation plants
 ― 
 
 ― 
 28 
 
 7 
 28 
 
 7 
 
 45 
$
 446 
 36 
$
 19 
 81 
 
 465 
    Other revenues
 
 
 
 
 
 
 
 
 36 
    Balancing accounts
 
 
 
 
 
 
 
 
 13 
        Total(1)
 
 
 
 
 
 
 
$
 514 
2009:
 
 
 
 
 
 
 
 
 
    Residential
 30 
$
 304 
 ― 
$
 ― 
 30 
$
 304 
    Commercial and industrial
 15 
 
 100 
 7 
 
 10 
 22 
 
 110 
    Electric generation plants
 ― 
 
 ― 
 65 
 
 19 
 65 
 
 19 
 
 45 
$
 404 
 72 
$
 29 
 117 
 
 433 
    Other revenues
 
 
 
 
 
 
 
 
 33 
    Balancing accounts
 
 
 
 
 
 
 
 
 24 
        Total(1)
 
 
 
 
 
 
 
$
 490 
(1) Includes sales to affiliates of $1 million in each of 2011, 2010 and 2009.

SDG&E’s natural gas revenues increased by $29 million (6%) to $543 million in 2011 and the cost of natural gas sold increased by $9 million (4%) to $226 million. The increase in revenues was primarily due to:
 
§  
$9 million higher recovery of CPUC-authorized costs, which revenues are fully offset in operation and maintenance expenses;
 
§  
an increase in cost of natural gas, which was caused primarily by higher volumes sold and higher natural gas prices, as we discuss below; and
 
§  
$8 million higher authorized base margin.
 
In 2010, SDG&E’s natural gas revenues increased by $24 million (5%) to $514 million, and the cost of natural gas increased by $11 million (5%) to $217 million. The increase in revenues was primarily due to:
 
§  
$15 million higher recovery of CPUC-authorized costs, which revenues are fully offset in operation and maintenance expenses;
 
§  
the increase in cost of natural gas, which was caused primarily by higher natural gas prices, as we discuss below; and
 
§  
$6 million higher authorized base margin.
 
The average cost of natural gas was $4.83 per thousand cubic feet (Mcf) for 2011, $4.79 per Mcf for 2010 and $4.61 per Mcf for 2009. In 2011, the 1-percent increase of $0.04 per Mcf resulted in higher revenues and cost of $2 million compared to 2010. In 2010, the 4-percent increase of $0.18 per Mcf resulted in higher revenues and cost of $8 million compared to 2009.
 
SOCALGAS: NATURAL GAS SALES AND TRANSPORTATION 2009-2011
(Volumes in billion cubic feet, dollars in millions)
 
 
 
 
 
 
 
 
 
Natural Gas Sales
Transportation
Total
Customer class
Volumes
Revenue
Volumes
Revenue
Volumes
Revenue
2011:
 
 
 
 
 
 
 
 
 
    Residential
 253 
$
 2,358 
 1 
$
 4 
 254 
$
 2,362 
    Commercial and industrial
 103 
 
 759 
 272 
 
 219 
 375 
 
 978 
    Electric generation plants
 ― 
 
 ― 
 166 
 
 42 
 166 
 
 42 
    Wholesale
 ― 
 
 ― 
 148 
 
 19 
 148 
 
 19 
 
 356 
$
 3,117 
 587 
$
 284 
 943 
 
 3,401 
    Other revenues
 
 
 
 
 
 
 
 
 99 
    Balancing accounts
 
 
 
 
 
 
 
 
 316 
        Total(1)
 
 
 
 
 
 
 
$
 3,816 
2010:
 
 
 
 
 
 
 
 
 
    Residential
 245 
$
 2,302 
 1 
$
 4 
 246 
$
 2,306 
    Commercial and industrial
 102 
 
 763 
 268 
 
 228 
 370 
 
 991 
    Electric generation plants
 ― 
 
 ― 
 187 
 
 44 
 187 
 
 44 
    Wholesale
 ― 
 
 ― 
 149 
 
 15 
 149 
 
 15 
 
 347 
$
 3,065 
 605 
$
 291 
 952 
 
 3,356 
    Other revenues
 
 
 
 
 
 
 
 
 92 
    Balancing accounts
 
 
 
 
 
 
 
 
 374 
        Total(1)
 
 
 
 
 
 
 
$
 3,822 
2009:
 
 
 
 
 
 
 
 
 
    Residential
 234 
$
 2,032 
 1 
$
 3 
 235 
$
 2,035 
    Commercial and industrial
 101 
 
 674 
 264 
 
 219 
 365 
 
 893 
    Electric generation plants
 ― 
 
 ― 
 200 
 
 48 
 200 
 
 48 
    Wholesale
 ― 
 
 ― 
 141 
 
 13 
 141 
 
 13 
 
 335 
$
 2,706 
 606 
$
 283 
 941 
 
 2,989 
    Other revenues
 
 
 
 
 
 
 
 
 105 
    Balancing accounts
 
 
 
 
 
 
 
 
 261 
        Total(1)
 
 
 
 
 
 
 
$
 3,355 
(1) Includes sales to affiliates of $53 million in 2011, $44 million in 2010, and $43 million in 2009.

SoCalGas’ natural gas revenues in 2011 were essentially unchanged when compared to 2010 at $3.8 billion, while the cost of natural gas sold decreased by $131 million (8%) to $1.6 billion in 2011 compared to 2010.  Natural gas revenues in 2011 compared to 2010 were impacted by:
 
§  
the decrease in cost of natural gas sold, which was caused primarily by lower natural gas prices, as we discuss below, offset by higher volumes sold; and
 
§  
$12 million lower regulatory awards in 2011; offset by
 
§  
$96 million higher recovery of CPUC-authorized costs, which revenues are fully offset in operation and maintenance expenses; and
 
§  
$54 million higher authorized base margin.
 
In 2010, SoCalGas’ natural gas revenues increased by $467 million (14%) to $3.8 billion, and the cost of natural gas increased by $356 million (27%) to $1.7 billion. The increase in revenues in 2010 was primarily due to:
 
§  
the increase in cost of natural gas, which was caused primarily by higher natural gas prices, as we discuss below, and higher volumes due to colder weather in late 2010;
 
§  
$52 million higher authorized base margin;
 
§  
$32 million higher recovery of CPUC-authorized costs, which revenues are fully offset in operation and maintenance expenses; and
 
§  
$13 million higher regulatory awards in 2010.
 
The average cost of natural gas was $4.41 per Mcf for 2011, $4.90 per Mcf for 2010, and $4.00 per Mcf for 2009. In 2011, the 10-percent decrease of $0.49 per Mcf resulted in lower revenues and cost of $175 million compared to 2010. In 2010, the 23-percent increase of $0.90 per Mcf resulted in higher revenues and cost of $310 million compared to 2009.
 
 
Sempra Pipelines & Storage Utilities: Revenues and Cost of Sales
 
Sempra Pipelines & Storage’s utilities are Chilquinta Energía, Luz del Sur, Mobile Gas and Ecogas.
 
Revenues generated by Chilquinta Energía and Luz del Sur are based on tariffs that are set by government agencies in their respective countries based on an efficient model distribution company defined by those agencies. The basis for the tariffs do not meet the requirement necessary for treatment under applicable accounting principles generally accepted in the United States of America (GAAP) for regulatory accounting. We discuss revenue recognition further for Chilquinta Energía and Luz del Sur in Note 1 of the Notes to Consolidated Financial Statements.
 
Operations of Mobile Gas and Ecogas qualify for regulatory accounting treatment under applicable GAAP, similar to the Sempra Utilities.
 
The table below summarizes natural gas and electric revenue for Sempra Pipelines & Storage’s utilities:
 
SEMPRA PIPELINES & STORAGE UTILITIES: NATURAL GAS AND ELECTRIC REVENUE 2009-2011
(Dollars in millions)
 
2011 
2010 
2009 
Customer class
Volumes
Revenue
Volumes
Revenue
Volumes
Revenue
Natural Gas Sales (billion cubic feet):
 
 
 
 
 
 
 
 
 
Mobile Gas
 40 
$
 93 
 37 
$
 106 
 32 
$
 112 
Ecogas
 22 
 
 91 
 21 
 
 94 
 19 
 
 89 
    Total
 62 
$
 184 
 58 
$
 200 
 51 
$
 201 
 
 
 
 
 
 
 
 
 
 
Electric Sales (million kilowatt hours)(1):
 
 
 
 
 
 
 
 
 
Luz del Sur
 4,715 
$
 487 
 ― 
$
 ― 
 ― 
$
 ― 
Chilquinta Energía
 1,859 
 
 481 
 ― 
 
 ― 
 ― 
 
 ― 
 
 6,574 
 
 968 
 ― 
 
 ― 
 ― 
 
 ― 
Other service revenues
 
 
 41 
 
 
 ― 
 
 
 ― 
    Total
 
$
 1,009 
 
$
 ― 
 
$
 ― 
(1) Luz del Sur and Chilquinta Energía were accounted for under the equity method until April 6, 2011, when they became consolidated entities upon our acquisition of additional ownership interests.

 
Energy-Related Businesses: Revenues and Cost of Sales
 
The table below shows revenues and cost of sales for our energy-related businesses.
 
ENERGY-RELATED BUSINESSES: REVENUES AND COST OF SALES 2009-2011
(Dollars in millions)
 
 
Years ended December 31,
 
 
2011 
2010 
2009 
REVENUES
 
 
 
 
 
 
 
 
 
 
 
 
    Sempra Generation
$
 886 
 52 
%
$
 1,172 
 59 
%
$
 1,179 
 70 
%
    Sempra Pipelines & Storage
 
 250 
 14 
 
 
 150 
 8 
 
 
 264 
 16 
 
    Sempra LNG
 
 714 
 42 
 
 
 711 
 36 
 
 
 278 
 16 
 
    Parent and other(1)
 
 (136)
 (8)
 
 
 (49)
 (3)
 
 
 (36)
 (2)
 
        Total revenues
$
 1,714 
 100 
%
$
 1,984 
 100 
%
$
 1,685 
 100 
%
COST OF SALES(2)
 
 
 
 
 
 
 
 
 
 
 
 
    Sempra Generation
$
 478 
 64 
%
$
 656 
 63 
%
$
 668 
 77 
%
    Sempra Pipelines & Storage
 
 17 
 2 
 
 
 14 
 1 
 
 
 131 
 15 
 
    Sempra LNG
 
 386 
 52 
 
 
 426 
 41 
 
 
 108 
 13 
 
    Parent and other(1)
 
 (135)
 (18)
 
 
 (50)
 (5)
 
 
 (43)
 (5)
 
        Total cost of natural gas, electric fuel
 
 
 
 
 
 
 
 
 
 
 
 
            and purchased power
$
 746 
 100 
%
$
 1,046 
 100 
%
$
 864 
 100 
%
    Sempra Generation
$
 79 
 58 
%
$
 78 
 89 
%
$
 62 
 80 
%
    Sempra Pipelines & Storage
 
 45 
 33 
 
 
 ― 
 ― 
 
 
 ― 
 ― 
 
    Sempra LNG
 
 13 
 9 
 
 
 11 
 12 
 
 
 16 
 21 
 
    Parent and other(1)
 
 ― 
 ― 
 
 
 (1)
 (1)
 
 
 (1)
 (1)
 
        Total other cost of sales
$
 137 
 100 
%
$
 88 
 100 
%
$
 77 
 100 
%
(1)
Includes eliminations of intercompany activity.
(2)
Excludes depreciation and amortization, which are shown separately on the Consolidated Statements of Operations.
 
Energy-Related Businesses: Revenues and Cost of Sales
 
Revenues from our energy-related businesses decreased by $270 million (14%) to $1.7 billion in 2011 compared to 2010. The decrease included
 
§  
$286 million lower revenues at Sempra Generation due to decreased power sales primarily from the end of the DWR contract as of September 30, 2011, and less favorable pricing; offset by
 
§  
$100 million higher revenues at Sempra Pipelines & Storage, including $70 million from the consolidation of revenues of Tecnored and Tecsur, two energy-services companies we acquired in April 2011, and $34 million from natural gas storage and marketing operations; and
 
§  
higher revenues at Sempra LNG from contractual counterparty obligations for non-delivery of cargoes, offset by lower natural gas revenues in 2011.
 
The cost of natural gas, electric fuel and purchased power from our energy-related businesses decreased by $300 million (29%) to $746 million in 2011 compared to 2010. The decrease was primarily driven by the lower revenues at Sempra Generation and the lower natural gas revenues at Sempra LNG.
 
Increased intersegment activity, eliminated in consolidation, also contributed to the lower total revenues and cost of sales in 2011.
 
In 2010, revenues from our energy-related businesses increased by $299 million (18%) to $2.0 billion. The increase included
 
§  
$433 million higher revenues at Sempra LNG, primarily due to increased marketing operations and the start up of operations at its Cameron LNG terminal and the nitrogen-injection facility at the Energía Costa Azul terminal; offset by
 
§  
$123 million lower revenues at Sempra Pipelines & Storage due to the expiration of the CFE natural gas supply contract in 2009. At the expiration of the contract, Sempra LNG began supplying the CFE under a separate contract ending December 2022.
 
Cost of natural gas, electric fuel and purchased power from our energy-related businesses increased by $182 million (21%) to $1.0 billion in 2010. The increase over 2009 was primarily associated with the higher revenues at Sempra LNG, partially offset by a decrease associated with the lower revenues at Sempra Pipelines & Storage.
 
In 2011, other cost of sales from our energy-related businesses increased by $49 million (56%) to $137 million primarily due to the consolidation of Tecnored and Tecsur starting in April 2011. Compared to 2009, our other cost of sales increased by $11 million (14%) to $88 million in 2010.
 
 
Operation and Maintenance (including Litigation Expense)
 
In the table below, we provide a breakdown of our business units’ operation and maintenance expenses.
 
OPERATION AND MAINTENANCE(1) 2009-2011
(Dollars in millions)
 
 
Years ended December 31,
 
 
2011 
2010 
2009 
Sempra Utilities:
 
 
 
 
 
 
 
 
 
 
 
 
    SDG&E
$
 1,072 
 38 
%
$
 987 
 37 
%
$
 960 
 39 
%
    SoCalGas
 
 1,305 
 46 
 
 
 1,174 
 44 
 
 
 1,138 
 46 
 
Sempra Global:
 
 
 
 
 
 
 
 
 
 
 
 
    Sempra Generation
 
 106 
 4 
 
 
 268 
 10 
 
 
 108 
 4 
 
    Sempra Pipelines & Storage
 
 227 
 8 
 
 
 105 
 4 
 
 
 83 
 3 
 
    Sempra LNG
 
 86 
 3 
 
 
 83 
 3 
 
 
 94 
 4 
 
Parent and other(2)
 
 29 
 1 
 
 
 51 
 2 
 
 
 88 
 4 
 
Total operation and maintenance
$
 2,825 
 100 
%
$
 2,668 
 100 
%
$
 2,471 
 100 
%
(1)
Includes Litigation Expense and Other Operation and Maintenance for Sempra Energy Consolidated.
(2)
Includes intercompany eliminations recorded in consolidation.

Sempra Energy Consolidated
 
Our other operation and maintenance expenses increased by $157 million (6%) to $2.8 billion in 2011 primarily due to:
 
§  
higher operation and maintenance expenses at the Sempra Utilities, as we discuss below; and
 
§  
$122 million at Sempra Pipelines & Storage, including $106 million from the consolidation of expenses of entities in Chile and Peru in 2011; offset by
 
§  
$162 million lower operation and maintenance expenses at Sempra Generation, including $145 million litigation expense in 2010 related to an agreement to settle certain energy crisis litigation, major scheduled plant maintenance in 2010 at the Mexicali and Mesquite power plants, and from the sale of El Dorado as of October 1, 2011; and
 
§  
$22 million lower operation and maintenance expenses at Parent and Other, which included $9 million litigation expense in 2010 related to an agreement to settle certain energy crisis litigation and lower other operation and maintenance expenses associated with our former commodities-marketing businesses, including transaction costs in 2010 related to the sales within RBS Sempra Commodities.
 
The $197 million (8%) increase in our operation and maintenance expenses in 2010 compared to 2009 included
 
§  
$160 million from Sempra Generation, primarily due to $145 million of litigation expense in 2010 related to an agreement to settle certain energy crisis litigation; and
 
§  
higher operation and maintenance expenses at the Sempra Utilities, as we discuss below; offset by
 
§  
$37 million lower operation and maintenance expenses at Parent and Other, primarily due to a reorganization in early 2010 that eliminated some central functions and moved other functions to the business units. This resulted in a reduction in general and administrative costs and also moved costs previously recognized by Parent and Other to the business units. The decrease was offset by higher operation and maintenance expenses at our former commodities-marketing businesses, including transaction costs related to the sales within RBS Sempra Commodities and $9 million litigation expense in 2010.
 

SDG&E
 
SDG&E’s operation and maintenance expenses increased by $85 million (9%) to $1.1 billion in 2011 primarily due to:
 
§  
$46 million higher other operational and maintenance costs, including a $15 million increase in liability insurance premiums for wildfire coverage; and
 
§  
$38 million higher recoverable expenses, primarily from expenses associated with customer distributed generation incentive programs and transmission expenses.
 
In 2010, SDG&E’s operation and maintenance expenses increased by $27 million (3%) compared to 2009 primarily due to:
 
§  
$19 million higher other operational and maintenance costs, including:
 
·  
$29 million higher liability insurance premiums for wildfire coverage and
 
·  
$13 million at Otay Mesa VIE, offset by
 
·  
$15 million from the unfavorable resolution of a regulatory matter in 2009; and
 
§  
$23 million net unfavorable impact from an increase in litigation reserves in 2010 compared to the favorable resolution of litigation in 2009; offset by
 
§  
$16 million lower recoverable expenses.
 
SoCalGas
 
SoCalGas’ operation and maintenance expenses increased by $131 million (11%) to $1.3 billion in 2011 primarily due to:
 
§  
$96 million higher recoverable expenses, primarily from expenses associated with energy efficiency and employee benefit programs;
 
§  
$20 million higher other operational and maintenance costs; and
 
§  
$5 million litigation expense in 2011 compared to a $10 million favorable impact from the resolution of a litigation matter in 2010.
 
In 2010, SoCalGas’ operation and maintenance expenses increased by $36 million (3%) compared to 2009 due to:
 
§  
$32 million higher recoverable expenses, primarily from expenses associated with energy efficiency programs; and
 
§  
$17 million higher other operational and maintenance costs; offset by
 
§  
$13 million net favorable impact from a favorable resolution of litigation reserves in 2010 compared to litigation expense in 2009.
 
 
Depreciation and Amortization
 
Sempra Energy Consolidated
 
Our depreciation and amortization expense was
 
§  
$978 million in 2011
 
§  
$867 million in 2010
 
§  
$775 million in 2009
 
The increase in 2011 included
 
§  
$48 million at Sempra Pipelines & Storage, including $40 million from the consolidation of entities in Chile and Peru in 2011;
 
§  
$41 million at SDG&E, primarily from higher electric plant depreciation; and
 
§  
$22 million at SoCalGas from an increase in net utility plant base.
 
The increase in 2010 compared to 2009 included
 
§  
$52 million at SDG&E, primarily from higher electric plant depreciation, including a full year of operations at Otay Mesa VIE;
 
§  
$16 million at SoCalGas from an increase in net utility plant base; and
 
§  
$16 million at Sempra LNG due to the start up of the Cameron LNG terminal and Energía Costa Azul LNG nitrogen injection facility in the second half of 2009.
 
 
Write-off of Long-lived Assets
 
In 2009, we recorded a $132 million write-off related to certain assets at one of Sempra Pipelines & Storage’s Liberty natural gas storage projects. Sempra Energy’s after-tax share of this write-off was $64 million. We discuss the write-off of the assets in Note 1 of the Notes to Consolidated Financial Statements.
 
 
Equity Earnings (Losses), Before Income Tax
 
Sempra Energy Consolidated
 
Earnings (losses) from our investment in RBS Sempra Commodities, which was formed in April 2008, were
 
§  
$(24) million in 2011
 
§  
$(314) million in 2010
 
§  
$463 million in 2009
 
We and RBS, our partner in the joint venture, sold substantially all of the partnership’s businesses and assets in four separate transactions completed in July, November and December of 2010 and February of 2011. Results for 2011 include a $16 million pretax write-down of our investment in RBS Sempra Commodities.
 
Equity earnings from our investment in RBS Sempra Commodities were adversely impacted by several factors in 2010, as we discuss in “Business Unit Results—Parent and Other.” Results for 2010 include a $305 million pretax write-down of our investment in RBS Sempra Commodities. This amount includes a $480 million loss related to the U.S. portion of our investment, partially offset by a $175 million gain on the non-U.S. portion. We discuss the write-down and additional information about the determination and allocation of this investment’s earnings in Note 4 of the Notes to Consolidated Financial Statements.
 
Equity earnings, before income tax, from our other equity method investments were
 
§  
$33 million in 2011
 
§  
$22 million in 2010
 
§  
$36 million in 2009
 
The increase in equity earnings, before income tax, in 2011 was primarily due to:
 
§  
$13 million of losses in 2010 from Sempra Generation’s investment in Elk Hills, including a $10 million loss on the sale of the investment in December 2010; and
 
§  
$5 million decreased losses from our investments in housing partnerships; offset by
 
§  
$6 million of equity losses in 2011 from renewables projects at Sempra Generation compared to $1 million of equity earnings in 2010.
 
In 2010, the decrease in our equity earnings before income taxes from other equity method investments was primarily due to the loss on the sale of Elk Hills in 2010. We provide further details about our investment in RBS Sempra Commodities and other equity method investments in Note 4 of the Notes to Consolidated Financial Statements.
 
 
Remeasurement of Equity Method Investments
 
In the second quarter of 2011, we recorded a $277 million non-taxable gain from the remeasurement of our equity method investments in Chilquinta Energía in Chile and Luz del Sur in Peru.  We provide additional discussion related to this gain below in “Income Taxes” and in Note 3 of the Notes to Consolidated Financial Statements.
 
 
Other Income, Net
 
Sempra Energy Consolidated
 
Other income, net, was
 
§  
$130 million in 2011
 
§  
$140 million in 2010
 
§  
$149 million in 2009
 
We include here the allowance for equity funds used during construction (AFUDC) at the Sempra Utilities, interest on regulatory balancing accounts, gains and losses from our investments and interest rate swaps, and other sundry amounts.
 

Other income, net, decreased by $10 million (7%) in 2011 primarily due to:
 
§  
proceeds of $48 million from a legal settlement at Sempra Pipelines & Storage in 2010; offset by
 
§  
$37 million increase in equity-related AFUDC in 2011 attributable to SDG&E primarily associated with the construction of the Sunrise Powerlink electric transmission line; and
 
§  
$10 million lower losses on interest rate and foreign exchange instruments, including $34 million of losses on interest rate instruments in 2010 related to Otay Mesa VIE (discussed below), offset by a $15 million Mexican peso exchange loss in 2011 (discussed in “Income Taxes – Mexican Currency Exchange Rate and Inflation Impact on Income Taxes and Related Economic Hedging Activity” below) and a $10 million gain recognized on an interest rate instrument in 2010 at Parent and Other.
 
The decrease in other income, net, in 2010 compared to 2009 was primarily due to:
 
§  
$34 million in losses on interest rate instruments in 2010 at Otay Mesa VIE compared to $27 million in gains in 2009; and
 
§  
a $20 million decrease in gains from investment activity related to our executive retirement and deferred compensation plans in 2010; offset by
 
§  
proceeds of $48 million from a legal settlement in 2010 at Sempra Pipelines & Storage;
 
§  
$18 million increase in AFUDC, including $14 million at SDG&E primarily due to construction on the Sunrise Powerlink project; and
 
§  
a $10 million gain recognized on an interest rate instrument in 2010 at Parent and Other.
 
SDG&E
 
Other income, net, was
 
§  
$79 million in 2011
 
§  
$10 million in 2010
 
§  
$64 million in 2009
 
Other income, net, increased by $69 million in 2011 primarily due to:
 
§  
$37 million increase in AFUDC primarily due to construction on the Sunrise Powerlink project; and
 
§  
$34 million of losses on interest rate instruments at Otay Mesa VIE in 2010. Otay Mesa VIE’s interest rate instrument’s activity was designated as a cash flow hedge as of April 1, 2011.
 
The decrease in other income, net, in 2010 compared to 2009 was primarily due to:
 
§  
$34 million in losses on interest rate instruments in 2010 at Otay Mesa VIE compared to $27 million in gains in 2009; offset by
 
§  
$14 million increase in AFUDC primarily due to construction on the Sunrise Powerlink project.
 
We provide further details of the components of other income, net, in Note 1 of the Notes to Consolidated Financial Statements.
 
 
Interest Expense
 
The table below shows the interest expense for Sempra Energy Consolidated, SDG&E and SoCalGas.
 

INTEREST EXPENSE 2009-2011
(Dollars in millions)
 
Years ended December 31,
 
2011 
2010 
2009 
Sempra Energy Consolidated
$
 465 
$
 436 
$
 367 
SDG&E
 
 142 
 
 136 
 
 104 
SoCalGas
 
 69 
 
 66 
 
 68 


Sempra Energy Consolidated
 
In 2011, our interest expense increased by $29 million (7%) primarily due to:
 
§  
$41 million at Sempra Pipelines & Storage, primarily from the consolidation of Chile and Peru in April 2011, and from lower capitalized interest in 2011 due to natural gas storage caverns at Bay Gas Storage, LLC (Bay Gas) and Mississippi Hub, LLC (Mississippi Hub) going into service; and
 
§  
$6 million at SDG&E, which we discuss below; offset by
 
§  
$6 million lower interest expense related to energy crisis litigation reserves at Parent and Other; and
 
§  
$5 million higher capitalized interest associated with renewables projects at Sempra Generation.
 
Our interest expense increased by $69 million (19%) in 2010 compared to 2009 due to:
 
§  
$80 million higher interest expense, primarily from long-term debt issued in 2009 and 2010 at Parent and Other and SDG&E;
 
§  
$27 million lower capitalized interest, primarily at Sempra LNG due to completion of construction projects; and
 
§  
$14 million in interest expense at Otay Mesa VIE in 2010; offset by
 
§  
$30 million lower interest expense from maturities of debt at Parent and Other; and
 
§  
$16 million lower short-term debt interest expense, primarily from lower average commercial paper borrowings and interest rates, and reduced interest expense related to energy crisis litigation reserves at Parent and Other.
 
SDG&E
 
Interest expense for SDG&E increased by $6 million (4%) in 2011 primarily due to issuances of long-term debt in 2011 and 2010, partially offset by higher AFUDC related to debt.
 
SDG&E’s interest expense increased by $32 million (31%) in 2010 compared to 2009, primarily from long-term debt issued in 2009 and 2010, and from interest expense at Otay Mesa VIE in 2010.
 
 
Income Taxes
 
The table below shows the income tax expense and effective income tax rates for Sempra Energy, SDG&E and SoCalGas.
 
INCOME TAX EXPENSE AND EFFECTIVE INCOME TAX RATES 2009-2011
(Dollars in millions)
 
Years ended December 31,
 
 
 
2011 
 
2010 
 
2009 
 
 
 
Income Tax
 
Effective Income
 
 
Income Tax
 
Effective Income
 
 
Income Tax
 
Effective Income
 
 
 
 
Expense
 
Tax Rate
 
 
Expense
 
Tax Rate
 
 
Expense
 
Tax Rate
 
Sempra Energy Consolidated
$
 366 
 
 21 
%
$
 102 
 
 13 
%
$
 422 
 
 29 
%
SDG&E
 
 237 
 
 34 
 
 
 173 
 
 33 
 
 
 177 
 
 32 
 
SoCalGas
 
 143 
 
 33 
 
 
 176 
 
 38 
 
 
 144 
 
 34 
 
 
 
 
Sempra Energy Consolidated
 
Sempra Energy’s income tax expense increased in 2011 due to both higher pretax income and a higher effective income tax rate. Nonrecurring events in both 2011 and 2010, related to our acquisitions in South America and the sale transactions within RBS Sempra Commodities, respectively, significantly impacted both the pretax income and the effective rate in both years. The higher rate in 2011 compared to 2010, including these impacts and others, was primarily due to:
 
§  
a lower percentage of pretax income in 2011 compared to 2010 in countries with lower statutory rates. The activity in each year related primarily to:
 
§  
in 2011, a $277 million non-taxable gain related to the remeasurement of our equity method investments in South America, as we discuss in Note 3 of the Notes to Consolidated Financial Statements
 
§  
in 2010, activity related to RBS Sempra Commodities, including a large non-taxable gain related to our share of the RBS Sempra Commodities sale to J.P. Morgan Ventures, as we discuss below
 
§  
lower renewable energy income tax credits;
 
§  
favorable adjustments in 2010 related to prior years’ income tax issues;
 
§  
higher state income taxes; and
 
§  
lower favorable impact from deductions for self-developed software costs at the Sempra Utilities; offset by
 
§  
tax benefit in 2011 versus tax expense in 2010 due to Mexican currency translation and inflation adjustments;
 
§  
higher book depreciation over income tax depreciation related to a certain portion of utility plant fixed assets;
 
§  
a $16 million write-down in 2010 of the deferred tax assets related to other postretirement benefits, as a result of a change in U.S. tax law that eliminates a future deduction, starting in 2013, for retiree healthcare funded by the Medicare Part D subsidy; and
 
§  
the impact of Otay Mesa VIE, as we discuss below.
 
As noted above, the effective income tax rate in 2010 was low primarily due to the following related to RBS Sempra Commodities:
 
§  
approximately $150 million of a total $175 million non-U.S. gain on sale of the businesses and assets within the joint venture was non-taxable; and
 
§  
approximately $40 million non-U.S. earnings from the operations of the joint venture and approximately $25 million of the non-U.S. gain on sale of the businesses and assets within the joint venture were net of income tax paid by the partnership.
 
Sempra Energy’s income tax expense and effective income tax rate decreased in 2010 compared to 2009, primarily due to lower pretax income and the impact on the rate of the 2010 activity related to RBS Sempra Commodities discussed above. The lower rate was also due to:
 
§  
higher renewable energy income tax credits;
 
§  
higher exclusions from taxable income of the equity portion of AFUDC; and
 
§  
higher favorable adjustments related to prior years’ income tax issues; offset by
 
§  
a $16 million write-down of the deferred tax assets related to other postretirement benefits, as a result of a change in U.S. tax law that eliminates a future deduction, starting in 2013, for retiree healthcare funded by the Medicare Part D subsidy;
 
§  
higher impact from tax expense in 2010 due to Mexican currency translation and inflation adjustments;
 
§  
the impact of Otay Mesa VIE, as we discuss below;
 
§  
$11 million state income tax expense related to our exit from the RBS Sempra Commodities business; and
 
§  
higher book depreciation over income tax depreciation related to a certain portion of utility plant fixed assets.
 
The results for Sempra Energy Consolidated and SDG&E include Otay Mesa VIE, which is consolidated, and therefore, Sempra Energy Consolidated’s and SDG&E’s effective income tax rates are impacted by the VIE’s stand-alone effective income tax rate. This impact caused Sempra Energy Consolidated’s rate to increase (decrease) by the following percentage points: 0 in 2011, 1 in 2010 and (1) in 2009, and caused SDG&E’s rate to increase (decrease) by the following percentage points: (1) in 2011, 1 in 2010 and (2) in 2009.
 
We report as part of our pretax results the income or loss attributable to noncontrolling interests. However, we do not record income taxes for this income or loss, as our entities with noncontrolling interests are currently treated as partnerships for income tax purposes and thus we are only liable for income taxes on the portion of the earnings that are allocated to us. As our entities with noncontrolling interests grow, and as we may continue to invest in such entities, the impact on our effective income tax rate may become more significant.
 
In 2009, Sempra Energy recorded an income tax benefit of $35 million from the write-off of assets at Liberty, which we discuss in Note 1 of the Notes to Consolidated Financial Statements. This tax benefit was due to a non-recurring event in 2009.
 
In 2012, Sempra Energy intends to change the accounting methodology that it currently uses to recognize investment tax credits, which currently impacts only those credits associated with Sempra Generation’s solar projects. Through December 31, 2011, Sempra Generation used what is referred to as the flow-through method of accounting in which the investment tax credits associated with a project are recognized as a reduction of tax expense in the year in which capacity is placed in service. Starting in the first quarter of 2012, Sempra Generation will change to the deferral method of accounting for these projects. Under this methodology, instead of recognizing the investment tax credit, Sempra Generation will reduce the book basis of the asset by the amount of the tax credit. This results in lower book depreciation and therefore higher future earnings as compared to our current method. This change in accounting principle will be applied retrospectively in the first quarter of 2012. The resulting decrease in net income and earnings from retroactively adopting the deferral method is estimated to be $26 million and $30 million for the years ended December 31, 2011 and 2010, respectively, and a negligible amount for the year ended December 31, 2009.
 
In 2012, we anticipate that our effective tax rate will increase from 21% to approximately 29% as a result of the change in accounting for investment tax credits from the flow-through method to the deferral method. In the years 2013 through 2016, we are currently projecting that our effective income tax rate will be approximately 30% to 32%. This increase in effective income tax rates is primarily due to: projected increases in pretax income; decreases in favorable tax deductions for self-developed software costs; increases in the amount by which book depreciation exceeds normalized tax depreciation; and lower exclusions from income for the equity portion of AFUDC. These projected effective tax rates do not include any impact from a possible repatriation of future earnings from our Mexican and Peruvian subsidiaries. If we were to repatriate future foreign earnings, as we discuss below, the rates would increase accordingly.
 
SDG&E
 
SDG&E’s income tax expense increased in 2011, primarily due to higher pretax book income and a higher effective tax rate. The higher rate in 2011 compared to 2010 was primarily due to:
 
§  
favorable adjustments in 2010 related to prior years’ income tax issues; offset by
 
§  
higher exclusions from taxable income of the equity portion of AFUDC;
 
§  
the impact of Otay Mesa VIE, as we discuss above;
 
§  
higher deductions for self-developed software costs;
 
§  
lower impact from higher book depreciation over income tax depreciation related to a certain portion of utility plant fixed assets; and
 
§  
a $3 million write-down in 2010 of the deferred tax assets related to other postretirement benefits as a result of a change in U.S. tax law, as we discuss above.
 
SDG&E’s income tax expense decreased in 2010 compared to 2009 primarily from lower pretax income, partially offset by a higher effective income tax rate resulting primarily from:
 
§  
the impact of Otay Mesa VIE, as we discuss above;
 
§  
a $3 million write-down of the deferred tax assets related to other postretirement benefits as a result of a change in U.S. tax law, as we discuss above; and
 
§  
higher book depreciation over income tax depreciation related to a certain portion of utility plant fixed assets; offset by
 
§  
higher exclusions from taxable income of the equity portion of AFUDC; and
 
§  
higher favorable adjustments related to prior years’ income tax issues.
 
In 2012, we anticipate that SDG&E’s effective income tax rate will increase from 34% to approximately 36%, due to a projected rise in pretax income, combined with a decrease in favorable income tax deductions for self-developed software costs (due to completion of SDG&E’s advanced meter project) and lower exclusions from income for the equity portion of AFUDC (due to the projected completion of construction on the Sunrise Powerlink electric transmission line). In the years 2013 through 2016, we are currently projecting that SDG&E’s effective income tax rate will be approximately 37%, due to projected increases in pretax income.
 
SoCalGas
 
SoCalGas’ income tax expense decreased in 2011, primarily due to lower pretax book income and a lower effective tax rate. The lower rate in 2011 compared to 2010 was primarily due to:
 
§  
a $13 million write-down in 2010 of the deferred tax assets related to other postretirement benefits as a result of a change in U.S. tax law, as we discuss above;
 
§  
higher deductions for self-developed software costs; and
 
§  
higher exclusions from taxable income of the equity portion of AFUDC; offset by
 
§  
higher book depreciation over income tax depreciation related to a certain portion of utility plant fixed assets.
 
Income tax expense increased in 2010 at SoCalGas primarily due to higher pretax income, as well as a higher effective income tax rate primarily due to a $13 million write-down of the deferred tax assets related to other postretirement benefits as a result of a change in U.S. tax law, as we discuss above.
 
In 2012, we anticipate that SoCalGas’ effective income tax rate will increase from 33% to approximately 37%, due to a projected rise in pretax income, combined with a decrease in favorable income tax deductions for self-developed software costs, and an increase in the amount by which book depreciation exceeds normalized tax depreciation. In the years 2013 through 2016, we are currently projecting that SoCalGas’ effective income tax rate will be approximately 40% to 42%, primarily due to projected increases in pretax income, combined with decreases in favorable income tax deductions for self-developed software costs, and an increase in the amount by which book depreciation exceeds normalized tax depreciation. 
 
In the variance discussions above, the following items are subject to flow-through treatment:
 
§  
the equity portion of AFUDC
 
§  
self-developed software costs
 
§  
depreciation on a certain portion of utility plant assets
 
We discuss the impact of items subject to flow-through treatment on our effective income tax rates in Note 7 of the Notes to Consolidated Financial Statements.
 
In December 2010, the Tax Relief, Unemployment Insurance Reauthorization, and Job Creation Act of 2010 (2010 Tax Act) was signed into law.  The 2010 Tax Act included the extension of bonus depreciation for U.S. federal income tax purposes for years 2010 through 2012 and an increase in the rate of bonus depreciation from 50 percent to 100 percent. This increased rate only applies to certain investments made after September 8, 2010 through December 31, 2012. Self-constructed property, where the construction period exceeds one year, construction starts between December 31, 2007 and January 1, 2013, and the property is placed in service by December 31, 2013, will qualify for bonus depreciation in 2013 at either the original or increased rate.
 
Due to the extension of bonus depreciation, Sempra Energy has generated a large U.S. federal net operating loss (NOL) in 2011 and is currently projecting a large U.S. federal NOL in 2012. We currently project the total NOL will not be fully utilized until 2016.  Because of these projected NOLs, and the carryforward of U.S. federal income tax credits discussed below, Sempra Energy expects no U.S. federal income tax payments in years 2012 through 2015.  However, because bonus depreciation only creates a temporary difference, versus a permanent difference, between Sempra Energy’s U.S. federal income tax return and its U.S. GAAP financial statements, it does not impact Sempra Energy’s effective income tax rate. We expect larger U.S. federal income tax payments in the future as these temporary differences reverse.
 
Bonus depreciation, in addition to impacting Sempra Energy’s U.S. federal income tax payments, will also have a temporary impact on Sempra Energy’s ability to utilize its U.S. federal income tax credits, which primarily are investment tax credits and production tax credits generated by Sempra Energy’s current and future renewable energy investments.  However, based on current projections, Sempra Energy does not expect, based on more-likely-than-not criteria required under U.S. GAAP, any of these income tax credits to expire prior to the end of their 20-year carryforward period, as allowed under current U.S. federal income tax law. We also expect bonus depreciation to increase the deferred tax component of SDG&E’s and SoCalGas’ rate base, which reduces rate base. 
 
We are currently considering the potential repatriation of future earnings beginning in 2013 from certain of our non-U.S. subsidiaries in Mexico and Peru. However, we expect to continue to indefinitely reinvest future earnings from our Chilean subsidiaries. Currently, all future repatriated earnings would be subject to U.S. income tax (with a credit for foreign income taxes) and future repatriations from Peru would be subject to local country withholding tax.  Because this potential repatriation would only be from future earnings, it does not change our current assertion, as we discuss in Note 7 of the Notes to Consolidated Financial Statements, that we intend to continue to indefinitely reinvest, for the foreseeable future, our cumulative undistributed non-U.S. earnings as of December 31, 2011. The forward-looking statements above on income tax matters do not include any impact from potential repatriation of future non-U.S. earnings.
 
Additionally, the 2010 Tax Act extended for years 2010 and 2011 the U.S. federal income tax law known as the look-through rule. This rule allows, under certain situations, for certain non-operating activity (e.g., dividend income, royalty income, interest income, rental income, etc.), of a greater than 50-percent owned non-U.S. subsidiary, to not be taxed under U.S. federal income tax law. If this rule is not extended beyond 2011, Sempra Energy’s effective income tax rate could potentially increase, over the amounts projected above, in subsequent years.
 
Mexican Currency Exchange Rate and Inflation Impact on Income Taxes and Related Economic Hedging Activity
 
Our Mexican subsidiaries have U.S. dollar denominated receivables and payables (monetary assets and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. They also have deferred income tax assets and liabilities that are denominated in the Mexican peso, which must be translated to U.S. dollars for financial reporting purposes. In addition, monetary assets and liabilities are adjusted for Mexican inflation for Mexican income tax purposes.
 
The fluctuations in both the currency exchange rate for the Mexican peso against the U.S. dollar, with regard to Mexican monetary assets and liabilities, and Mexican inflation are subject to Mexican income tax and thus expose us to significant fluctuations in our income tax expense.  The income tax expense of each of our Sempra Global business units is impacted by these factors. Parent and Other is also impacted due to a Mexican holding company. The impacts of these fluctuations at each business unit may offset to some extent at the consolidated level.
 
For Sempra Energy Consolidated, the impacts in 2009-2011 related to the factors described above are as follows:
 
MEXICAN CURRENCY IMPACT ON INCOME TAXES AND RELATED ECONOMIC HEDGING ACTIVITY
(Dollars in millions)
 
 
Years ended December 31,
 
 
2011 
2010 
2009 
Income tax benefit (expense) on currency exchange
 
 
 
 
 
 
 
rate movement of monetary assets and liabilities
$
 11 
$
 (10)
$
 (12)
Translation of non-U.S. deferred income tax balances
 
 11 
 
 (2)
 
 4 
Income tax expense on inflation
 
 (4)
 
 (7)
 
 (8)
 
Total impact on income taxes
 
 18 
 
 (19)
 
 (16)
After-tax losses on Mexican peso exchange rate
 
 
 
 
 
 
 
instruments (included in Other Income, Net)
 
 (9)
 
 ― 
 
 ― 
Net impacts on Sempra Energy Consolidated
 
 
 
 
 
 
 
Statements of Operations
$
 9 
$
 (19)
$
 (16)
 
Equity Earnings, Net of Income Tax
 
Sempra Energy Consolidated
 
Equity earnings of unconsolidated subsidiaries, net of income tax, which are primarily earnings from Sempra Pipelines & Storage’s equity method investments, were
 
§  
$52 million in 2011
 
§  
$49 million in 2010
 
§  
$68 million in 2009
 
The increase in 2011 was primarily due to:
 
§  
a $44 million pretax write-down of Sempra Pipelines & Storage’s investment in Argentina in 2010; and
 
§  
$10 million higher earnings related to the joint-venture interest acquired from El Paso Corporation in April 2010; offset by
 
§  
$50 million lower earnings related to equity method investments in Chile and Peru, for entities that are now consolidated.
 
Equity earnings, net of income tax, decreased in 2010 compared to 2009 primarily due to:
 
§  
the $44 million pretax write-down in Argentina in 2010; offset by
 
§  
$19 million earnings related to the joint-venture interest acquired from El Paso Corporation; and
 
§  
$13 million higher earnings from investments in Chile and Peru.
 
(Earnings) Losses Attributable to Noncontrolling Interests
 
Sempra Energy Consolidated
 
Earnings attributable to noncontrolling interests were $42 million in 2011 compared to losses of $16 million in 2010. The change was primarily due to:
 
§  
$19 million earnings attributable to noncontrolling interest in 2011 compared to losses of $16 million in 2010 at Otay Mesa VIE, which we discuss below; and
 
§  
$22 million earnings primarily from noncontrolling interests at Luz del Sur in 2011.
 
Losses attributable to noncontrolling interests increased by $9 million in 2010 compared to 2009 primarily due to:
 
§  
losses attributable to Otay Mesa VIE of $16 million in 2010 compared to earnings of $24 million in 2009, which we discuss below; offset by
 
§  
$33 million associated with the write-off of assets at Liberty in 2009.
 

SDG&E
 
Earnings attributable to noncontrolling interest, all related to Otay Mesa VIE, were $19 million in 2011 compared to losses of $16 million in 2010. The change was primarily due to $34 million of losses on interest rate instruments in 2010.
 
Losses attributable to noncontrolling interest were $16 million in 2010 compared to earnings of $24 million in 2009. The change was primarily due to:
 
§  
$34 million in losses on interest rate instruments in 2010 compared to $27 million in gains in 2009; and
 
§  
$14 million in interest expense in 2010; offset by
 
§  
$34 million increase in operating income in 2010.
 
 
Earnings
 
We summarize variations in overall earnings in “Overall Results of Operations of Sempra Energy and Factors Affecting the Results” above. We discuss variations in earnings by business unit above in “Business Unit Results.”
 
 
TRANSACTIONS WITH AFFILIATES
 
We provide information about our related party transactions in Note 1 of the Notes to Consolidated Financial Statements.
 
 
BOOK VALUE PER SHARE
 
Sempra Energy’s book value per share on the last day of each year was
 
§  
$41.00 in 2011
 
§  
$37.54 in 2010
 
§  
$36.54 in 2009
 
The increases in 2011 and 2010 were primarily the result of comprehensive income exceeding dividends. The increase in 2010 was offset to a large extent by the reduction in common stock shares from a 2010 share repurchase program at an amount per share greater than book value. We discuss the share repurchase program in Note 13 of the Notes to Consolidated Financial Statements.
 

 

CAPITAL RESOURCES AND LIQUIDITY
 

 
OVERVIEW
 
We expect our cash flows from operations to fund a substantial portion of our capital expenditures and dividends.  In addition, we may meet our cash requirements through the issuance of short-term and long-term debt and the expected distributions from RBS Sempra Commodities related to proceeds from the transactions to sell certain businesses within the joint venture, as we discuss below.
 
Significant events in 2011 affecting capital resources, liquidity and cash flows were
 
§  
long-term debt issuances at Sempra Energy ($800 million) and SDG&E ($600 million)
 
§  
 $623 million in distributions received from RBS Sempra Commodities related to the sale of joint venture businesses and assets
 
§  
Sempra Pipelines & Storage’s acquisition of additional interests in South American utilities for $611 million, net of cash acquired
 
§  
$2.8 billion in expenditures for property, plant and equipment, including $789 million for SDG&E’s Sunrise Powerlink project
 
§  
$482 million of Sempra Energy debt retirements
 
§  
a cash payment of $130 million in January 2011 related to a 2010 settlement to resolve certain energy crisis litigation
 
We discuss these events in more detail later in this section.
 
Our committed lines of credit provide liquidity and support commercial paper.  As we discuss in Note 5 of the Notes to Consolidated Financial Statements, Sempra Energy, Sempra Global and the Sempra Utilities each have four-year revolving credit facilities, expiring in 2014. At Sempra Energy and Sempra Global, the agreements are syndicated broadly among 23 different lenders and at the Sempra Utilities, among 22 different lenders.  No single lender has greater than a 7-percent share in any agreement.
 
The table below shows the amount of available funds at year-end 2011:
 
AVAILABLE FUNDS AT DECEMBER 31, 2011
(Dollars in millions)
 
 
Sempra Energy
 
 
 
 
Consolidated
SDG&E
SoCalGas
Unrestricted cash and cash equivalents
$
 252 
$
 29 
$
 36 
Available unused credit(1)
 
 2,734 
 
 363 
 
 563 
(1)
Borrowings on the shared line of credit at SDG&E and SoCalGas, discussed in Note 5, are limited to $600 million for each utility and $800 million in total. SDG&E’s available funds reflect variable-rate demand notes of $237 million supported by the line. SoCalGas’ availability reflects the impact of SDG&E’s use of the combined credit available on the line.
 
Sempra Energy Consolidated
 
We believe that these available funds and cash flows from operations, distributions from equity method investments and security issuances, combined with current cash balances, will be adequate to:
 
§  
finance capital expenditures
 
§  
meet liquidity requirements
 
§  
fund shareholder dividends
 
§  
fund new business acquisitions or start-ups
 
§  
repay maturing long-term debt
 
In March 2011, Sempra Energy publicly offered and sold $500 million of 2-percent notes and $300 million of floating rate notes, both maturing in 2014. In August 2011, SDG&E publicly offered and sold $350 million of 3-percent first mortgage bonds maturing in 2021. In November 2011, SDG&E publicly offered and sold $250 million of 3.95-percent first mortgage bonds maturing in 2041. SDG&E and SoCalGas issued long-term debt in 2010 in the aggregate principal amounts of $750 million and $300 million, respectively. Changing economic conditions could affect the availability and cost of both short-term and long-term financing. If cash flows from operations were to be significantly reduced or we were unable to borrow under acceptable terms, we would reduce or postpone discretionary capital expenditures and investments in new businesses. If these measures were necessary, they would primarily impact certain of our Sempra Global businesses before we would reduce funds necessary for the ongoing needs of the Sempra Utilities, and secondarily our South American utilities. We continuously monitor our ability to finance the needs of our operating, investing and financing activities in a manner consistent with our intention to maintain strong, investment-grade credit ratings and capital structure.
 
In three separate transactions during 2010 and one in early 2011, we and RBS sold substantially all of the businesses and assets of our joint-venture partnership that comprised our commodities-marketing businesses. Distributions from the partnership in 2011 were $623 million. As we conclude the transactions to divest the businesses, we expect to recover our remaining $126 million investment in the partnership in 2012. Minor amounts may be retained beyond 2012 by the partnership to help offset unanticipated future general and administrative costs necessary to complete the dissolution of the partnership. We are providing transitional back-up guarantees, a few of which may continue for a prolonged period of time. Either RBS or JP Morgan Chase & Co., one of the buyers’ parties in the sales transactions, has fully indemnified us for any claims or losses in connection with the related transactions.
 
We provide additional information about RBS Sempra Commodities and the sales transactions and guarantees in Notes 3, 4, 5 and 15 of the Notes to Consolidated Financial Statements.
 
In April 2011, Sempra Pipelines & Storage acquired AEI’s interests in Chilquinta Energía, Luz del Sur, and related entities for $611 million in cash (net of cash acquired). This transaction was funded with excess funds from foreign operations, proceeds from divestitures and short-term debt.
 
We provide additional information about Chilquinta Energía and Luz del Sur in Note 3 of the Notes to Consolidated Financial Statements.
 
At December 31, 2010, our cash and cash equivalents held in foreign jurisdictions that are unavailable to fund domestic operations unless repatriated were approximately $150 million. At December 31, 2011, these cash balances are negative when netted against loans from Sempra Energy to fund the acquisitions in South America in April 2011. We intend for funds associated with accumulated foreign earnings through December 31, 2011 to remain indefinitely in our foreign subsidiaries to fund their operations. We are currently considering a plan to repatriate future earnings from certain foreign operations beginning in 2013.
 
We have significant investments in several trusts to provide for future payments of pensions and other postretirement benefits, and nuclear decommissioning. Changes in asset values, which are dependent on the activity in the equity and fixed income markets, have not affected the trust funds’ abilities to make required payments, but may impact funding requirements for pension and other postretirement benefit plans. At the Sempra Utilities, funding requirements are generally recoverable in rates.
 
On February 24, 2012, our board of directors approved an increase to our quarterly common stock dividend to $0.60 per share ($2.40 annually), an increase of $0.12 per share ($0.48 annually) from $0.48 per share ($1.92 annually) authorized in February 2011. Declarations of dividends on our common stock are made at the discretion of the board. While we view dividends as an integral component of shareholder return, the amount of future dividends will depend upon earnings, cash flows, financial and legal requirements, and other relevant factors at that time.
 
On February 18, 2011, our board of directors approved an increase to our quarterly common stock dividend to $0.48 per share ($1.92 annually), an increase of $0.09 per share ($0.36 annually) from $0.39 per share ($1.56 annually) authorized in February 2009. We provide further information regarding dividends and dividend restrictions in “Dividends” and “Common Stock Data” below. We discuss restricted net assets in Note 1 of the Notes to Consolidated Financial Statements.
 
We discuss our principal credit agreements further in Note 5 of the Notes to Consolidated Financial Statements.
 
 
Short-Term Borrowings
 
Our short-term debt is used to finance capital expenditures, meet liquidity requirements, fund shareholder dividends and fund new business acquisitions or start-ups. Our corporate short-term unsecured promissory notes, or commercial paper, were our primary source of short-term debt funding in 2011.
 
The following table shows selected statistics for our commercial paper borrowings for 2011:
 
COMMERCIAL PAPER STATISTICS
 
 
(Dollars in millions)
 
 
 
Commercial Paper
Sempra Energy Consolidated
 
 
 
Amount outstanding at December 31, 2011(1)
$
 821 
 
Weighted average interest rate at December 31, 2011
 
0.74%
 
 
 
 
 
Maximum month-end amount outstanding during 2011(2)
$
 1,016 
 
 
 
 
 
Monthly weighted average amount outstanding during 2011
$
 699 
 
Monthly weighted average interest rate during 2011
 
0.58%
(1)
Includes $400 million classified as long-term, as we discuss in Note 5 of the Notes to Consolidated Financial Statements.
(2)
The largest amount outstanding at the end of the last day of any month during 2011.
 
Significant cash flows impacting short-term debt levels at Sempra Energy Consolidated during 2011 include a payment in January related to a settlement to resolve certain energy crisis litigation ($130 million); issuance of long-term debt at Sempra Energy in March ($800 million); acquisitions made by Sempra Pipelines & Storage in April ($611 million); distributions from RBS Sempra Commodities in April ($329 million), August ($98 million) and December ($196 million); redemption of subsidiary preferred stock in June ($80 million); and capital investments made by Sempra Generation in renewable projects in December ($234 million).
 
 
Sempra Utilities
 
SoCalGas expects that cash flows from operations and debt issuances will continue to be adequate to meet its capital expenditure requirements. In March 2011, Sempra Energy made a $200 million capital contribution to SDG&E, and SDG&E expects its cash flows from operations and debt issuances will be adequate to meet its future capital expenditure requirements.
 
SoCalGas declared and paid a $50 million common dividend in 2011 and a $100 million common dividend in 2010. As a result of an increase in SoCalGas’ capital investment programs over the next few years, management expects SoCalGas’ dividends on common stock to be reduced or temporarily suspended over the next few years to maintain SoCalGas’ authorized capital structure during the periods of high capital investments.
 
SDG&E’s most recent common dividend to Sempra Energy was declared and paid in the first quarter of 2009 in the amount of $150 million. As a result of SDG&E’s large capital investment program over the past few years and the level of capital investment planned for 2012, SDG&E does not expect to pay common dividends to Sempra Energy in 2012. However, due to the scheduled completion of construction of the Sunrise Powerlink transmission power line in 2012, SDG&E expects to resume the declaration and payment of dividends on its common stock in 2013.
 
 
Sempra Generation
 
We expect Sempra Generation to require funds for the development of electric generation facilities, primarily renewable energy projects. Projects at Sempra Generation may be financed through a combination of operating cash flow, project financing, low-cost financing from the U.S. Department of Energy, U.S. Treasury Department cash grants, funds from the parent, partnering in joint ventures and proceeds received from the sale of El Dorado (now named Desert Star Energy Center) natural gas power plant to SDG&E on October 1, 2011. Cash flows from operations at Sempra Generation are expected to decrease substantially since its contract with the DWR expired in September 2011, due to less favorable pricing on any replacement contracts obtained, and the sale of El Dorado.  Also, Sempra Generation may not be able to replace all of the lost revenue due to decreased market demand. Sales to the DWR comprised six percent of Sempra Energy’s revenues in 2011. However, Sempra Generation is also undertaking and investing in several projects for the construction of renewable generation facilities, with planned in-service dates ranging from 2012 to 2016.
 
Some of Sempra Generation’s long-term power sale contracts contain collateral requirements which require Sempra Generation and/or the counterparty to post cash, guarantees or letters of credit to the other party for exposure in excess of established thresholds. Sempra Generation may be required to provide collateral when market price movements adversely affect the counterparty’s cost of replacement energy supplies if Sempra Generation fails to deliver the contracted amounts. Sempra Generation had no outstanding collateral requirements under such contracts at December 31, 2011 or 2010.
 
 
Sempra Pipelines & Storage
 
We expect Sempra Pipelines & Storage to require funding from the parent or from external sources to fund projects and investments, including development and expansion of its natural gas storage projects. We expect projects at Chilquinta Energía and Luz del Sur to be funded by external borrowings and funds internally generated by Chilquinta Energía and Luz del Sur.
 
We provide additional information about Sempra Pipelines & Storage’s investments in Chilquinta Energía and Luz del Sur in Note 3 of the Notes to Consolidated Financial Statements.
 
 
Sempra LNG
 
Sempra LNG required funding from 2007 through 2009 for its development and construction of the Energía Costa Azul and Cameron LNG terminals.  As both of these facilities are now in service, Sempra LNG is expected to provide operating cash flow for further development within Sempra Global.
 
 
CASH FLOWS FROM OPERATING ACTIVITIES
 

CASH PROVIDED BY OPERATING ACTIVITIES
(Dollars in millions)
 
2011 
2011 Change
2010 
2010 Change
2009 
Sempra Energy Consolidated
$
 1,867 
$
 (287)
 (13)
%
$
 2,154 
$
 279 
 15 
%
$
 1,875 
SDG&E
 
 882 
 
 153 
 21 
 
 
 729 
 
 88 
 14 
 
 
 641 
SoCalGas
 
 554 
 
 (182)
 (25)
 
 
 736 
 
 296 
 67 
 
 
 440 


Sempra Energy Consolidated
 
Cash provided by operating activities at Sempra Energy decreased in 2011 due to:
 
§  
$402 million in settlement payments for the 2007 wildfires in 2011 (using $381 million of restricted cash), compared to $43 million net settlement payments for the 2007 wildfires in 2010;
 
§  
$130 million settlement payment related to energy crisis litigation in 2011, which was an increase to other current liabilities when accrued in 2010;
 
§  
$145 million lower distributions from RBS Sempra Commodities in 2011; and
 
§  
a $32 million increase in accounts receivable in 2011 compared to an $89 million decrease in accounts receivable in 2010; offset by
 
§  
$268 million decrease in income taxes receivable in 2011 compared to a $30 million increase in income taxes receivable in 2010;
 
§  
$161 million higher net income, adjusted for noncash items included in earnings, in 2011 compared to 2010; and
 
§  
$300 million of funds received in 2011 from a wildfire litigation settlement compared to $144 million of funds received in 2010, which is offset by an increase in restricted cash in cash flows from investing activities.
 
Cash provided by operating activities at Sempra Energy increased in 2010 due to:
 
§  
$170 million higher net income, adjusted for noncash items included in earnings, in 2010 compared to 2009;
 
§  
an increase in accounts payable in 2010 compared to a decrease in 2009 due to higher natural gas prices in 2010;
 
§  
an accounts receivable decrease in 2010 compared to an increase in 2009; and
 
§  
$144 million of restricted funds received from Cox Communications from a wildfire litigation settlement that we describe in Note 15 of the Notes to Consolidated Financial Statements, which is offset by an increase in restricted cash in cash flows from investing activities; offset by
 
§  
a decrease in overcollected regulatory balancing accounts in 2010 compared to an increase in 2009, which we discuss for SDG&E and SoCalGas below;
 
§  
an increase in inventory in 2010 compared to a decrease in 2009, primarily at Sempra Pipelines & Storage as a result of natural gas optimization activities; and
 
§  
$209 million lower distributions of joint venture earnings received from RBS Sempra Commodities in 2010.
 
Changes in Other Current Assets and Other Current Liabilities in 2010 at both Sempra Energy and SDG&E include $273 million in payments received from our liability insurance and $316 million of settlements paid, related to the SDG&E 2007 wildfire litigation, respectively. We used $34 million of the restricted cash from the litigation settlement for such payments.
 
 
SDG&E
 
Cash provided by operating activities at SDG&E increased in 2011 due to:
 
§  
$305 million higher net income, adjusted for noncash items included in earnings, in 2011 compared to 2010;
 
§  
a higher increase in accounts payable in 2011 compared to 2010; and
 
§  
$300 million of funds received in 2011 from a wildfire litigation settlement compared to $144 million of funds received in 2010; which is offset by an increase in restricted cash in cash flows from investing activities; offset by
 
§  
$111 million increase in income taxes receivable in 2011 compared to a $12 million decrease in income taxes receivable in 2010; and
 
§  
$402 million in settlement payments for the 2007 wildfires in 2011 (using $381 million of restricted cash), compared to $43 million net settlement payments for the 2007 wildfires in 2010.
 
Cash provided by operating activities at SDG&E increased in 2010 due to:
 
§  
$68 million higher net income, adjusted for noncash items included in earnings, in 2010;
 
§  
lower income tax payments in 2010; and
 
§  
$144 million of restricted funds received from a wildfire litigation settlement, which is offset by an increase in restricted cash in cash flows from investing activities; offset by
 
§  
$43 million net settlement payments in 2010 (using $34 million of restricted cash) compared to $10 million net receipts from our liability insurance carriers in 2009 related to the 2007 wildfire litigation (as we discuss above under “Sempra Energy Consolidated”); and
 
§  
a decrease in overcollected regulatory balancing accounts in 2010 compared to an increase in 2009. Over- and undercollected regulatory balancing accounts reflect the difference between customer billings and recorded or CPUC-authorized costs. These differences are required to be balanced over time.
 
 
SoCalGas
 
Cash provided by operating activities at SoCalGas decreased in 2011 due to:
 
§  
an increase in accounts receivable in 2011 compared to a decrease in 2010;
 
§  
an decrease in accounts payable in 2011 compared to an increase in 2010 primarily due to lower natural gas prices in 2011; and
 
§  
a higher increase in inventory in 2011 compared to 2010; offset by
 
§  
$40 million higher net income, adjusted for noncash items included in earnings, in 2011 compared to 2010.
 
Cash provided by operating activities at SoCalGas increased in 2010 due to:
 
§  
$58 million higher net income, adjusted for noncash items included in earnings, in 2010 compared to 2009;
 
§  
an increase in accounts payable in 2010 compared to a decrease in 2009 primarily due to higher natural gas prices in 2010;
 
§  
a decrease in accounts receivable in 2010 compared to an increase in 2009 due to lower other accounts receivable in 2010 related to natural gas storage transactions; and
 
§  
decreases in other liabilities of $137 million in 2009, including a $55 million prepayment of remaining installments due under a litigation settlement in 2009; offset by
 
§  
a decrease in inventory of $74 million in 2009 due to higher withdrawals from inventory in the fourth quarter of 2009 to supply core customers; and
 
§  
a decrease in overcollected regulatory balancing accounts in 2010 compared to an increase in 2009.
 
The table below shows the contributions to pension and other postretirement benefit plans for each of the past three years.
 

CONTRIBUTIONS TO PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS 2009-2011
(Dollars in millions)
 
Pension Benefits
 
Other Postretirement Benefits
 
2011 
2010 
2009 
 
2011 
2010 
2009 
Sempra Energy Consolidated
$
 212 
$
 159 
$
 185 
 
$
 72 
$
 52 
$
 45 
SDG&E
 
 69 
 
 61 
 
 58 
 
 
 15 
 
 15 
 
 16 
SoCalGas
 
 95 
 
 71 
 
 76 
 
 
 55 
 
 35 
 
 28 
 
CASH FLOWS FROM INVESTING ACTIVITIES
 

CASH USED IN INVESTING ACTIVITIES
(Dollars in millions)
 
2011 
2011 Change
2010 
2010 Change
2009 
Sempra Energy Consolidated
$
 (3,070)
$
 1,787 
 139 
%
$
 (1,283)
$
 (1,389)
 (52)
%
$
 (2,672)
SDG&E
 
 (1,764)
 
 450 
 34 
 
 
 (1,314)
 
 389 
 42 
 
 
 (925)
SoCalGas
 
 (634)
 
 68 
 12 
 
 
 (566)
 
 70 
 14 
 
 
 (496)


Sempra Energy Consolidated
 
Cash used in investing activities at Sempra Energy increased in 2011 due to:
 
§  
a $782 million increase in capital expenditures;
 
§  
$611 million in cash used to fund Sempra Pipelines & Storage’s purchase of South American entities;
 
§  
$279 million lower distributions received from RBS Sempra Commodities related to the sale of joint venture businesses and assets, as we discuss in Note 4 of the Notes to Consolidated Financial Statements;
 
§  
a $300 million increase in SDG&E’s restricted cash due to funds received from a wildfire litigation settlement compared to $144 million of funds received in 2010;
 
§  
$180 million of distributions from Fowler Ridge 2 Wind Farm at Sempra Generation in 2010; and
 
§  
$175 million of proceeds received from Sempra Generation’s 2010 sale of its investment in Elk Hills; offset by
 
§  
 $381 million in payments for claims related to wildfire litigation using restricted funds received from a wildfire litigation settlement; and
 
§  
Sempra Pipelines & Storage’s $292 million acquisition (net of cash acquired) resulting in the purchase of Mexican pipeline and natural gas infrastructure assets in 2010.
 
Cash used in investing activities at Sempra Energy decreased in 2010 due to:
 
§  
$849 million of distributions received from RBS Sempra Commodities LLP in 2010 related to the sale of joint venture businesses and assets, as we discuss in Note 4 of the Notes to Consolidated Financial Statements;
 
§  
$560 million lower contributions to Rockies Express, as the $65 million contribution in the first quarter of 2010 was the last required for the construction phase of the project;
 
§  
$235 million for Sempra Generation’s 2009 investment in Fowler Ridge 2; and
 
§  
$175 million of proceeds received from Sempra Generation’s 2010 sale of its investment in Elk Hills; offset by
 
§  
$144 million increase in restricted cash from funds received from a wildfire litigation settlement; and
 
§  
Sempra Pipelines & Storage’s acquisition of Mexican pipeline and natural gas infrastructure assets.
 
 
SDG&E
 
Cash used in investing activities increased at SDG&E in 2011 primarily due to:
 
§  
a $621 million increase in capital expenditures; and
 
§  
a $300 million increase in restricted cash due to funds received from a wildfire litigation settlement compared to $144 million of funds received in 2010; offset by
 
§  
 $381 million in payments for claims related to wildfire litigation using restricted funds received from a wildfire litigation settlement.
 
Cash used in investing activities increased at SDG&E in 2010 primarily due to:
 
§  
a $255 million net increase in capital expenditures (a $369 million increase at SDG&E, offset by a decrease of $114 million at Otay Mesa VIE);
 
§  
$144 million increase in restricted cash due to funds received from a wildfire litigation settlement; and
 
§  
net proceeds of $24 million related to industrial development bonds in 2009; offset by
 
§  
$34 million in payments of claims related to wildfire litigation using restricted funds received from a wildfire litigation settlement.
 
 
SoCalGas
 
Cash used in investing activities increased at SoCalGas in 2011 primarily due to:
 
§  
a $180 million increase in capital expenditures; offset by
 
§  
a $49 million decrease in advances to Sempra Energy in 2011 compared a $63 million increase in advances to Sempra Energy in 2010.
 
Cash used in investing activities at SoCalGas increased in 2010, primarily due to a $63 million increase in advances to Sempra Energy in 2010.
 
 
CAPITAL EXPENDITURES AND INVESTMENTS
 
The table below shows our expenditures for property, plant and equipment, and for investments. We provide capital expenditure information by segment in Note 16 of the Notes to Consolidated Financial Statements.
 
SEMPRA ENERGY CONSOLIDATED
CAPITAL EXPENDITURES AND INVESTMENTS/ACQUISITIONS
(Dollars in millions)
 
Property, plant and equipment
 
Investments and acquisition of businesses
2011 
$
 2,844 
 
$
 941 
2010 
 
 2,062 
 
 
 611 
2009 
 
 1,912 
 
 
 939 
2008 
 
 2,061 
 
 
 2,675 
2007 
 
 2,011 
 
 
 121 
 
Sempra Energy Consolidated Capital Expenditures
 
We discuss capital expenditures at the Sempra Utilities below.
 
At Sempra Global, the primary capital expenditures over the last three years were as follows:
 
Sempra Generation
 
In 2011, capital expenditures include $181 million for the construction of the Mesquite Solar facility. In 2010, capital expenditures include $123 million for construction of the Copper Mountain Solar facility. Total capital expenditures in 2009 were $38 million.
 
Sempra Pipelines & Storage
 
In 2011, Sempra Pipelines & Storage had capital expenditures from the South American entities of $110 million related to distribution infrastructure and generation projects, including a hydroelectric power plant in Peru. Also in 2011, Sempra Pipelines & Storage had capital expenditures related to the development of approximately 20 Bcf of additional capacity at Bay Gas and Mississippi Hub. In 2010, Sempra Pipelines & Storage increased its operational working natural gas storage capacity by approximately 12 Bcf at Bay Gas and Mississippi Hub. In 2009, Sempra Pipelines & Storage completed its Cameron Interstate Pipeline project in Louisiana connecting the Cameron LNG terminal with several interstate pipelines. Related amounts included in total capital expenditures were
 
Natural gas storage:
 
Pipelines:
§ $122 million in 2011
 
§ None in 2011
 
§ $170 million in 2010
 
§ None in 2010
 
§ $127 million in 2009
 
§ $10 million in 2009
 
 
Sempra LNG
 
Sempra LNG’s Energía Costa Azul and Cameron terminals began commercial operations in May 2008 and July 2009, respectively. The nitrogen-injection facility at Energía Costa Azul was placed in service in December 2009. Expenditures for these facilities were $11 million in 2011, $17 million in 2010 and $207 million in 2009.
 
 
Sempra Energy Consolidated Investments and Acquisitions
 
In 2011, investments consisted primarily of:
 
§  
$611 million in cash used to fund Sempra Pipelines & Storage’s purchase of South American entities
 
§  
$146 million for the initial investment in Flat Ridge 2 Wind Farm
 
§  
$88 million for the initial investment in Mehoopany Wind Farm
 
§  
the purchase of $84 million in industrial development bonds
 

In 2010, investments consisted primarily of:
 
§  
acquisition of Mexican pipelines and infrastructure assets for approximately $300 million
 
§  
$209 million for the initial investment in Cedar Creek 2 Wind Farm
 
§  
$65 million invested in Rockies Express
 
In 2009, investments consisted primarily of:
 
§  
$625 million for Rockies Express and $235 million for Fowler Ridge 2 Wind Farm
 
§  
the purchase of $75 million in industrial development bonds
 
 
Sempra Energy Consolidated Distributions From Other Investments
 
Sempra Energy’s Distributions From Other Investments consist primarily of distributions representing return of investment from equity method and other investments at Sempra Generation and Sempra Pipelines & Storage as follows:
 

(Dollars in millions)
2011 
2010 
2009 
Sempra Generation
 
 
 
 
 
 
 
Fowler Ridge 2
$
 2 
$
 180 
$
 ― 
 
Cedar Creek 2
 
 5 
 
 96 
 
 ― 
 
Elk Hills
 
 ― 
 
 9 
 
 ― 
 
 
 
 
 
 
 
 
Sempra Pipelines & Storage
 
 
 
 
 
 
 
Rockies Express
 
 57 
 
 55 
 
 23 
 
South America
 
 ― 
 
 31 
 
 ― 
Total
$
 64 
$
 371 
$
 23 
 
The 2010 distributions from Fowler Ridge 2 and Cedar Creek 2 were made by the joint ventures upon entering into loans to finance the projects. Distributions of earnings from these investments are included in cash flows from operations.
 
 
Purchase of Bonds Issued by Unconsolidated Affiliate
 
In November 2009, Sempra Pipelines & Storage purchased $50 million of 2.75-percent bonds issued by Chilquinta Energía S.A., a then unconsolidated affiliate, that are adjusted for Chilean inflation. The bonds mature on October 30, 2014. We discuss these bonds in Note 5 of the Notes to Consolidated Financial Statements.
 
 
Sempra Utilities Capital Expenditures and Investments
 
The Sempra Utilities’ capital expenditures for property, plant and equipment were
 

(Dollars in millions)
2011 
2010 
2009 
SDG&E
$
 1,831 
$
 1,210 
$
 955 
SoCalGas
 
 683 
 
 503 
 
 480 

Capital expenditures at the Sempra Utilities in 2011 consisted primarily of:
 
SDG&E
 
§  
$593 million of improvements to natural gas and electric distribution systems
 
§  
$789 million for the Sunrise Powerlink transmission line
 
§  
$173 million of improvements to electric transmission systems
 
§  
$276 million for electric generation plants and equipment
 
SoCalGas
 
§  
$683 million of improvements to natural gas infrastructure
 

Through December 31, 2011, SDG&E has recorded $1.48 billion to property, plant and equipment related to the Sunrise Powerlink project, including $130 million of AFUDC related to debt and equity.
 
SDG&E also purchased $152 million of industrial development bonds in 2009. We discuss these bonds in Note 5 of the Notes to Consolidated Financial Statements.
 
 
FUTURE CONSTRUCTION EXPENDITURES AND INVESTMENTS
 
The amounts and timing of capital expenditures are generally subject to approvals by the CPUC, the FERC and other regulatory bodies. However, in 2012, we expect to make capital expenditures and investments of approximately $3.1 billion. These expenditures include
 
§  
$2.1 billion at the Sempra Utilities for capital projects and plant improvements ($1.4 billion at SDG&E and $710 million at SoCalGas)
 
§  
$1.0 billion at our other subsidiaries for development of natural gas storage facilities and pipelines, capital projects in South America and renewable generation projects
 
In 2012, the Sempra Utilities expect their capital expenditures and investments to include
 
§  
$630 million for improvements to SDG&E’s natural gas and electric distribution systems
 
§  
$170 million at SDG&E for the Sunrise Powerlink transmission line
 
§  
$200 million for improvements to SDG&E’s electric transmission systems
 
§  
$90 million for SDG&E’s electric generation plants and equipment
 
§  
$285 million for SDG&E’s renewable projects
 
§  
$710 million at SoCalGas for improvements to distribution and transmission systems and storage facilities, and for advanced metering infrastructure
 
The Sempra Utilities expect to finance these expenditures and investments with cash flows from operations, cash on hand and debt issuances.
 
Over the next five years and subject to the factors described below which could cause these estimates to vary substantially, the Sempra Utilities expect to make capital expenditures and investments of:
 
§  
$5.8 billion at SDG&E
 
§  
$5.0 billion at SoCalGas
 
In 2012, the expected capital expenditures and investments of $1.0 billion at our other subsidiaries, net of anticipated project financing and joint venture structures, include
 
 
Sempra Pipelines & Storage
 
§  
approximately $100 million to $200 million for capital projects in South America, including approximately $70 million for the Santa Teresa hydroelectric power at Luz del Sur
 
§  
approximately $50 million to $100 million for development of natural gas storage projects at Bay Gas and Mississippi Hub
 
 
Sempra Generation
 
§  
approximately $400 million for investment in the first phase (150 MW) of Mesquite Solar, a solar project at our Mesquite Power plant near Arlington, Arizona
 
§  
approximately $100 million for investment in the second phase (approximately 150 MW) of Copper Mountain Solar, a solar project located near Boulder City, Nevada
 
§  
approximately $200 million for investment in other renewable projects
 
Over the next five years and subject to the factors described below which could cause these estimates to vary substantially, Sempra Energy expects to make aggregate capital expenditures at its other subsidiaries of approximately $2.8 billion. This amount is net of $1.3 billion in anticipated project financing, and anticipated joint venture structures.
 
Capital expenditure amounts include capitalized interest. At the Sempra Utilities, the amounts also include the portion of AFUDC related to debt, but exclude the portion of AFUDC related to equity.  We provide further details about AFUDC in Note 1 of the Notes to Consolidated Financial Statements.
 
Periodically, we review our construction, investment and financing programs and revise them in response to changes in regulation, economic conditions, competition, customer growth, inflation, customer rates, the cost and availability of capital, and environmental requirements. We discuss these considerations in more detail in Notes 14 and 15 of the Notes to Consolidated Financial Statements.
 
Our level of capital expenditures and investments in the next few years may vary substantially and will depend on the cost and availability of financing, regulatory approvals, changes in U.S. federal tax law and business opportunities providing desirable rates of return.  We intend to finance our capital expenditures in a manner that will maintain our strong investment-grade credit ratings and capital structure.
 
 
CASH FLOWS FROM FINANCING ACTIVITIES
 

CASH FLOWS FROM FINANCING ACTIVITIES
(Dollars in millions)
 
2011 
2011 Change
2010 
2010 Change
2009 
Sempra Energy Consolidated
$
 534 
$
 603 
 
 
$
 (69)
$
 (645)
 
 
$
 576 
SDG&E
 
 784 
 
 85 
 
 
 
 699 
 
 421 
 
 
 
 278 
SoCalGas
 
 (301)
 
 (499)
 
 
 
 198 
 
 299 
 
 
 
 (101)
 
Sempra Energy Consolidated
 
Cash from financing activities in 2011 increased due to:
 
§  
$973 million higher issuances of long-term debt;
 
§  
$500 million common stock repurchase program in 2010; and
 
§  
$423 million lower long-term debt payments; offset by
 
§  
$498 million decrease in short-term debt in 2011 compared to a $568 million increase in 2010;
 
§  
$80 million for the redemption of subsidiary preferred stock;
 
§  
$76 million increase in common dividends paid; and
 
§  
$43 million related to Sempra Pipelines & Storage’s September 2011 tender offer discussed in Note 3 of the Notes to Consolidated Financial Statements.
 
At Sempra Energy, financing activities used cash in 2010 compared to providing cash in 2009, primarily due to:
 
§  
$500 million common stock repurchase program in 2010;
 
§  
$1 billion lower issuances of debt; and
 
§  
$470 million higher debt payments; offset by
 
§  
$94 million for the purchase of the remaining 40-percent ownership interest in Mississippi Hub in 2009 (as we discuss in Note 3 of the Notes to Consolidated Financial Statements); and
 
§  
$568 million increase in short-term debt in 2010 compared to a $659 million decrease in 2009.
 
 
SDG&E
 
Cash provided by financing activities in 2011 increased due to:
 
§  
a $200 million capital contribution from Sempra Energy in 2011; offset by
 
§  
$146 million lower issuances of long-term debt.
 
Cash provided by financing activities in 2010 increased primarily due to:
 
§  
$305 million higher issuances of long-term debt; and
 
§  
$150 million common dividends paid to Sempra Energy in 2009.
 
 
SoCalGas
 
At SoCalGas, financing activities used cash in 2011 compared to providing cash in 2010, primarily due to:
 
§  
a $250 million long-term debt payment in 2011; and
 
§  
$300 million issuance of long-term in 2010; offset by
 
§  
$50 million lower common dividends paid.
 

Cash provided by financing activities at SoCalGas in 2010 increased primarily due to:
 
§  
$300 million issuance of long-term debt in 2010; and
 
§  
$100 million long-term debt payment in 2009; offset by
 
§  
$100 million in common dividends paid in 2010.
 
 
LONG-TERM DEBT
 
Long-term debt balances (including the current portion of long-term debt) at December 31 were
 

(Dollars in millions)
2011 
2010 
2009 
Sempra Energy Consolidated
$
 10,414 
$
 9,329 
$
 8,033 
SDG&E
 
 4,077 
 
 3,498 
 
 2,668 
SoCalGas
 
 1,321 
 
 1,582 
 
 1,294 

At December 31, 2011, the following information applies to long-term debt, excluding commercial paper classified as long-term:
 
 
Sempra Energy
 
 
 
 
(Dollars in millions)
Consolidated
SDG&E
SoCalGas
Weighted average life to maturity, in years
 13.2 
 
 18.3 
 
 13.0 
 
Weighted average interest rate
 5.23 
%
 4.80 
%
 5.32 
%
 
Issuances of Long-Term Debt
 
Major issuances of long-term debt over the last three years included the following:
 

(Dollars in millions)
 
Amount
 
Rate
 
Maturing
 
 
 
 
 
 
 
 
Sempra Energy
 
 
 
 
 
 
 
Variable rate notes (1.22% at December 31, 2011),
 
 
 
 
 
 
 
    March 2011
$
 300 
 
 1.22 
%
2014 
 
Notes, March 2011
 
 500 
 
 2.00 
 
2014 
 
Notes, October 2009
 
 750 
 
 6.00 
 
2039 
 
Notes, May 2009
 
 750 
 
 6.50 
 
2016 
 
 
 
 
 
 
 
 
SDG&E
 
 
 
 
 
 
 
First mortgage bonds, November 2011
 
 250 
 
 3.95 
 
2041 
 
First mortgage bonds, August 2011
 
 350 
 
 3.00 
 
2021 
 
First mortgage bonds, August 2010
 
 500 
 
 4.50 
 
2040 
 
First mortgage bonds, May 2010
 
 250 
 
 5.35 
 
2040 
 
First mortgage bonds, May 2009
 
 300 
 
 6.00 
 
2039 
 
 
 
 
 
 
 
 
SoCalGas
 
 
 
 
 
 
 
First mortgage bonds, November 2010
 
 300 
 
 5.125 
 
2040 

Sempra Energy used the proceeds from its issuances of long-term debt primarily for general corporate purposes, including the repayment of commercial paper and to repay maturing long-term notes.
 
The Sempra Utilities used the proceeds from their issuances of long-term debt:
 
§  
for general working capital purposes;
 
§  
to support their electric (at SDG&E) and natural gas (SDG&E and SoCalGas) capital expenditure programs;
 
§  
to replenish amounts expended and fund future expenditures for the expansion and improvement of their utility plants; and
 
§  
to repay commercial paper at SDG&E.
 
 
Payments on Long-Term Debt
 
Payments on long-term debt in 2011 included
 
§  
$100 million of SoCalGas 4.375-percent first mortgage bonds at maturity in January 2011
 
§  
$150 million of SoCalGas variable rate first mortgage bonds at maturity in January 2011
 
Payments on long-term debt in 2010 included
 
§  
$500 million of Sempra Energy notes payable at maturity in March 2010
 
§  
retirement of $128 million of industrial development bonds related to Sempra Pipelines & Storage’s Liberty project
 
Payments on long-term debt in 2009 included
 
§  
$300 million of Sempra Energy 4.75-percent notes payable at maturity in May 2009
 
§  
$100 million of SoCalGas variable rate first mortgage bonds at maturity in December 2009
 
In Note 5 of the Notes to Consolidated Financial Statements, we provide information about our lines of credit and additional information about debt activity.
 
 
Payments on Notes Payable to Unconsolidated Affiliate
 
Sempra Pipelines & Storage prepaid $100 million of notes payable due to Chilquinta Energía Finance Co. LLC in November 2009.
 
 
CAPITAL STOCK TRANSACTIONS
 
 
Sempra Energy
 
Cash provided by employee stock option exercises and newly issued shares for our dividend reinvestment and 401(k) saving plans was
 
§  
$28 million in 2011
 
§  
$40 million in 2010
 
§  
$73 million in 2009
 
In 2010, we entered into a Collared Accelerated Share Acquisition Program under which we prepaid $500 million to repurchase shares of our common stock in a share forward transaction. We received 8.1 million shares under the program during 2010 and an additional 1.5 million shares when the program was completed in March 2011. We discuss the repurchase program in Note 13 of the Notes to Consolidated Financial Statements.
 
 
DIVIDENDS
 
 
Sempra Energy
 
Sempra Energy paid cash dividends on common stock of:
 
§  
$440 million in 2011
 
§  
$364 million in 2010
 
§  
$341 million in 2009
 
The increase in 2011 was due to increases in the per-share quarterly dividend from $0.39 in 2010 to $0.48 in 2011. The increase in 2010 is due to suspension of dividend reinvestment programs in July 2010.
 
On December 6, 2011, Sempra Energy declared a quarterly dividend of $0.48 per share of common stock that was paid on January 15, 2012. We provide additional information about Sempra Energy dividends above in “Capital Resources and Liquidity – Overview – Sempra Energy Consolidated.”
 
SDG&E paid a $150 million common dividend to Sempra Energy in the first quarter of 2009 after an extended review period associated with the Sunrise Powerlink project delayed the planned construction start. SDG&E did not pay any common dividends to Sempra Energy in 2011 and 2010 to preserve cash to fund its capital expenditures program.
 

SoCalGas paid dividends to Pacific Enterprises (PE) and PE paid corresponding dividends to Sempra Energy of:
 
§  
$50 million in 2011
 
§  
$100 million in 2010
 
PE, a wholly owned subsidiary of Sempra Energy, owns all of SoCalGas’ outstanding common stock. Accordingly, dividends paid by SoCalGas to PE and dividends paid by PE to Sempra Energy are both eliminated in Sempra Energy’s consolidated financial statements.
 
The board of directors for each of Sempra Energy, SDG&E and SoCalGas has the discretion to determine the payment and amount of future dividends by each such entity. The CPUC’s regulation of SDG&E’s and SoCalGas’ capital structures limits the amounts that are available for loans and dividends to Sempra Energy. At December 31, 2011, Sempra Energy could have received combined loans and dividends of approximately $969 million from SoCalGas and approximately $400 million from SDG&E.
 
We provide additional information about restricted net assets in Note 1 of the Notes to Consolidated Financial Statements.
 
 
CAPITALIZATION
 

TOTAL CAPITALIZATION AND DEBT-TO-CAPITALIZATION RATIOS
(Dollars in millions)
 
 
As of December 31, 2011
 
 
Sempra Energy
 
 
 
 
 
 
 
 
 
Consolidated(1)
 
SDG&E(1)
 
SoCalGas
 
Total capitalization
$
 21,183 
 
$
 7,997 
 
$
 3,514 
 
Debt-to-capitalization ratio
 
 51 
%
 
 51 
%
 
 38 
%
(1)
Includes noncontrolling interests and debt of Otay Mesa Energy Center LLC for Sempra Energy and SDG&E with no significant impact.

Significant changes during 2011 that affected capitalization include the following:
 
§  
Sempra Energy Consolidated: comprehensive income exceeding dividends and net increases in long-term debt (including commercial paper classified as long-term)
 
§  
SDG&E: comprehensive income, a capital contribution from Sempra Energy and a net increase in long-term debt
 
§  
SoCalGas: comprehensive income exceeding dividends, partially offset by a net decrease in long-term debt
 
We provide additional information about these significant changes in Notes 1, 5 and 13 of the Notes to Consolidated Financial Statements.
 

COMMITMENTS
 
The following tables summarize principal contractual commitments, primarily long-term, at December 31, 2011 for Sempra Energy, SDG&E and SoCalGas. We provide additional information about commitments above and in Notes 5, 8 and 15 of the Notes to Consolidated Financial Statements.
 
PRINCIPAL CONTRACTUAL COMMITMENTS OF SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
 
 
2012 
2013 and 2014
2015 and 2016
Thereafter
Total
Long-term debt(1)
$
 320 
$
 1,987 
$
 1,102 
$
 6,401 
$
 9,810 
Interest on long-term debt(2)
 
 511 
 
 910 
 
 806 
 
 4,688 
 
 6,915 
Operating leases
 
 73 
 
 140 
 
 125 
 
 538 
 
 876 
Capital leases
 
 15 
 
 16 
 
 6 
 
 167 
 
 204 
Purchased-power contracts
 
 1,049 
 
 2,230 
 
 2,363 
 
 9,555 
 
 15,197 
Natural gas contracts
 
 558 
 
 431 
 
 121 
 
 257 
 
 1,367 
LNG contracts(3)
 
 517 
 
 1,314 
 
 1,507 
 
 12,131 
 
 15,469 
Construction commitments
 
 995 
 
 499 
 
 112 
 
 193 
 
 1,799 
SONGS decommissioning
 
 ― 
 
 ― 
 
 ― 
 
 524 
 
 524 
Other asset retirement obligations
 
 19 
 
 39 
 
 38 
 
 1,305 
 
 1,401 
Pension and other postretirement benefit
 
 
 
 
 
 
 
 
 
 
    obligations(4)
 
 274 
 
 607 
 
 556 
 
 756 
 
 2,193 
Environmental commitments
 
 12 
 
 18 
 
 3 
 
 13 
 
 46 
Other
 
 30 
 
 31 
 
 25 
 
 73 
 
 159 
Totals
$
 4,373 
$
 8,222 
$
 6,764 
$
 36,601 
$
 55,960 
(1)
Excludes $400 million commercial paper classified as long-term, as we discuss in Note 5 of the Notes to Consolidated Financial Statements.
(2)
We calculate expected interest payments using the stated interest rate for fixed-rate obligations, including floating-to-fixed interest rate swaps. We calculate expected interest payments for variable-rate obligations, including fixed-to-floating interest rate swaps, based on forward rates in effect at December 31, 2011.
(3)
Sempra LNG has various LNG purchase agreements with major international companies for the supply of LNG to Sempra LNG’s Energía Costa Azul and Cameron terminals. The agreements range from short-term to multi-year periods and are priced using a predetermined formula based on U.S. market indices. The expected payments under the contracts are based on forward prices of the applicable market index from 2012 to 2021 and an estimated one percent escalation per year after 2021. We provide more information about these contracts in Note 15 of the Notes to Consolidated Financial Statements.
(4)
Amounts represent expected company contributions to the plans for the next 10 years.

PRINCIPAL CONTRACTUAL COMMITMENTS OF SDG&E
(Dollars in millions)
 
 
2012 
2013 and 2014
2015 and 2016
Thereafter
Total
Long-term debt
$
 10 
$
 150 
$
 284 
$
 3,451 
$
 3,895 
Interest on long-term debt(1)
 
 187 
 
 371 
 
 351 
 
 2,637 
 
 3,546 
Operating leases
 
 19 
 
 36 
 
 34 
 
 46 
 
 135 
Capital leases
 
 9 
 
 11 
 
 6 
 
 167 
 
 193 
Purchased-power contracts
 
 319 
 
 581 
 
 460 
 
 1,948 
 
 3,308 
Construction commitments
 
 229 
 
 55 
 
 41 
 
 83 
 
 408 
SONGS decommissioning
 
 ― 
 
 ― 
 
 ― 
 
 524 
 
 524 
Other asset retirement obligations
 
 5 
 
 9 
 
 8 
 
 152 
 
 174 
Pension and other postretirement benefit
 
 
 
 
 
 
 
 
 
 
    obligations(2)
 
 81 
 
 185 
 
 148 
 
 160 
 
 574 
Environmental commitments
 
 2 
 
 3 
 
 2 
 
 11 
 
 18 
Totals
$
 861 
$
 1,401 
$
 1,334 
$
 9,179 
$
 12,775 
(1)
SDG&E calculates expected interest payments using the stated interest rate for fixed-rate obligations, including floating-to-fixed interest rate swaps. SDG&E calculates expected interest payments for variable-rate obligations based on forward rates in effect at December 31, 2011.
(2)
Amounts represent expected company contributions to the plans for the next 10 years.

PRINCIPAL CONTRACTUAL COMMITMENTS OF SOCALGAS
(Dollars in millions)
 
 
2012 
2013 and 2014
2015 and 2016
Thereafter
Total
Long-term debt
$
 250 
$
 250 
$
 8 
$
 805 
$
 1,313 
Interest on long-term debt(1)
 
 67 
 
 104 
 
 88 
 
 659 
 
 918 
Natural gas contracts
 
 400 
 
 157 
 
 81 
 
 145 
 
 783 
Operating leases
 
 28 
 
 56 
 
 54 
 
 240 
 
 378 
Capital leases
 
 6 
 
 5 
 
 ― 
 
 ― 
 
 11 
Construction commitments
 
 60 
 
 137 
 
 71 
 
 110 
 
 378 
Environmental commitments
 
 9 
 
 12 
 
 1 
 
 1 
 
 23 
Pension and other postretirement benefit
 
 
 
 
 
 
 
 
 
 
    obligations(2)
 
 153 
 
 348 
 
 332 
 
 474 
 
 1,307 
Asset retirement obligations
 
 14 
 
 30 
 
 29 
 
 1,102 
 
 1,175 
Totals
$
 987 
$
 1,099 
$
 664 
$
 3,536 
$
 6,286 
(1)
SoCalGas calculates interest payments using the stated interest rate for fixed-rate obligations.
(2)
Amounts represent expected company contributions to the plans for the next 10 years.

The tables exclude
 
§  
contracts between consolidated affiliates
 
§  
intercompany debt
 
§  
individual contracts that have annual cash requirements less than $1 million
 
§  
employment contracts
 
The tables also exclude income tax liabilities of
 
§  
$34 million for Sempra Energy Consolidated
 
§  
$7 million for SDG&E
 
These liabilities relate to uncertain tax positions and were excluded from the tables because we are unable to reasonably estimate the timing of future payments due to uncertainties in the timing of the effective settlement of tax positions. We provide additional information about unrecognized tax benefits in Note 7 of the Notes to Consolidated Financial Statements.
 
 
OFF BALANCE-SHEET ARRANGEMENTS
 
Sempra Energy has provided maximum guarantees aggregating $185 million at December 31, 2011 to related parties, including continuing transitional guarantees related to RBS Sempra Commodities. We discuss these guarantees in Notes 5 and 15 of the Notes to Consolidated Financial Statements.
 

 

CREDIT RATINGS
 

The credit ratings of Sempra Energy, SDG&E and SoCalGas remained at investment grade levels in 2011. In August 2011, Fitch downgraded the rating on Sempra Energy’s unsecured debt from A- with a negative outlook to BBB+ with a stable outlook, consistent with Moody’s and Standard & Poor’s (S&P) ratings. Also at that time, Fitch affirmed that this downgrade had no effect on SDG&E’s and SoCalGas’ ratings.
 
Sempra Energy, SDG&E and SoCalGas have committed lines of credit to provide liquidity and to support commercial paper and variable-rate demand notes. Borrowings under these facilities bear interest at benchmark rates plus a margin that varies with market index rates and each borrower’s credit rating. Each facility also requires a commitment fee on available unused credit.
 
Under these committed lines, if Sempra Energy were to experience a ratings downgrade from its current level, the rate at which borrowings bear interest would increase by 25 to 50 basis points, depending on the severity of the downgrade. The commitment fee on available unused credit would also increase 15 to 25 basis points, depending on the severity of the downgrade.
 
Under these committed lines, if SDG&E or SoCalGas were to experience a ratings downgrade from its current level, the rate at which borrowings bear interest would increase by 25 to 75 basis points, depending on the severity of the downgrade. The commitment fee on available unused credit would also increase 2.5 to 22.5 basis points, depending on the severity of the downgrade.
 
For Sempra Energy and SDG&E, their credit ratings may affect credit limits related to derivative instruments, as we discuss in Note 10 of the Notes Consolidated Financial Statements.
 

 

FACTORS INFLUENCING FUTURE PERFORMANCE
 

 
SEMPRA ENERGY OVERVIEW
 
The Sempra Utilities’ operations have historically provided relatively stable earnings and liquidity. However, for the next few years, SoCalGas intends to limit its common stock dividends to reinvest its earnings in significant capital projects.
 
Sempra Generation is developing and investing in renewable energy generation projects that have long-term contracts with utilities. The renewable projects have planned in-service dates ranging from 2012 to 2016. These projects require construction financing from a variety of sources including operating cash flow, project financing, low-cost financing procured under the U.S. Department of Energy’s (DOE) loan guaranty program, U.S. Treasury Department cash grants, funds from the parent and partnering in joint ventures. The varying costs of these alternative financing sources impact the projects’ returns.
 
Current energy market prices are significantly lower than those under Sempra Generation’s contract with the DWR, which ended on September 30, 2011 and had provided a significant portion of Sempra Generation’s revenues. Revenues from Sempra Generation’s natural gas generation plants are also expected to be lower due to a decline in market demand and the sale of Sempra Generation’s El Dorado natural gas generation plant to SDG&E on October 1, 2011. Based on current market prices for electricity, contracts Sempra Generation enters into at its natural gas-fired plants to replace the DWR contract, if obtained, or merchant (daily) sales will provide substantially lower earnings.
 
In 2012, Sempra Energy intends to change the accounting methodology that it currently uses to recognize investment tax credits, which currently impacts only those credits associated with Sempra Generation’s solar projects. Through December 31, 2011, Sempra Generation used what is referred to as the flow-through method of accounting in which the investment tax credits associated with a project are recognized as a reduction of tax expense in the year in which capacity is placed in service. Starting in the first quarter of 2012, Sempra Generation will change to the deferral method of accounting for these projects. Under this methodology, instead of recognizing the investment tax credit, Sempra Generation will reduce the book basis of the asset by the amount of the tax credit. This results in lower book depreciation and therefore higher future earnings as compared to our current method. This change in accounting principle will be applied retrospectively in the first quarter of 2012. The decrease in net income and earnings from retroactively adopting the deferral method is estimated to be $26 million and $30 million, respectively, for the years ended December 31, 2011 and 2010, and a negligible amount for the year ended December 31, 2009.
 
This change in accounting for solar investment tax credits has no impact from an economic perspective. This change only affects when Sempra Generation recognizes earnings for these projects, but it does not affect the timing of cash flows. These projects are contracted for 20 to 25 years with utility counterparties.
 
In April 2011, Sempra Pipelines & Storage increased its investment in two utilities in South America. We expect the acquisition to be accretive to our earnings per share. However, in connection with our increased interests in Chilquinta Energía and Luz del Sur, Sempra Energy added $975 million in goodwill to its Consolidated Balance Sheet as of December 31, 2011. Goodwill is subject to impairment testing, annually and under other potential circumstances, which may cause its fair value to vary if differing estimates and assumptions are used in the valuation techniques applied as indicated by changing market or other conditions.
 
We discuss the acquisition in Note 3 of the Notes to Consolidated Financial Statements. Sempra Pipelines & Storage is also expected to provide earnings from construction projects when completed and other investments, but will require substantial funding for these investments.
 
At Sempra LNG, until there are firm LNG supply or capacity services contracts from third parties that would subscribe to 100 percent of the capacity of Sempra LNG’s Cameron terminal, Sempra LNG will seek to purchase short-term LNG supplies and sell short-term capacity, which may result in greater variability in revenues and earnings. Sempra LNG is currently evaluating opportunities to utilize its assets to support the liquefaction and exportation of LNG. The objective is to obtain a long-term contract and fully utilize our existing infrastructure while minimizing our future additional capital investment. In January 2012, the DOE approved Cameron LNG’s application for an LNG export license.
 
The Sempra Utilities’ performance will depend primarily on the ratemaking and regulatory process, environmental regulations, economic conditions, actions by the California legislature to address the state budget crisis and the changing energy marketplace. Their performance will also depend on the successful completion of capital projects that we discuss in various sections of this report.
 
Both SDG&E and SoCalGas have their 2012 General Rate Case (GRC) applications pending at the CPUC. The Sempra Utilities filed their initial applications for the 2012 GRC in December 2010 to establish their authorized 2012 revenue requirements and the ratemaking mechanisms by which those requirements will change on an annual basis over the subsequent three-year (2013-2015) period. In July 2011, SDG&E and SoCalGas filed revised applications and in February 2012, SDG&E and SoCalGas filed amendments to update the July 2011 filing. The 2012 amendments revised the requested increases to their authorized revenue requirements, as compared to their 2011 authorized revenues, to $235 million at SDG&E and to $268 million at SoCalGas. The Division of Ratepayer Advocates and other intervening parties are recommending that the CPUC reduce the utilities’ revenue requirements in 2012 by approximately 5 percent compared to 2011.
 
Evidentiary hearings were completed in January 2012 and final briefs reflecting the results from these hearings are scheduled to be filed with the CPUC by May 1, 2012. The final decision for the 2012 GRC will be made effective retroactive to January 1, 2012. However, until such time as a final decision is rendered, both SDG&E and SoCalGas are operating under the rates that were in effect in 2011 for the items addressed in the GRC process. The timing of the CPUC decision and the outcome from these proceedings will have an impact on the financial condition and operating results of the Sempra Utilities. If the CPUC’s final decision grants a significantly lower authorized revenue requirement, it could result in a material adverse effect to the Sempra Utilities’ cash flows, financial position and results of operations starting in 2012 as compared to 2011. More detailed information regarding the 2012 GRC is discussed in Note 14 of the Notes to the Consolidated Financial Statements.
 
In regard to the 2007 wildfire litigation, SDG&E’s settlement of claims and the estimate of outstanding claims and legal fees is approximately $2 billion, which is in excess of the $1.1 billion of liability insurance coverage and the $444 million of proceeds received as a result of the settlement with Cox Communications. However, SDG&E has concluded that it is probable that it will be permitted to recover from its utility customers substantially all reasonably incurred costs of resolving wildfire claims in excess of its liability insurance coverage and amounts recovered from other potentially responsible parties. Consequently, Sempra Energy and SDG&E expect no significant earnings impact from the resolution of the remaining wildfire claims. As of December 31, 2011, SDG&E’s Consolidated Balance Sheet reflects a regulatory asset in the amount of $594 million for these costs. However, SDG&E’s cash flow may be adversely affected by timing differences between the resolution of claims and recoveries from other potentially responsible parties and utility customers, which may extend over a number of years. In addition, recovery from customers will require future regulatory actions, and a failure to obtain substantial or full recovery, or any negative assessment of the likelihood of recovery, would likely have a material adverse effect on Sempra Energy’s and SDG&E’s financial condition, cash flows and results of operations.
 
SDG&E will continue to gather information to evaluate and assess the remaining wildfire claims and the likelihood, amount and timing of related recoveries from other potentially responsible parties and utility customers and will make appropriate adjustments to wildfire reserves and the related regulatory asset as additional information becomes available. We provide additional information concerning these matters in Notes 14 and 15 of the Notes to Consolidated Financial Statements.
 
SDG&E has a 20-percent ownership interest in San Onofre Nuclear Generating Station (SONGS), a 2,150-MW nuclear generating facility near San Clemente, California. SONGS is operated by Southern California Edison Company (Edison) and is subject to the jurisdiction of the NRC. Edison is currently addressing a number of regulatory and performance issues at SONGS, and the NRC has required Edison to take actions to provide greater assurance of compliance by SONGS personnel. Edison continues to implement plans and address the identified issues, however a number of these issues remain outstanding. To the extent that these issues persist, the likelihood of further required action by Edison persists, which may result in increased SONGS operating costs and/or adversely impacted operations. Currently, SDG&E is allowed to fully offset its share of SONGS operating costs in revenue. If further action is required, it may result in an increase in SDG&E’s Operation and Maintenance expense, with any increase being fully offset in Operating Revenues – Electric or, if electric generation is adversely impacted, require SDG&E to procure additional electricity supply from other sources.
 
In light of the aftermath and the significant safety events at the Fukushima Daiichi nuclear plant in Japan resulting from the earthquake and tsunami in March 2011, the NRC plans to perform additional operation and safety reviews of nuclear facilities in the United States. The lessons learned from the events in Japan and the results of the NRC reviews may impact future operations and capital requirements at nuclear facilities in the United States, including the operations and capital requirements at SONGS.
 
In 2010 and 2011, Edison installed four replacement steam generators in SONGS’ Units 2 and 3. Inspections of the Unit 2 steam generators during a planned maintenance and refueling outage in February 2012 found isolated areas of wear in some of the approximately 19,500 heat transfer tubes. As the steam generators are designed to include sufficient tubes to accommodate a need to remove some from service, Edison, in consultation with the steam generators’ manufacturer, determined that a number of the tubes should be removed from service as a preventive measure with the number of tubes being removed from service being well within the extra margin. Additionally, on January 31, 2012, a water leak was detected in one of the tubes of a new steam generator in Unit 3, and the unit was safely taken offline. Extensive testing of the Unit 3 steam generators is ongoing to fully understand the cause of the leak. In a memorandum dated February 16, 2012, the NRC determined that inasmuch as the leak was in a newly installed steam generator, it will conduct an event follow-up baseline inspection to review Edison’s response to the leak and verify the appropriateness of its remedial actions. Each unit will be restarted when repairs on that unit are completed, and Edison is satisfied that it is safe to do so.
 
The steam generators are warranted for an initial period of 20 years from acceptance by its supplier, Mitsubishi Heavy Industries (MHI). Subject to certain exceptions, the purchase agreement sets forth specified damages for certain repairs, generally limits MHI’s aggregate contractual liability to the purchase price of the generators and excludes consequential damages from recovery, such as the cost of replacement power. We provide more information about SONGS in Notes 6, 14 and 15 of the Notes to Consolidated Financial Statements.
 
Pending the outcome of the various regulatory agency evaluations of natural gas pipeline safety regulations, practices and procedures, Sempra Energy, including the Sempra Utilities, may incur incremental expense and capital investment associated with its natural gas pipeline operations and investments. In August 2011, SoCalGas, SDG&E, PG&E and Southwest Gas filed implementation plans to test or replace all natural gas transmission pipelines that have not been pressure tested with the CPUC as we discuss in Note 14 of the Notes to Consolidated Financial Statements. The Sempra Utilities are currently estimating that the total cost for Phase 1 of the two-phase plan is $3.1 billion over a 10-year period. The Sempra Utilities requested that the incremental capital investment required as a result of any approved plan be included in rate base and that cost recovery be allowed for any other incremental cost not eligible for rate-base recovery. The costs that are the subject of these plans are outside the scope of the 2012 GRC proceedings discussed above.
 
SDG&E’s next CPUC cost of capital proceeding is scheduled to be filed in April 2012 for a 2013 test year. In its 2012 GRC, SoCalGas has advised the CPUC of its intent to file its next CPUC cost of capital proceeding on the same schedule as SDG&E. A cost of capital proceeding determines the authorized capital structure, authorized rate of return and authorized rate for recovery of debt service costs on SDG&E’s electric distribution and generation assets and on both companies’ natural gas transmission and distribution assets. SDG&E’s and SoCalGas’ current CPUC authorized return on equity (ROE) is 11.10 percent and 10.82 percent, respectively, with authorized common equity capital structures of 49.00 percent and 48.00 percent, respectively. If the proceedings result in either a reduction in the authorized ROE or in the authorized common equity capital structure, it would have an adverse effect on the respective company’s cash flows, financial position and results of operations starting in 2013. Also, to the extent that either company’s authorized rate for recovery of debt service costs is higher than their actual rate of debt service costs at the time of the cost of capital proceeding, the authorized rate for recovery of debt service costs will be reduced to the actual rate of debt service costs, which would adversely affect the respective company’s cash flows, financial position and results of operations starting in 2013. We provide more information about the cost of capital proceedings in Note 14 of the Notes to Consolidated Financial Statements.
 
SoCalGas’ cost of capital trigger mechanism (the Market Indexed Capital Adjustment Mechanism or MICAM) identifies two conditions for determining whether a change in the authorized rate of return is required. Both conditions are based on the 30-year Treasury bond yields – one being the most recent trailing 12-month rolling average yield and the second being the corresponding 12-month forward forecasted yield as published by Global Insight. If both conditions fall outside a range of 3.88 percent (MICAM floor) to 6.88 percent (MICAM ceiling) in a given month, SoCalGas’ authorized ROE would be adjusted, upward or downward, by one-half of the difference between the trailing 12-month rolling average yield and 5.38 percent (SoCalGas’ MICAM benchmark interest rate), effective January 1 following the year in which both conditions were exceeded. Also, SoCalGas’ authorized recovery rate for the cost of debt and preferred stock would be adjusted to their actual weighted average cost. Therefore, SoCalGas’ authorized rate of return (ROR) would adjust, upward or downward, as a result of all three cost adjustments.
 
At December 31, 2011, neither SDG&E’s nor SoCalGas’ benchmark range has been exceeded. As of January 31, 2012, the historical rolling average yield for the 30-year Treasury bonds of 3.79 percent fell below the MICAM floor of 3.88 percent. In addition, the Global Insight 12-month forward forecasted yield of 3.48 percent published in early February 2012 is also below the MICAM floor. Therefore, SoCalGas’ MICAM mechanism calls for an adjustment of its ROE and authorized recovery for the cost of debt and preferred stock to their actual weighted average cost to be effective on January 1, 2013. However, as SoCalGas has advised the CPUC of its plan to file a cost of capital application in April 2012 along with the other California investor-owned utilities, SoCalGas expects that the decision from this cost of capital application will supersede the rates that would result from the MICAM trigger. As there haven’t been any objections raised to SoCalGas’ proposal to file a cost of capital application, management believes that the CPUC will accept SoCalGas’ application. Absent a SoCalGas cost of capital application and proceeding, SoCalGas’ ROE would be reduced to 10.02 percent effective January 1, 2013, a reduction of 80 basis points from its current authorized ROE, and its authorized ROR would be reduced to 8.05 percent, a reduction of 63 basis points from its current authorized ROR.
 
The current FERC formulaic rate methodology for SDG&E’s electric transmission assets will be reviewed in 2013, with the new rates effective in September 2013. This proceeding will assess the rate-making methodology to be employed for SDG&E’s FERC-regulated operations, including a determination of SDG&E’s FERC-authorized ROE and recovery of operation and maintenance expenses. If this proceeding results in a reduction from SDG&E’s current authorized ROE of 11.35 percent or in an adverse determination for the recovery of operation and maintenance expenses, it would adversely affect SDG&E’s cash flows, results of operations and financial condition.
 
We discuss additional potential and expected impacts of the 2010 Tax Act on our income tax expense, earnings and cash flows in “Results of Operations – Changes in Revenues, Costs and Earnings – Income Taxes” above.
 
In three separate transactions in 2010 and one in early 2011, we and RBS sold substantially all of the businesses and assets of our commodities-marketing partnership. We expect our share of the remaining proceeds from the sales of all of the joint venture’s businesses and related cash distributions to approximate $126 million, the amount of our remaining investment in the joint venture. We provide additional information in Notes 4 and 5 of the Notes to Consolidated Financial Statements.
 
We may be further impacted by depressed and rapidly changing economic conditions. Moreover, the dollar has fluctuated significantly compared to some foreign currencies, especially in Mexico and South America where we have significant operations. We discuss foreign currency rate risk further below under “Market Risk—Foreign Currency Rate Risk.” North American natural gas prices, which affect profitability at Sempra Generation and Sempra LNG, are currently significantly below Asian and European prices. These factors could, if they remain unchanged, adversely affect profitability.
 
We discuss additional matters that could affect our future performance in Notes 14 and 15 of the Notes to Consolidated Financial Statements.
 
 
FINANCIAL DERIVATIVES REFORMS
 
In July 2010, federal legislation to reform financial markets was enacted that significantly alters how over-the-counter (OTC) derivatives are regulated, which may impact all of our businesses. The law increased regulatory oversight of OTC energy derivatives, including (1) requiring standardized OTC derivatives to be traded on registered exchanges regulated by the U.S. Commodity Futures Trading Commission (CFTC), (2) imposing new and potentially higher capital and margin requirements and (3) authorizing the establishment of overall volume and position limits. The law gives the CFTC authority to exempt end users of energy commodities which could reduce, but not eliminate, the applicability of these measures to us and other end users. These requirements could cause our OTC transactions to be more costly and have an adverse effect on our liquidity due to additional capital requirements. In addition, as these reforms aim to standardize OTC products, they could limit the effectiveness of our hedging programs, because we would have less ability to tailor OTC derivatives to match the precise risk we are seeking to mitigate.
 
 
LITIGATION
 
We describe legal proceedings which could adversely affect our future performance in Note 15 of the Notes to Consolidated Financial Statements.
 
 
SEMPRA UTILITIES – INDUSTRY DEVELOPMENTS AND CAPITAL PROJECTS
 
We describe capital projects, electric and natural gas regulation and rates, and other pending proceedings and investigations that affect our business in Note 14 of the Notes to Consolidated Financial Statements.
 
 
SEMPRA GLOBAL INVESTMENTS
 
As we discuss in “Cash Flows From Investing Activities,” our investments will significantly impact our future performance. In addition to the discussion below, we provide information about these investments in “Capital Resources and Liquidity.”
 
 
Sempra Generation
 
Copper Mountain Solar
 
Copper Mountain Solar is a photovoltaic generation facility operated and under development by Sempra Generation in Boulder City, Nevada. When fully developed, the project will be capable of producing up to approximately 400 MW of solar power. Copper Mountain Solar 1 is a 58-MW photovoltaic generation facility currently in operation, and now includes the 10-MW facility previously referred to as El Dorado Solar.
 
Copper Mountain Solar 2 (CMS 2) will total 150 MW and construction began in December 2011. CMS 2 is divided into two phases, with the first phase of 92 MW planned to be completed by the end of January 2013 and the remaining 58 MW planned to be completed in 2015. PG&E has contracted for all of the solar power at CMS 2 for 25 years and has an option to accelerate the second phase of 58 MW to be available before 2015. The contract was approved by the CPUC in December 2011.
 
Mesquite Solar
 
Mesquite Solar is a photovoltaic generation facility under development by Sempra Generation in Maricopa County, Arizona. When fully developed, the project will be capable of producing up to approximately 700 MW of solar power. Construction of the first phase (Mesquite Solar 1) of 150 MW began in June 2011 and is expected to be completed in early 2013. In December 2011, solar panels were fully installed and began delivering 42 MW of electricity to the grid. PG&E has contracted for all of the solar power at Mesquite Solar 1 for 20 years, which contract was approved by the CPUC in April 2011.
 
Auwahi Wind
 
In January 2011, Sempra Generation entered into a 20-year contract with Maui Electric Company to provide 21 MW of wind energy from the Auwahi Wind project in the southeastern region of Maui. The contract was approved by the Hawaii Public Utilities Commission in June 2011. We expect construction on the project to begin in early 2012, and the project to be fully operational in late 2012.
 
In October 2011, Sempra Generation, 100-percent owner of the Auwahi Wind project, sold a 50-percent interest to a BP affiliate, Auwahi Wind Energy Holdings.
 
Energía Sierra Juárez
 
In April 2011, SDG&E entered into a 20-year contract for renewable power supplied from the 156-MW first phase of Sempra Generation’s Energía Sierra Juárez wind project in Baja California, Mexico. The contract is subject to approval by the CPUC and FERC. We expect construction on the project to begin in 2012, and the project to be fully operational in 2014.
 
Sempra Generation intends to develop the project within the framework of a joint venture, and is working on an agreement for the sale of a 50-percent partnership interest in the current phase of the project to BP Wind Energy.
 
Mehoopany Wind Farm
 
In December 2011, Sempra Generation entered into a joint venture with BP Wind Energy to develop the Mehoopany Wind Farm in Wyoming County, Pennsylvania, which is expected to generate up to 141 MW of energy. The power output from the wind farm has been sold under 20-year contracts to Old Dominion Electric Cooperative and Southern Maryland Electric Cooperative Inc. Construction began in November 2011, and we expect the project to be fully operational by the end of 2012.
 
Flat Ridge 2 Wind Farm
 
In December 2011, Sempra Generation entered into a joint venture with BP Wind Energy to develop the Flat Ridge 2 Wind Farm near Wichita, Kansas, which is expected to generate up to 419 MW of energy. The power output from the wind farm has been sold under three contracts for 20 to 25 year terms, including contracts with Associated Electric Cooperative, Inc. and Southwestern Electric Power Company. We expect the project to be fully operational by the end of 2012.
 
 
Sempra Pipelines & Storage
 
Natural Gas Storage Projects
 
Currently, Sempra Pipelines & Storage has 23 Bcf of operational working natural gas storage capacity. We are currently developing another 20 Bcf of capacity with planned in-service dates through 2013 and may, over the long term, develop as much as 76 Bcf of total storage capacity.
 
Sempra Pipelines & Storage’s natural gas storage facilities and projects include
 
§  
Bay Gas, a facility located 40 miles north of Mobile, Alabama, that provides underground storage and delivery of natural gas. Sempra Pipelines & Storage owns 91 percent of the project. It is the easternmost salt dome storage facility on the Gulf Coast, with direct service to the Florida market and markets across the Southeast, Mid-Atlantic and Northeast regions.
 
§  
Mississippi Hub, located 45 miles southeast of Jackson, Mississippi, an underground salt dome natural gas storage project with access to shale basins of East Texas and Louisiana, traditional gulf supplies and LNG, with multiple interconnections to serve the Southeast and Northeast regions.
 
§  
Liberty natural gas storage expansion, a salt cavern development project in Cameron Parish, Louisiana. Sempra Pipelines & Storage owns 75 percent of the project and ProLiance Transportation LLC owns the remaining 25 percent. The project’s location provides access to several LNG facilities in the area.
 

South American Utilities
 
We discuss the April 2011 increase in Sempra Pipelines & Storage’s investments in Chile and Peru in Note 3 of the Notes to Consolidated Financial Statements.
 
Santa Teresa. In May 2011, groundbreaking took place for Santa Teresa, a project at Luz del Sur to build a 98-MW hydroelectric power plant in Peru’s Cusco region. It is planned to be completed in 2014.
 
 
MARKET RISK
 
Market risk is the risk of erosion of our cash flows, earnings, asset values and equity due to adverse changes in market prices, and interest and foreign currency rates.
 
 
Risk Policies
 
Sempra Energy has policies governing its market risk management and trading activities. As required by CPUC and FERC affiliate compliance rules, Sempra Energy and the Sempra Utilities maintain separate and independent risk management committees, organizations and processes for each of the Sempra Utilities and for all non-CPUC regulated affiliates to provide oversight of these activities. The committees consist of senior officers who establish policy, oversee energy risk management activities, and monitor the results of trading and other activities to ensure compliance with our stated energy risk management and trading policies. These activities include, but are not limited to, daily monitoring of market positions that create credit, liquidity and market risk. The respective oversight organizations and committees are independent from the energy procurement departments.
 
Along with other tools, we use Value at Risk (VaR) to measure our exposure to market risk primarily associated with commodity derivative instruments that we hold. VaR is an estimate of the potential loss on a position or portfolio of positions over a specified holding period, based on normal market conditions and within a given statistical confidence interval. VaR is calculated independently by the respective risk management oversight organizations. We use historical volatilities and correlations between instruments and positions in our calculations.
 
The Sempra Utilities use energy and natural gas derivatives to manage natural gas and energy price risk associated with servicing load requirements. The use of energy and natural gas derivatives is subject to certain limitations imposed by company policy and is in compliance with risk management and trading activity plans that have been filed with and approved by the CPUC. Any costs or gains/losses associated with the use of energy and natural gas derivatives are considered to be commodity costs. Commodity costs are generally passed on to customers as incurred. However, SoCalGas is subject to incentive mechanisms that reward or penalize the utility for commodity costs below or above certain benchmarks.
 
In 2010 and early 2011, Sempra Energy and RBS completed the divestiture of substantially all of the businesses and assets of RBS Sempra Commodities, their joint venture partnership, in four separate transactions, as we discuss in Note 4 of the Notes to Consolidated Financial Statements. In connection with each of these transactions, the buyers were, subject to certain qualifications, obligated to replace any guarantees that we had issued in connection with the applicable businesses sold with guarantees of their own. At December 31, 2011, the buyers have substantially completed this process for those counterparties with existing, open positions. For those guarantees which have not been replaced, the buyers are obligated to indemnify us in accordance with the applicable transaction documents for any claims or losses in connection with the guarantees that we issued associated with the businesses sold. We provide additional information in Note 1 of the Notes to Consolidated Financial Statements.
 
In addition, as a transitional measure, Sempra Energy continues to provide back-up guarantees and credit support for RBS Sempra Commodities, as we discuss above in “Capital Resources and Liquidity” and in Note 5 of the Notes to Consolidated Financial Statements.
 
We discuss revenue recognition in Notes 1 and 10 of the Notes to Consolidated Financial Statements and the additional market-risk information regarding derivative instruments in Note 10 of the Notes to Consolidated Financial Statements.
 
We have exposure to changes in commodity prices, interest rates and foreign currency rates and exposure to counterparty nonperformance. The following discussion of these primary market-risk exposures as of December 31, 2011, includes a discussion of how these exposures are managed.
 
 
Commodity Price Risk
 
Market risk related to physical commodities is created by volatility in the prices and basis of certain commodities. Our various subsidiaries are exposed, in varying degrees, to price risk, primarily to prices in the natural gas and electricity markets. Our policy is to manage this risk within a framework that considers the unique markets and operating and regulatory environments of each subsidiary.
 
Sempra Global is generally exposed to commodity price risk indirectly through its LNG, natural gas pipeline and storage, and power generating assets. Sempra Global may utilize commodity transactions in the course of optimizing these assets. These transactions are typically priced based on market indices, but may also include fixed price purchases and sales of commodities. Any residual exposure is monitored as described above.
 
The Sempra Utilities’ market-risk exposure is limited due to CPUC-authorized rate recovery of the costs of commodity purchases, intrastate transportation, and storage activity. However, SoCalGas may, at times, be exposed to market risk as a result of incentive mechanisms that reward or penalize the utility for commodity costs below or above certain benchmarks for SoCalGas’ Gas Cost Incentive Mechanism, which we discuss in Note 14 of the Notes to Consolidated Financial Statements. If commodity prices were to rise too rapidly, it is likely that volumes would decline. This decline would increase the per-unit fixed costs, which could lead to further volume declines. The Sempra Utilities manage their risk within the parameters of their market risk management framework. As of December 31, 2011, the total VaR of the Sempra Utilities’ natural gas and electric positions was not material, and the procurement activities were in compliance with the procurement plans filed with and approved by the CPUC.
 
 
Interest Rate Risk
 
We are exposed to fluctuations in interest rates primarily as a result of our having issued short- and long-term debt. Subject to regulatory constraints, we periodically enter into interest rate swap agreements to moderate our exposure to interest rate changes and to lower our overall costs of borrowing.
 
The table below shows the nominal amount and the one-year VaR for long-term debt, excluding commercial paper classified as long-term debt and capital lease obligations, at December 31, 2011 and 2010:
 

 
Sempra Energy
 
 
 
 
 
 
 
Consolidated
 
SDG&E
 
SoCalGas
 
Nominal
One-Year
 
Nominal
One-Year
 
Nominal
One-Year
(Dollars in millions)
Debt
VaR(1)
 
Debt
VaR(1)
 
Debt
VaR(1)
At December 31, 2011
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    Sempra Utility fixed-rate
$
 4,617 
$
 782 
 
$
 3,304 
$
 623 
 
$
 1,313 
$
 159 
    Sempra Utility variable-rate
 
 591 
 
 25 
 
 
 591 
 
 25 
 
 
 ― 
 
 ― 
    All other, fixed-rate and variable-rate
 
 4,602 
 
 377 
 
 
 ― 
 
 ― 
 
 
 ― 
 
 ― 
At December 31, 2010
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    Sempra Utility fixed-rate
$
 4,117 
$
 787 
 
$
 2,704 
$
 587 
 
$
 1,413 
$
 200 
    Sempra Utility variable-rate
 
 751 
 
 59 
 
 
 601 
 
 59 
 
 
 150 
 
 ― 
    All other, fixed-rate and variable-rate
 
 3,459 
 
 509 
 
 
 ― 
 
 ― 
 
 
 ― 
 
 ― 
(1) After the effects of interest rate swaps.

At December 31, 2011, the total notional amount of interest rate swap transactions ranged from $15 million to $305 million at Sempra Energy and $285 million to $355 million at SDG&E (ranges relate to amortizing notional amounts). We provide further information about interest rate swap transactions in Note 10 of the Notes to Consolidated Financial Statements.
 
We also are subject to the effect of interest rate fluctuations on the assets of our pension plans, other postretirement benefit plans, and SDG&E’s nuclear decommissioning trusts. However, we expect the effects of these fluctuations, as they relate to the Sempra Utilities, to be passed on to customers.
 
 
Credit Risk
 
Credit risk is the risk of loss that would be incurred as a result of nonperformance of our counterparties’ contractual obligations. We monitor credit risk through a credit-approval process and the assignment and monitoring of credit limits. We establish these credit limits based on risk and return considerations under terms customarily available in the industry.
 
As with market risk, we have policies governing the management of credit risk that are administered by the respective credit departments for each of the Sempra Utilities and, on a combined basis, for all non-CPUC regulated affiliates and overseen by their separate risk management committees.
 
This oversight includes calculating current and potential credit risk on a daily basis and monitoring actual balances in comparison to approved limits. We avoid concentration of counterparties whenever possible, and we believe our credit policies significantly reduce overall credit risk. These policies include an evaluation of the following:
 
§  
prospective counterparties’ financial condition (including credit ratings)
 
§  
collateral requirements
 
§  
the use of standardized agreements that allow for the netting of positive and negative exposures associated with a single counterparty
 
§  
downgrade triggers
 
We believe that we have provided adequate reserves for counterparty nonperformance.
 
When development projects at Sempra Global become operational, they rely significantly on the ability of their suppliers to perform on long-term agreements and on our ability to enforce contract terms in the event of nonperformance. Also, the factors that we consider in evaluating a development project include negotiating customer and supplier agreements and, therefore, we rely on these agreements for future performance. We also may base our decision to go forward on development projects on these agreements.
 
As noted above under “Interest Rate Risk,” we periodically enter into interest rate swap agreements to moderate exposure to interest rate changes and to lower the overall cost of borrowing. We would be exposed to interest rate fluctuations on the underlying debt should a counterparty to the swap fail to perform.
 
 
Foreign Currency Rate Risk
 
We have investments in entities whose functional currency is not the U.S. dollar, exposing us to foreign exchange movements, primarily in Latin American currencies.
 
The Mexican subsidiaries have U.S. dollar receivables and payables that give rise to foreign exchange movements for accounting principles generally accepted in Mexico and tax purposes. In addition, monetary assets and liabilities are adjusted for inflation for Mexican tax purposes. The fluctuations in foreign currency and inflation are subject to Mexican taxes and expose us to significant fluctuations in tax expense from changes in the exchange and inflation rates in Mexico.
 
Our primary objective in reducing foreign currency risk is to preserve the economic value of our overseas investments and to reduce earnings volatility that would otherwise occur due to exchange rate fluctuations. We may offset material cross-currency transactions and net income exposure through various means, including financial instruments and short-term investments. Because we do not hedge our net investment in foreign countries, we are susceptible to volatility in other comprehensive income caused by exchange rate fluctuations.
 
The hypothetical effects for every one percent appreciation in the U.S. dollar from year-end 2011 levels against the currencies of Latin American countries in which we have operations and investments are as follows:
 

(Dollars in millions)
 
Hypothetical Effects
 
Translation of 2011 earnings to U.S. dollars
$
 (2)
 
Transactional exposures
 
 - 
 
Translation of net assets of foreign subsidiaries and investments in foreign entities
 
 (17)

 
Although the balances of monetary assets and liabilities at our Mexican subsidiaries may fluctuate significantly throughout the year, based on long-term debt balances with non-Mexican entities of $335 million at December 31, 2011, the hypothetical effect for Sempra Energy for every one percent increase in the Mexican inflation rate is approximately $1 million of additional income tax expense at our Mexican subsidiaries.
 

 

CRITICAL ACCOUNTING POLICIES AND ESTIMATES, AND KEY NONCASH PERFORMANCE INDICATORS
 

Management views certain accounting policies as critical because their application is the most relevant, judgmental, and/or material to our financial position and results of operations, and/or because they require the use of material judgments and estimates.
 
We describe our significant accounting policies in Note 1 of the Notes to Consolidated Financial Statements.  We discuss choices among alternative accounting policies that are material to our financial statements and information concerning significant estimates with the audit committee of the Sempra Energy board of directors.
 

CRITICAL ACCOUNTING POLICIES
SEMPRA ENERGY, SDG&E AND SOCALGAS
CONTINGENCIES
Assumptions & Approach Used
 
We accrue losses for the estimated impacts of various conditions, situations or circumstances involving uncertain outcomes. For loss contingencies, we accrue the loss if an event has occurred on or before the balance sheet date and:
 
§ information available through the date we file our financial statements indicates it is probable that a loss has been incurred, given the likelihood of uncertain future events, and
 
§ the amount of the loss can be reasonably estimated.
 
 
We do not accrue contingencies that might result in gains. We continuously assess contingencies for litigation claims, environmental remediation and other events.
Effect if Different
Assumptions Used
 
Details of our issues in this area are discussed in Note 15 of the Notes to Consolidated Financial Statements.
 
REGULATORY ACCOUNTING
Assumptions & Approach Used
 
The Sempra Utilities record a regulatory asset if it is probable that, through the ratemaking process, the utility will recover that asset from customers. Similarly, regulatory liabilities are recorded for amounts recovered in rates in advance of the expenditure. The Sempra Utilities review probabilities associated with regulatory balances whenever new events occur, such as:
 
§ changes in the regulatory environment or the utility’s competitive position
 
§ issuance of a regulatory commission order
 
§ passage of new legislation
 
 
To the extent that circumstances associated with regulatory balances change, the regulatory balances are adjusted accordingly.
Effect if Different
Assumptions Used
 
Details of the Sempra Utilities’ regulatory assets and liabilities are discussed in Notes 1 and 15 of the Notes to Consolidated Financial Statements.


SEMPRA ENERGY, SDG&E AND SOCALGAS (CONTINUED)
INCOME TAXES
Assumptions & Approach Used
 
Our income tax expense and related balance sheet amounts involve significant management estimates and judgments. Amounts of deferred income tax assets and liabilities, as well as current and noncurrent accruals, involve judgments and estimates of the timing and probability of recognition of income and deductions by taxing authorities. When we evaluate the anticipated resolution of income tax issues, we consider
 
§ past resolutions of the same or similar issue
 
§ the status of any income tax examination in progress
 
§ positions taken by taxing authorities with other taxpayers with similar issues
 
 
The likelihood of deferred tax recovery is based on analyses of the deferred tax assets and our expectation of future taxable income, based on our strategic planning.
Effect if Different
Assumptions Used
 
Actual income taxes could vary from estimated amounts because of:
 
§ future impacts of various items, including changes in tax laws
 
§ our financial condition in future periods
 
§ the resolution of various income tax issues between us and taxing authorities
 
 
We discuss details of our issues in this area in Note 7 of the Notes to Consolidated Financial Statements.
Assumptions & Approach Used
 
For an uncertain position to qualify for benefit recognition, the position must have at least a “more likely than not” chance of being sustained (based on the position’s technical merits) upon challenge by the respective authorities. The term “more likely than not” means a likelihood of more than 50 percent. If we do not have a more likely than not position with respect to a tax position, then we do not recognize any of the potential tax benefit associated with the position. A tax position that meets the “more likely than not” recognition is measured as the largest amount of tax benefit that is greater than 50 percent likely of being realized upon the effective resolution of the tax position.
Effect if Different
Assumptions Used
 
Unrecognized tax benefits involve management’s judgment regarding the likelihood of the benefit being sustained. The final resolution of uncertain tax positions could result in adjustments to recorded amounts and may affect our results of operations, financial position and cash flows.
 
We discuss additional information related to accounting for uncertainty in income taxes in Note 7 of the Notes to Consolidated Financial Statements.


SEMPRA ENERGY, SDG&E AND SOCALGAS (CONTINUED)
DERIVATIVES
Assumptions & Approach Used
 
We value derivative instruments at fair value on the balance sheet. Depending on the purpose for the contract and the applicability of hedge accounting, the impact of instruments may be offset in earnings, on the balance sheet, or in other comprehensive income. We also use normal purchase or sale accounting for certain contracts. As discussed elsewhere in this report, whenever possible, we use exchange quotations or other third-party pricing to estimate fair values; if no such data is available, we use internally developed models and other techniques. The assumed collectability of derivative assets and receivables considers
 
§ events specific to a given counterparty
 
§ the tenor of the transaction
 
§ the credit-worthiness of the counterparty
 
Effect if Different
Assumptions Used
 
The application of hedge accounting to certain derivatives and the normal purchase or sale accounting election is made on a contract-by-contract basis. Using hedge accounting or the normal purchase or sale election in a different manner could materially impact Sempra Energy’s results of operations. However, such alternatives would not have a significant impact on the Sempra Utilities’ results of operations because of regulatory accounting principles. We provide details of our financial instruments in Note 10 of the Notes to Consolidated Financial Statements.
 
DEFINED BENEFIT PLANS
Assumptions & Approach Used
 
To measure our pension and postretirement obligations, costs and liabilities, we rely on several assumptions. We consider current market conditions, including interest rates, in making these assumptions.  We annually review these assumptions prior to the beginning of each year and update when appropriate.
 
The critical assumptions used to develop the required estimates include the following key factors:
 
§ discount rate
 
§ expected return on plan assets
 
§ health-care cost trend rates
 
§ mortality rates
 
§ rate of compensation increases
 
§ payout elections (lump sum or annuity)
 


SEMPRA ENERGY, SDG&E AND SOCALGAS (CONTINUED)
DEFINED BENEFIT PLANS (CONTINUED)
Effect if Different
Assumptions Used
 
The actuarial assumptions we use may differ materially from actual results due to:
 
§ return on plan assets
 
§ changing market and economic conditions
 
§ higher or lower withdrawal rates
 
§ longer or shorter participant life spans
 
§ more or fewer lump sum versus annuity payout elections made by plan participants
 
§ retirement rates
 
 
These differences, other than those related to the Sempra Utilities plans, where rate recovery offsets any effects of the assumptions on earnings, may result in a significant impact to the amount of pension and postretirement benefit expense we record. For the remaining plans, the approximate annual effect on earnings of a 25 basis point increase or decrease in the assumed discount rate would be less than $1 million and the effect of a 25 basis point increase or decrease in the assumed rate of return on plan assets would be less than $1 million.
 
We provide additional information, including the impact of increases and decreases in the health-care cost trend rate, in Note 8 of the Notes to Consolidated Financial Statements.


SEMPRA ENERGY AND SDG&E
ASSET RETIREMENT OBLIGATIONS
Assumptions & Approach Used
 
SDG&E’s legal asset retirement obligations (AROs) related to the decommissioning of SONGS are recorded at fair value based on a site specific study performed every three years. The fair value of the obligations includes
 
§ estimated decommissioning costs, including labor, equipment, material and other disposal costs
 
§ inflation adjustment applied to estimated cash flows
 
§ discount rate based on a credit-adjusted risk-free rate
 
§ expected date of decommissioning
 
Effect if Different
Assumptions Used
 
Changes in the estimated decommissioning costs, or in the assumptions and judgments by management underlying these estimates, could cause revisions to the estimated total cost associated with retiring the assets. Due to regulatory recovery of SDG&E’s nuclear decommissioning expense, rate-making accounting treatment is applied to SDG&E’s nuclear decommissioning activities, so they have no impact on SDG&E’s reported earnings.
 
We provide additional detail in Note 6 of the Notes to the Consolidated Financial Statements.


SEMPRA ENERGY
IMPAIRMENT TESTING OF LONG-LIVED ASSETS
Assumptions & Approach Used
 
Whenever events or changes in circumstances indicate that an asset’s carrying amount may not be recoverable, we consider if the estimated future undiscounted cash flows are less than the carrying amount of the assets.  If so, we estimate the fair value of these assets to determine the extent to which cost exceeds fair value.  For these estimates, we may consider data from multiple valuation methods, including data from market participants. We exercise judgment to estimate the future cash flows and the useful lives of long-lived assets and to determine our intent to use the assets. Our intent to use or dispose of assets is subject to re-evaluation and can change over time.
Effect if Different
Assumptions Used
 
If an impairment test is required, the fair value of long-lived assets can vary if differing estimates and assumptions are used in the valuation techniques applied as indicated by changing market or other conditions. We discuss impairment of long-lived assets in Note 1 of the Notes to Consolidated Financial Statements.
 
IMPAIRMENT TESTING OF GOODWILL
Assumptions & Approach Used
 
On an annual basis or whenever events or changes in circumstances necessitate an evaluation, we consider whether goodwill may be impaired. We exercise judgment to develop estimates of the fair value of the reporting unit and the corresponding goodwill.  Our fair value estimates are developed from the perspective of a knowledgeable market participant. In the absence of observable transactions in the marketplace for similar investments, we consider an income-based approach such as discounted cash flow analysis. A discounted cash flow analysis may be based directly on anticipated future revenues and expenses and may be performed based on free cash flows generated within the reporting unit. Critical assumptions that affect our estimates of fair value may include
 
§ consideration of market transactions
 
§ future cash flows
 
§ the appropriate risk-adjusted discount rate
 
§ country risk
 
§ entity risk
 
Effect if Different
Assumptions Used
 
Testing goodwill for impairment requires an entity to first determine if the carrying value of a reporting unit exceeds its fair value and if so, to measure the amount of goodwill impairment, if any. When determining if goodwill is impaired, the fair value of the reporting unit and goodwill can vary if differing estimates and assumptions are used in the valuation techniques applied as indicated by changing market or other conditions.  As a result, recognizing a goodwill impairment may or may not be required. Sempra Energy added $975 million in goodwill to its Consolidated Balance Sheet in 2011.  We discuss goodwill in Notes 1, 2 and 3 of the Notes to Consolidated Financial Statements.


CARRYING VALUE OF EQUITY METHOD INVESTMENTS
Assumptions & Approach Used
 
We generally account for investments under the equity method when we have an ownership interest of 20 to 50 percent. The premium, or excess cost over the underlying carrying value of net assets, is referred to as equity method goodwill, which is included in the impairment testing of the equity method investment.
 
We consider whether the fair value of each equity investment as a whole, not the underlying net assets, has declined and whether that decline is other than temporary. To help evaluate whether a decline in fair value below cost has occurred and if the decline is other than temporary, we may develop fair value estimates for the investment. Our fair value estimates are developed from the perspective of a knowledgeable market participant. In the absence of observable transactions in the marketplace for similar investments, we consider an income-based approach such as discounted cash flow analysis or, with less weighting, the replacement cost of the underlying net assets. A discounted cash flow analysis may be based directly on anticipated future distributions from the investment, or may be performed based on free cash flows generated within the entity and adjusted for our ownership share total. When calculating estimates of fair or realizable values, we also consider whether we intend to hold or sell the investment. For certain held investments, critical assumptions include
 
§ the appropriate risk-adjusted discount rate
 
§ the availability and costs of natural gas
 
§ competing fuels (primarily propane) and electricity
 
 
For investments that we hold for sale, such as our Argentine investments, or investments that are substantially sold, such as RBS Sempra Commodities, we consider comparable sales values, executed sales transactions or indications of value determined by cash and affiliate receivables within the entity when determining our estimates of fair value.
Effect if Different
Assumptions Used
 
The risk assumptions applied by other market participants to value the investments could vary significantly or the appropriate approaches could be weighted differently. These differences could impact whether or not the fair value of the investment is less than its cost, and if so, whether that condition is other than temporary.  This could result in an impairment charge or a different amount of impairment charge, and, in cases where an impairment charge has been recorded, additional loss or gain upon sale.
 
We provide additional details in Note 4 of the Notes to Consolidated Financial Statements.


 
KEY NONCASH PERFORMANCE INDICATORS
 
A discussion of key noncash performance indicators related to each business unit follows:
 
 
Sempra Utilities
 
Key noncash performance indicators include number of customers, and natural gas volumes and electricity sold. Additional noncash performance indicators include goals related to safety, customer service, customer reputation, environmental considerations, on-time and on-budget completion of major projects and initiatives, and in the case of SDG&E, electric reliability. We discuss natural gas volumes and electricity sold in “Results of Operations – Changes in Revenues, Costs and Earnings” above.
 
 
Sempra Generation
 
Key noncash performance indicators include plant availability factors at the generating plants. For competitive reasons, Sempra Generation does not disclose its plant availability factors. Additional noncash performance indicators include goals related to safety, environmental considerations, and compliance with reliability standards.
 
 
Sempra Pipelines & Storage
 
Key noncash performance indicators for Sempra Pipelines & Storage’s consolidated operations include natural gas sales volume, facility availability, capacity utilization, and for our South American and other distribution operations, customer count and consumption. We discuss these above in “Our Business” and “Factors Influencing Future Performance.” Additional noncash performance indicators include goals related to safety, environmental considerations, and regulatory compliance.
 
 
Sempra LNG
 
Key noncash performance indicators include plant availability and capacity utilization. We discuss these above in “Our Business” and “Factors Influencing Future Performance.” Additional noncash performance indicators include goals related to safety, environmental considerations, regulatory compliance, and on-time and on-budget completion of development projects.
 
 
NEW ACCOUNTING STANDARDS
 
We discuss the relevant pronouncements that have recently become effective and have had or may have a significant effect on our financial statements in Note 2 of the Notes to Consolidated Financial Statements.
 

 
 

INFORMATION REGARDING FORWARD-LOOKING STATEMENTS
 

We make statements in this report that are not historical fact and constitute forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Forward-looking statements are necessarily based upon assumptions with respect to the future, involve risks and uncertainties, and are not guarantees of performance. These forward-looking statements represent our estimates and assumptions only as of the filing date of this report. We assume no obligation to update or revise any forward-looking statement as a result of new information, future events or other factors.
 
In this report, when we use words such as “believes,” “expects,” “anticipates,” “plans,” “estimates,” “projects,” “contemplates,” “intends,” “depends,” “should,” “could,” “would,” “will,” “may,” “potential,” “target,” “goals,” or similar expressions, or when we discuss our guidance, strategy, plans or intentions, we are making forward-looking statements.
 
Factors, among others, that could cause our actual results and future actions to differ materially from those described in forward-looking statements include
 
§  
local, regional, national and international economic, competitive, political, legislative and regulatory conditions and developments;
 
§  
actions by the California Public Utilities Commission, California State Legislature, Federal Energy Regulatory Commission, Nuclear Regulatory Commission, California Energy Commission, California Air Resources Board, and other regulatory, governmental and environmental bodies in the United States and other countries in which we operate;
 
§  
capital markets conditions, including the availability of credit and the liquidity of our investments;
 
§  
inflation, interest and exchange rates;
 
§  
the impact of benchmark interest rates, generally U.S. Treasury bond and Moody’s A-rated utility bond yields, on our Sempra Utilities’ cost of capital;
 
§  
energy markets, including the timing and extent of changes and volatility in commodity prices;
 
§  
the availability of electric power, natural gas and liquefied natural gas, including disruptions caused by failures in the North American transmission grid, pipeline explosions and equipment failures;
 
§  
weather conditions, natural disasters, catastrophic accidents, and conservation efforts;
 
§  
risks inherent in nuclear power generation and radioactive materials storage, including the catastrophic release of such materials;
 
§  
wars, terrorist attacks and cybersecurity threats;
 
§  
business, regulatory, environmental and legal decisions and requirements;
 
§  
expropriation of assets by foreign governments and title and other property disputes;
 
§  
the status of deregulation of retail natural gas and electricity delivery;
 
§  
the timing and success of business development efforts and construction, maintenance and capital projects;
 
§  
the inability or determination not to enter into long-term supply and sales agreements or long-term firm capacity agreements;
 
§  
the resolution of litigation; and
 
§  
other uncertainties, all of which are difficult to predict and many of which are beyond our control.
 
We caution you not to rely unduly on any forward-looking statements. You should review and consider carefully the risks, uncertainties and other factors that affect our business as described in this report and in our Annual Report on Form 10-K and other reports that we file with the Securities and Exchange Commission.
 

 
 

COMMON STOCK DATA
 

 
SEMPRA ENERGY COMMON STOCK
 
Our common stock is traded on the New York Stock Exchange. At February 24, 2012, there were approximately 37,500 record holders of our common stock.
 
The following table shows Sempra Energy quarterly common stock data:
 

 
First
Second
Third
Fourth
 
Quarter
Quarter
Quarter
Quarter
2011 
 
 
 
 
 
 
 
 
Market price
 
 
 
 
 
 
 
 
    High
$
 54.44 
$
 55.97 
$
 53.76 
$
 55.61 
    Low
$
 50.32 
$
 51.53 
$
 44.78 
$
 48.38 
 
 
 
 
 
 
 
 
 
2010 
 
 
 
 
 
 
 
 
Market price
 
 
 
 
 
 
 
 
    High
$
 56.61 
$
 51.43 
$
 54.32 
$
 54.45 
    Low
$
 47.55 
$
 43.91 
$
 46.25 
$
 49.49 
 
We declared dividends of $0.48 and $0.39 per share in each quarter of 2011 and 2010, respectively. On February 24, 2012, our board of directors approved an increase to our quarterly common stock dividend to $0.60 per share ($2.40 annually), an increase of $0.12 per share ($0.48 annually) from $0.48 per share ($1.92 annually) authorized in February 2011.
 
 
SOCALGAS AND SDG&E COMMON STOCK
 
Pacific Enterprises (PE), a wholly owned subsidiary of Sempra Energy, owns all of SoCalGas’ outstanding common stock. Enova Corporation, a wholly owned subsidiary of Sempra Energy, owns all of SDG&E’s issued and outstanding common stock.
 
Information concerning dividend declarations for SoCalGas and SDG&E is included in each of their “Statements of Consolidated Comprehensive Income and Changes in Equity” set forth in the Consolidated Financial Statements.
 
 
DIVIDEND RESTRICTIONS
 
The payment and the amount of future dividends for Sempra Energy, SDG&E, and SoCalGas are within the discretion of their boards of directors. The CPUC’s regulation of the Sempra Utilities’ capital structures limits the amounts that the Sempra Utilities can pay us in the form of loans and dividends. We discuss these matters in Note 1 of the Notes to the Consolidated Financial Statements under “Restricted Net Assets” and in “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Capital Resources and Liquidity” in the “Overview – Sempra Utilities,” “Overview – Sempra Energy Consolidated” and “Dividends” sections.
 

PERFORMANCE GRAPH -- COMPARATIVE TOTAL SHAREHOLDER RETURNS
 

The following graph (Figure 2) compares the percentage change in the cumulative total shareholder return on Sempra Energy common stock for the five-year period ending December 31, 2011, with the performance over the same period of the Standard & Poor’s (S&P) 500 Index and the Standard & Poor’s 500 Utilities Index.
 
These returns were calculated assuming an initial investment of $100 in our common stock, the S&P 500 Index and the S&P 500 Utilities Index on December 31, 2006, and the reinvestment of all dividends.
 




[i002.gif]





Figure 2: Comparison of Cumulative Five-Year Total Return







 

FIVE-YEAR SUMMARIES
 

The following tables present selected financial data of Sempra Energy, SDG&E and SoCalGas for the five years ended December 31, 2011. The data is derived from the audited consolidated financial statements of each company. You should read this information in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the consolidated financial statements and notes contained in this Annual Report.
 
FIVE-YEAR SUMMARY OF SELECTED FINANCIAL DATA FOR SEMPRA ENERGY
(In millions, except for per share amounts)
 
At December 31 or for the years then ended
 
2011 
2010 
2009 
2008 
2007 
Sempra Energy Consolidated
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Revenues
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Utilities:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    Natural gas
$
 4,489 
 
$
 4,491 
 
$
 4,002 
 
$
 5,573 
 
$
 4,968 
 
    Electric
 
 3,833 
 
 
 2,528 
 
 
 2,419 
 
 
 2,553 
 
 
 2,184 
 
Energy-related businesses
 
 1,714 
 
 
 1,984 
 
 
 1,685 
 
 
 2,632 
 
 
 4,286 
 
    Total revenues
$
 10,036 
 
$
 9,003 
 
$
 8,106 
 
$
 10,758 
 
$
 11,438 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Income from continuing operations
$
 1,407 
 
$
 733 
 
$
 1,122 
 
$
 1,068 
 
$
 1,118 
 
(Earnings) losses from continuing operations attributable
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    to noncontrolling interests
 
 (42)
 
 
 16 
 
 
 7 
 
 
 55 
 
 
 17 
 
Preferred dividends of subsidiaries
 
 (8)
 
 
 (10)
 
 
 (10)
 
 
 (10)
 
 
 (10)
 
Income from continuing operations attributable
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    to common shares
$
 1,357 
 
$
 739 
 
$
 1,119 
 
$
 1,113 
 
$
 1,125 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net income
$
 1,407 
 
$
 733 
 
$
 1,122 
 
$
 1,068 
 
$
 1,092 
 
Earnings attributable to common shares
$
 1,357 
 
$
 739 
 
$
 1,119 
 
$
 1,113 
 
$
 1,099 
 
Attributable to common shares:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    Income from continuing operations
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
        Basic
$
 5.66 
 
$
 3.02 
 
$
 4.60 
 
$
 4.50 
 
$
 4.34 
 
        Diluted
$
 5.62 
 
$
 2.98 
 
$
 4.52 
 
$
 4.43 
 
$
 4.26 
 
    Earnings
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
        Basic
$
 5.66 
 
$
 3.02 
 
$
 4.60 
 
$
 4.50 
 
$
 4.24 
 
        Diluted
$
 5.62 
 
$
 2.98 
 
$
 4.52 
 
$
 4.43 
 
$
 4.16 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Dividends declared per common share
$
 1.92 
 
$
 1.56 
 
$
 1.56 
 
$
 1.37 
 
$
 1.24 
 
Return on common equity
 
 14.4 
%
 
 8.2 
%
 
 13.2 
%
 
 13.6 
%
 
 13.9 
%
Effective income tax rate
 
 21 
%
 
 13 
%
 
 29 
%
 
 30 
%
 
 34 
%
Price range of common shares:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    High
$
 55.97 
 
$
 56.61 
 
$
 57.18 
 
$
 63.00 
 
$
 66.38 
 
    Low
$
 44.78 
 
$
 43.91 
 
$
 36.43 
 
$
 34.29 
 
$
 50.95 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Weighted average rate base:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    SoCalGas
$
 2,948 
 
$
 2,860 
 
$
 2,758 
 
$
 2,702 
 
$
 2,642 
 
    SDG&E
$
 5,071 
 
$
 4,697 
 
$
 4,362 
 
$
 4,050 
 
$
 3,846 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
AT DECEMBER 31
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current assets
$
 2,332 
 
$
 3,353 
 
$
 2,295 
 
$
 2,476 
 
$
 9,964 
 
Total assets
$
 33,356 
 
$
 30,283 
 
$
 28,512 
 
$
 26,400 
 
$
 28,717 
 
Current liabilities
$
 4,163 
 
$
 3,786 
 
$
 3,888 
 
$
 3,612 
 
$
 9,020 
 
Long-term debt (excludes current portion)
$
 10,078 
 
$
 8,980 
 
$
 7,460 
 
$
 6,544 
 
$
 4,553 
 
Short-term debt(1)
$
 785 
 
$
 507 
 
$
 1,191 
 
$
 913 
 
$
 1,071 
 
Contingently redeemable preferred stock of subsidiary
$
 79 
 
$
 79 
 
$
 79 
 
$
 79 
 
$
 79 
 
Sempra Energy shareholders’ equity
$
 9,838 
 
$
 9,027 
 
$
 9,007 
 
$
 7,969 
 
$
 8,339 
 
Common shares outstanding
 
 239.9 
 
 
 240.4 
 
 
 246.5 
 
 
 243.3 
 
 
 261.2 
 
Book value per share
$
 41.00 
 
$
 37.54 
 
$
 36.54 
 
$
 32.75 
 
$
 31.93 
 
(1) Includes long-term debt due within one year.

We discuss the impact of natural gas prices on revenues in 2011, 2010 and 2009 and the changes in our effective income tax rate in 2011 and 2010 in “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Changes in Revenues, Costs and Earnings.”
 
On April 6, 2011, we increased our interests in two South American utilities, which are now consolidated. Prior to the acquisition, we accounted for our investments in these entities as equity method investments. On April 30, 2010, we completed an acquisition resulting in the purchase of Mexican pipeline and natural gas infrastructure.  We discuss these acquisitions in Note 3 of the Notes to Consolidated Financial Statements.
 
On April 1, 2008, we sold our commodities-marketing businesses into a joint venture, and began accounting for these businesses under the equity method. In 2010 and early 2011, we and RBS sold substantially all of the businesses and assets of the joint venture. We discuss these transactions further in Notes 3 and 4 of the Notes to Consolidated Financial Statements.
 
We discuss litigation and other contingencies in Note 15 of the Notes to Consolidated Financial Statements.
 
Net Income and Earnings Attributable to Common Shares in 2007 included $26 million in after-tax loss from discontinued operations, primarily due to asset sales.
 

FIVE-YEAR SUMMARIES OF SELECTED FINANCIAL DATA FOR SDG&E AND SOCALGAS
(Dollars in millions)
 
At December 31 or for the years then ended
 
2011 
2010 
2009 
2008 
2007 
SDG&E
 
 
 
 
 
 
 
 
 
 
Statement of Operations Data:
 
 
 
 
 
 
 
 
 
 
    Operating revenues
$
 3,373 
$
 3,049 
$
 2,916 
$
 3,251 
$
 2,852 
    Operating income
 
 755 
 
 657 
 
 589 
 
 570 
 
 500 
    Dividends on preferred stock
 
 5 
 
 5 
 
 5 
 
 5 
 
 5 
    Earnings attributable to common shares
 
 431 
 
 369 
 
 344 
 
 339 
 
 283 
 
 
 
 
 
 
 
 
 
 
 
Balance Sheet Data:
 
 
 
 
 
 
 
 
 
 
    Total assets
$
 13,555 
$
 12,077 
$
 10,229 
$
 9,079 
$
 8,499 
    Long-term debt (excludes current portion)
 
 4,058 
 
 3,479 
 
 2,623 
 
 2,142 
 
 1,958 
    Short-term debt(1)
 
 19 
 
 19 
 
 78 
 
 2 
 
 ― 
    Preferred stock subject to mandatory redemption
 
 ― 
 
 ― 
 
 ― 
 
 ― 
 
 14 
    Contingently redeemable preferred stock
 
 79 
 
 79 
 
 79 
 
 79 
 
 79 
    SDG&E shareholders’ equity
 
 3,739 
 
 3,108 
 
 2,739 
 
 2,542 
 
 2,200 
SoCalGas
 
 
 
 
 
 
 
 
 
 
Statement of Operations Data:
 
 
 
 
 
 
 
 
 
 
    Operating revenues
$
 3,816 
$
 3,822 
$
 3,355 
$
 4,768 
$
 4,282 
    Operating income
 
 486 
 
 516 
 
 476 
 
 434 
 
 437 
    Dividends on preferred stock
 
 1 
 
 1 
 
 1 
 
 1 
 
 1 
    Earnings attributable to common shares
 
 287 
 
 286 
 
 273 
 
 244 
 
 230 
 
 
 
 
 
 
 
 
 
 
 
Balance Sheet Data:
 
 
 
 
 
 
 
 
 
 
    Total assets
$
 8,475 
$
 7,986 
$
 7,287 
$
 7,351 
$
 6,406 
    Long-term debt (excludes current portion)
 
 1,064 
 
 1,320 
 
 1,283 
 
 1,270 
 
 1,113 
    Short-term debt(1)
 
 257 
 
 262 
 
 11 
 
 100 
 
 ― 
    SoCalGas shareholders’ equity
 
 2,193 
 
 1,955 
 
 1,766 
 
 1,490 
 
 1,470 
(1) Includes long-term debt due within one year.

We discuss the impact of natural gas prices on revenues in 2011, 2010 and 2009 in “Management’s Discussion and Analysis of Financial Condition and Results of Operations Changes in Revenues, Costs and Earnings.” We do not provide per-share data for SDG&E and SoCalGas because the common stock of each of them is indirectly wholly owned by Sempra Energy.
 
We discuss litigation and other contingencies in Note 15 of the Notes to Consolidated Financial Statements.

 
 
CONTROLS AND PROCEDURES
 
 

EVALUATION OF DISCLOSURE CONTROLS AND PROCEDURES
 

 
SEMPRA ENERGY, SDG&E, SOCALGAS
 
Sempra Energy, SDG&E and SoCalGas have designed and maintain disclosure controls and procedures to ensure that information required to be disclosed in their respective reports is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the Securities and Exchange Commission and is accumulated and communicated to the management of each company, including each respective Chief Executive Officer and Chief Financial Officer, to allow timely decisions regarding required disclosure. In designing and evaluating these controls and procedures, the management of each company recognizes that any system of controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives; therefore, the management of each company applies judgment in evaluating the cost-benefit relationship of other possible controls and procedures.
 
Under the supervision and with the participation of management, including the Chief Executive Officers and Chief Financial Officers of Sempra Energy, SDG&E and SoCalGas, each company evaluated the effectiveness of the design and operation of its disclosure controls and procedures as of December 31, 2011, the end of the period covered by this report. Based on these evaluations, the Chief Executive Officers and Chief Financial Officers of Sempra Energy, SDG&E and SoCalGas concluded that their respective company’s disclosure controls and procedures were effective at the reasonable assurance level.
 

 

MANAGEMENT’S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING
 

 
SEMPRA ENERGY, SDG&E, SOCALGAS
 
The respective management of each company is responsible for establishing and maintaining adequate internal control over financial reporting, as defined in Exchange Act Rules 13a-15(f). Under the supervision and with the participation of the management of each company, including each company’s principal executive officer and principal financial officer, the effectiveness of each company’s internal control over financial reporting was evaluated based on the framework in Internal Control Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on the evaluations, each company concluded that its internal control over financial reporting was effective as of December 31, 2011. Deloitte & Touche, LLP audited the effectiveness of each company’s internal control over financial reporting as of December 31, 2011, as stated in their reports, which are included in this Annual Report.
 
There have been no changes in the companies’ internal control over financial reporting during the most recent fiscal quarter that have materially affected, or are reasonably likely to materially affect, the companies’ internal control over financial reporting.
 
 
CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
 
Not applicable.
 



REPORTS OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
 

 

SEMPRA ENERGY
 

 
To the Board of Directors and Shareholders of Sempra Energy:
 
We have audited the internal control over financial reporting of Sempra Energy and subsidiaries (the “Company”) as of December 31, 2011, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.  The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control over Financial Reporting.  Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.
 
We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States).  Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects.  Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances.  We believe that our audit provides a reasonable basis for our opinion.
 
A company’s internal control over financial reporting is a process designed by, or under the supervision of, the company’s principal executive and principal financial officers, or persons performing similar functions, and effected by the company’s board of directors, management, and other personnel to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles.  A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
 
Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis.  Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
 
In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.
 
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements as of and for the year ended December 31, 2011 of the Company and our report dated February 28, 2012 expressed an unqualified opinion on those financial statements.
 

/S/ DELOITTE & TOUCHE LLP

San Diego, California
February 28, 2012


 
 
 
 

 
To the Board of Directors and Shareholders of Sempra Energy:
 
We have audited the accompanying consolidated balance sheets of Sempra Energy and subsidiaries (the “Company”) as of December 31, 2011 and 2010, and the related consolidated statements of operations, comprehensive income and changes in equity, and cash flows for each of the three years in the period ended December 31, 2011.  These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.
 
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States).  Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement.  An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements.  An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation.  We believe that our audits provide a reasonable basis for our opinion.
 
In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of Sempra Energy and subsidiaries as of December 31, 2011 and 2010, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2011, in conformity with accounting principles generally accepted in the United States of America.
 
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 28, 2012 expressed an unqualified opinion on the Company’s internal control over financial reporting.
 

/S/ DELOITTE & TOUCHE LLP

San Diego, California
February 28, 2012

 
 
 
 



 

SAN DIEGO GAS & ELECTRIC COMPANY
 

 
To the Board of Directors and Shareholders of San Diego Gas & Electric Company:
 
We have audited the internal control over financial reporting of San Diego Gas & Electric Company (the “Company”) as of December 31, 2011, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.  The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control over Financial Reporting.  Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.
 
We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States).  Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects.  Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances.  We believe that our audit provides a reasonable basis for our opinion.
 
A company’s internal control over financial reporting is a process designed by, or under the supervision of, the company’s principal executive and principal financial officers, or persons performing similar functions, and effected by the company’s board of directors, management, and other personnel to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles.  A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
 
Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis.  Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
 
In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.
 
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements as of and for the year ended December 31, 2011 of the Company and our report dated February 28, 2012 expressed an unqualified opinion on those financial statements.
 

/S/ DELOITTE & TOUCHE LLP

San Diego, California
February 28, 2012



 
 
 
 

 
To the Board of Directors and Shareholders of San Diego Gas & Electric Company:
 
We have audited the accompanying consolidated balance sheets of San Diego Gas & Electric Company (the “Company”) as of December 31, 2011 and 2010, and the related consolidated statements of operations, comprehensive income and changes in equity, and cash flows for each of the three years in the period ended December 31, 2011.  These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.
 
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States).  Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement.  An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements.  An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation.  We believe that our audits provide a reasonable basis for our opinion.
 
In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of San Diego Gas & Electric Company as of December 31, 2011 and 2010, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2011, in conformity with accounting principles generally accepted in the United States of America.
 
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 28, 2012 expressed an unqualified opinion on the Company’s internal control over financial reporting.
 

/S/ DELOITTE & TOUCHE LLP

San Diego, California
February 28, 2012

 
 
 
 



 

SOUTHERN CALIFORNIA GAS COMPANY
 

 
To the Board of Directors and Shareholders of Southern California Gas Company:
 
We have audited the internal control over financial reporting of Southern California Gas Company and subsidiaries (the “Company”) as of December 31, 2011, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.  The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control over Financial Reporting.  Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.
 
We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States).  Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects.  Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances.  We believe that our audit provides a reasonable basis for our opinion.
 
A company’s internal control over financial reporting is a process designed by, or under the supervision of, the company’s principal executive and principal financial officers, or persons performing similar functions, and effected by the company’s board of directors, management, and other personnel to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles.  A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
 
Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis.  Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
 
In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.
 
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements as of and for the year ended December 31, 2011 of the Company and our report dated February 28, 2012 expressed an unqualified opinion on those financial statements.
 

/S/ DELOITTE & TOUCHE LLP

San Diego, California
February 28, 2012


 
 
 
 

 
To the Board of Directors and Shareholders of Southern California Gas Company:
 
We have audited the accompanying consolidated balance sheets of Southern California Gas Company and subsidiaries (the “Company”) as of December 31, 2011 and 2010, and the related consolidated statements of operations, comprehensive income and changes in shareholders’ equity, and cash flows for each of the three years in the period ended December 31, 2011.  These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.
 
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States).  Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement.  An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements.  An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation.  We believe that our audits provide a reasonable basis for our opinion.
 
In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of Southern California Gas Company and subsidiaries as of December 31, 2011 and 2010, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2011, in conformity with accounting principles generally accepted in the United States of America.
 
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 28, 2012 expressed an unqualified opinion on the Company’s internal control over financial reporting.
 

/S/ DELOITTE & TOUCHE LLP

San Diego, California
February 28, 2012

 
 
 
 

SEMPRA ENERGY
CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions, except per share amounts)
 
Years ended December 31,
 
2011 
2010
2009
 
 
REVENUES
 
 
 
 
 
 
Utilities
$
 8,322 
$
 7,019 
$
 6,421 
Energy-related businesses
 
 1,714 
 
 1,984 
 
 1,685 
    Total revenues
 
 10,036 
 
 9,003 
 
 8,106 
EXPENSES AND OTHER INCOME
 
 
 
 
 
 
Utilities:
 
 
 
 
 
 
    Cost of natural gas
 
 (1,866)
 
 (2,012)
 
 (1,645)
    Cost of electric fuel and purchased power
 
 (1,397)
 
 (637)
 
 (672)
Energy-related businesses:
 
 
 
 
 
 
    Cost of natural gas, electric fuel and purchased power
 
 (746)
 
 (1,046)
 
 (864)
    Other cost of sales
 
 (137)
 
 (88)
 
 (77)
Litigation expense
 
 (37)
 
 (169)
 
 (4)
Other operation and maintenance
 
 (2,788)
 
 (2,499)
 
 (2,467)
Depreciation and amortization
 
 (978)
 
 (867)
 
 (775)
Franchise fees and other taxes
 
 (343)
 
 (327)
 
 (296)
Write-off of long-lived assets
 
 ― 
 
 ― 
 
 (132)
Equity earnings (losses), before income tax:
 
 
 
 
 
 
    RBS Sempra Commodities LLP
 
 (24)
 
 (314)
 
 463 
    Other
 
 33 
 
 22 
 
 36 
Remeasurement of equity method investments
 
 277 
 
 ― 
 
 ― 
Other income, net
 
 130 
 
 140 
 
 149 
Interest income
 
 26 
 
 16 
 
 21 
Interest expense
 
 (465)
 
 (436)
 
 (367)
Income before income taxes and equity earnings
 
 
 
 
 
 
    of certain unconsolidated subsidiaries
 
 1,721 
 
 786 
 
 1,476 
Income tax expense
 
 (366)
 
 (102)
 
 (422)
Equity earnings, net of income tax
 
 52 
 
 49 
 
 68 
Net income
 
 1,407 
 
 733 
 
 1,122 
(Earnings) losses attributable to noncontrolling interests
 
 (42)
 
 16 
 
 7 
Preferred dividends of subsidiaries
 
 (8)
 
 (10)
 
 (10)
Earnings
$
 1,357 
$
 739 
$
 1,119 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Basic earnings per common share
$
 5.66 
$
 3.02 
$
 4.60 
Weighted-average number of shares outstanding, basic (thousands)
 
 239,720 
 
 244,736 
 
 243,339 
 
 
 
 
 
 
 
Diluted earnings per common share
$
 5.62 
$
 2.98 
$
 4.52 
Weighted-average number of shares outstanding, diluted (thousands)
 
 241,523 
 
 247,942 
 
 247,384 
 
 
 
 
 
 
 
Dividends declared per share of common stock
$
 1.92 
$
 1.56 
$
 1.56 
See Notes to Consolidated Financial Statements.



SEMPRA ENERGY
CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
 
December 31,
December 31,
 
2011 
2010 
ASSETS
 
 
 
 
Current assets:
 
 
 
 
    Cash and cash equivalents
$
 252 
$
 912 
    Restricted cash
 
 24 
 
 131 
    Trade accounts receivable, net
 
 1,198 
 
 891 
    Other accounts and notes receivable, net
 
 147 
 
 141 
    Due from unconsolidated affiliates
 
 ― 
 
 34 
    Income taxes receivable
 
 ― 
 
 248 
    Deferred income taxes
 
 ― 
 
 75 
    Inventories
 
 346 
 
 258 
    Regulatory balancing accounts – undercollected
 
 38 
 
 ― 
    Regulatory assets
 
 89 
 
 90 
    Fixed-price contracts and other derivatives
 
 85 
 
 81 
    Settlements receivable related to wildfire litigation
 
 10 
 
 300 
    Other
 
 143 
 
 192 
        Total current assets
 
 2,332 
 
 3,353 
 
 
 
 
 
Investments and other assets:
 
 
 
 
    Restricted cash
 
 22 
 
 27 
    Regulatory assets arising from pension and other postretirement
 
 
 
 
        benefit obligations
 
 1,126 
 
 869 
    Regulatory assets arising from wildfire litigation costs
 
 594 
 
 364 
    Other regulatory assets
 
 1,060 
 
 934 
    Nuclear decommissioning trusts
 
 804 
 
 769 
    Investment in RBS Sempra Commodities LLP
 
 126 
 
 787 
    Other investments
 
 1,545 
 
 2,164 
    Goodwill
 
 1,036 
 
 87 
    Other intangible assets
 
 448 
 
 453 
    Sundry
 
 691 
 
 600 
        Total investments and other assets
 
 7,452 
 
 7,054 
 
 
 
 
 
Property, plant and equipment:
 
 
 
 
    Property, plant and equipment
 
 31,303 
 
 27,087 
    Less accumulated depreciation and amortization
 
 (7,731)
 
 (7,211)
        Property, plant and equipment, net ($494 and $516 at December 31, 2011 and
 
 
 
 
            2010, respectively, related to VIE)
 
 23,572 
 
 19,876 
Total assets
$
 33,356 
$
 30,283 
See Notes to Consolidated Financial Statements.



SEMPRA ENERGY
CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
 
December 31,
December 31,
 
2011 
2010
LIABILITIES AND EQUITY
 
 
 
 
Current liabilities:
 
 
 
 
    Short-term debt
$
 449 
$
 158 
    Accounts payable – trade
 
 983 
 
 755 
    Accounts payable – other
 
 124 
 
 109 
    Due to unconsolidated affiliates
 
 ― 
 
 36 
    Income taxes payable
 
 16 
 
 ― 
    Deferred income taxes
 
 173 
 
 ― 
    Dividends and interest payable
 
 219 
 
 188 
    Accrued compensation and benefits
 
 323 
 
 311 
    Regulatory balancing accounts – overcollected
 
 105 
 
 241 
    Current portion of long-term debt
 
 336 
 
 349 
    Fixed-price contracts and other derivatives
 
 92 
 
 106 
    Customer deposits
 
 142 
 
 129 
    Reserve for wildfire litigation
 
 586 
 
 639 
    Other
 
 615 
 
 765 
        Total current liabilities
 
 4,163 
 
 3,786 
Long-term debt ($345 and $355 at December 31, 2011 and 2010, respectively,
 
 
 
 
      related to VIE)
 
 10,078 
 
 8,980 
 
 
 
 
 
Deferred credits and other liabilities:
 
 
 
 
    Customer advances for construction
 
 142 
 
 154 
    Pension and other postretirement benefit obligations, net of plan assets
 
 1,423 
 
 1,105 
    Deferred income taxes
 
 1,554 
 
 1,561 
    Deferred investment tax credits
 
 49 
 
 50 
    Regulatory liabilities arising from removal obligations
 
 2,551 
 
 2,630 
    Asset retirement obligations
 
 1,905 
 
 1,449 
    Other regulatory liabilities
 
 87 
 
 138 
    Fixed-price contracts and other derivatives
 
 301 
 
 290 
    Deferred credits and other
 
 783 
 
 823 
        Total deferred credits and other liabilities
 
 8,795 
 
 8,200 
Contingently redeemable preferred stock of subsidiary
 
 79 
 
 79 
 
 
 
 
 
Commitments and contingencies (Note 15)
 
 
 
 
 
 
 
 
 
Equity:
 
 
 
 
    Preferred stock (50 million shares authorized; none issued)
 
 ― 
 
 ― 
    Common stock (750 million shares authorized; 240 million
 
 
 
 
        shares outstanding at December 31, 2011 and 2010; no par value)
 
 2,104 
 
 2,036 
    Retained earnings
 
 8,225 
 
 7,329 
    Deferred compensation
 
 (2)
 
 (8)
    Accumulated other comprehensive income (loss)
 
 (489)
 
 (330)
        Total Sempra Energy shareholders’ equity
 
 9,838 
 
 9,027 
    Preferred stock of subsidiaries
 
 20 
 
 100 
    Other noncontrolling interests
 
 383 
 
 111 
        Total equity
 
 10,241 
 
 9,238 
Total liabilities and equity
$
 33,356 
$
 30,283 
See Notes to Consolidated Financial Statements.
 
 
 
 
 


SEMPRA ENERGY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in millions)
 
Years ended December 31,
 
2011 
2010 
2009 
CASH FLOWS FROM OPERATING ACTIVITIES
 
 
 
 
 
 
    Net income
$
 1,407 
$
 733 
$
 1,122 
    Adjustments to reconcile net income to net cash provided
 
 
 
 
 
 
        by operating activities:
 
 
 
 
 
 
            Depreciation and amortization
 
 978 
 
 867 
 
 775 
            Deferred income taxes and investment tax credits
 
 (24)
 
 48 
 
 295 
            Equity (earnings) losses
 
 (61)
 
 243 
 
 (567)
            Remeasurement of equity method investments
 
 (277)
 
 ― 
 
 ― 
            Write-off of long-lived assets
 
 ― 
 
 ― 
 
 132 
            Fixed-price contracts and other derivatives
 
 2 
 
 13 
 
 (30)
            Other
 
 (15)
 
 (55)
 
 (48)
    Net change in other working capital components
 
 (225)
 
 58 
 
 (256)
    Distributions from RBS Sempra Commodities LLP
 
 53 
 
 198 
 
 407 
    Changes in other assets
 
 34 
 
 54 
 
 139 
    Changes in other liabilities
 
 (5)
 
 (5)
 
 (94)
        Net cash provided by operating activities
 
 1,867 
 
 2,154 
 
 1,875 
 
 
 
 
 
 
 
CASH FLOWS FROM INVESTING ACTIVITIES
 
 
 
 
 
 
    Expenditures for property, plant and equipment
 
 (2,844)
 
 (2,062)
 
 (1,912)
    Proceeds from sale of assets
 
 2 
 
 303 
 
 179 
    Expenditures for investments and acquisition of businesses,
 
 
 
 
 
 
        net of cash acquired
 
 (941)
 
 (611)
 
 (939)
    Distributions from RBS Sempra Commodities LLP
 
 570 
 
 849 
 
 ― 
    Distributions from other investments
 
 64 
 
 371 
 
 23 
    Purchases of nuclear decommissioning and other trust assets
 
 (755)
 
 (371)
 
 (267)
    Proceeds from sales by nuclear decommissioning and other trusts
 
 753 
 
 372 
 
 230 
    Decrease in restricted cash
 
 653 
 
 195 
 
 37 
    Increase in restricted cash
 
 (541)
 
 (318)
 
 (45)
    Decrease in notes receivable from unconsolidated affiliate
 
 ― 
 
 ― 
 
 100 
    Purchase of bonds issued by unconsolidated affiliate
 
 ― 
 
 ― 
 
 (50)
    Other
 
 (31)
 
 (11)
 
 (28)
        Net cash used in investing activities
 
 (3,070)
 
 (1,283)
 
 (2,672)
 
 
 
 
 
 
 
CASH FLOWS FROM FINANCING ACTIVITIES
 
 
 
 
 
 
    Common dividends paid
 
 (440)
 
 (364)
 
 (341)
    Redemption of subsidiary preferred stock
 
 (80)
 
 ― 
 
 ― 
    Preferred dividends paid by subsidiaries
 
 (8)
 
 (10)
 
 (10)
    Issuances of common stock
 
 28 
 
 40 
 
 73 
    Repurchases of common stock
 
 (18)
 
 (502)
 
 (22)
    Issuances of debt (maturities greater than 90 days)
 
 2,098 
 
 1,125 
 
 2,151 
    Payments on debt (maturities greater than 90 days)
 
 (482)
 
 (905)
 
 (435)
    (Decrease) increase in short-term debt, net
 
 (498)
 
 568 
 
 (659)
    Payments on notes payable to unconsolidated affiliate
 
 ― 
 
 ― 
 
 (100)
    Purchase of noncontrolling interests
 
 (43)
 
 ― 
 
 (94)
    Other
 
 (23)
 
 (21)
 
 13 
        Net cash provided by (used in) financing activities
 
 534 
 
 (69)
 
 576 
 
 
 
 
 
 
 
Effect of exchange rate changes on cash and cash equivalents
 
 9 
 
 ― 
 
 ― 
 
 
 
 
 
 
 
(Decrease) increase in cash and cash equivalents
 
 (660)
 
 802 
 
 (221)
Cash and cash equivalents, January 1
 
 912 
 
 110 
 
 331 
Cash and cash equivalents, December 31
$
 252 
$
 912 
$
 110 
See Notes to Consolidated Financial Statements.


SEMPRA ENERGY
CONSOLIDATED STATEMENTS OF CASH FLOWS (CONTINUED)
(Dollars in millions)
 
Years ended December 31,
 
2011 
2010 
2009 
CHANGES IN OTHER WORKING CAPITAL COMPONENTS
 
 
 
 
 
 
(Excluding cash and cash equivalents, and debt due within one year)
 
 
 
 
 
 
    Accounts and notes receivable
$
 (32)
$
 89 
$
 (190)
    Income taxes, net
 
 268 
 
 (30)
 
 (17)
    Inventories
 
 (84)
 
 (62)
 
 124 
    Regulatory balancing accounts
 
 (150)
 
 (155)
 
 42 
    Regulatory assets and liabilities
 
 (2)
 
 6 
 
 (1)
    Other current assets
 
 295 
 
 310 
 
 685 
    Accounts and notes payable
 
 60 
 
 79 
 
 (109)
    Other current liabilities
 
 (580)
 
 (179)
 
 (790)
        Net change in other working capital components
$
 (225)
$
 58 
$
 (256)
 
 
 
 
 
 
 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
 
 
 
 
 
 
    Interest payments, net of amounts capitalized
$
 440 
$
 415 
$
 326 
    Income tax payments, net of refunds
 
 144 
 
 68 
 
 112 
 
 
 
 
 
 
 
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING ACTIVITIES
 
 
 
 
 
 
    Acquisition of businesses:
 
 
 
 
 
 
        Assets acquired
$
 2,833 
$
 303 
$
 ― 
        Cash paid, net of cash acquired
 
 (611)
 
 (292)
 
 ― 
        Fair value of equity method investments immediately prior to the acquisition
 
 (882)
 
 ― 
 
 ― 
        Fair value of noncontrolling interests
 
 (279)
 
 ― 
 
 ― 
        Additional consideration accrued
 
 (32)
 
 ― 
 
 ― 
        Liabilities assumed
$
 1,029 
$
 11 
$
 ― 
 
 
 
 
 
 
 
    Increase in capital lease obligations for investments in property, plant and equipment
$
 ― 
$
 192 
$
 50 
    Accrued capital expenditures
 
 368 
 
 341 
 
 247 
    Return of investment (industrial development bonds)
 
 180 
 
 ― 
 
 ― 
 
 
 
 
 
 
 
SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES
 
 
 
 
 
 
    Dividends declared but not paid
$
 120 
$
 96 
$
 99 
    Cancellation of debt (industrial development bonds)
 
 180 
 
 ― 
 
 ― 
    Conversion of debt into equity
 
 30 
 
 ― 
 
 ― 
See Notes to Consolidated Financial Statements.



SEMPRA ENERGY
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME AND CHANGES IN EQUITY
(Dollars in millions)
 
Years ended December 31, 2011, 2010 and 2009
 
 
 
 
 
Deferred
 
 
 
 
 
 
 
 
 
Compen-
Accumulated
 
 
 
 
 
 
 
 
sation
Other
Sempra
 
 
 
 
 
 
 
Relating
Compre-
Energy
Non-
 
 
Common
Retained
to
hensive
Shareholders’
controlling
Total
 
Stock
Earnings
ESOP
Income (Loss)
Equity
Interests
Equity
Balance at December 31, 2008
$
 2,265 
$
 6,235 
$
 (18)
$
 (513)
$
 7,969 
$
 340 
$
 8,309 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net income (loss)
 
 
 
 1,129 
 
 
 
 
 
 1,129 
 
 (7)
 
 1,122 
Comprehensive income adjustments:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    Foreign currency translation adjustments
 
 
 
 
 
 
 
 102 
 
 102 
 
 
 
 102 
    Available-for-sale securities
 
 
 
 
 
 
 
 7 
 
 7 
 
 
 
 7 
    Pension and other postretirement benefits
 
 
 
 
 
 
 
 (3)
 
 (3)
 
 
 
 (3)
    Financial instruments
 
 
 
 
 
 
 
 38 
 
 38 
 
 (3)
 
 35 
Comprehensive income (loss)
 
 
 
 
 
 
 
 144 
 
 1,273 
 
 (10)
 
 1,263 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Share-based compensation expense
 
 38 
 
 
 
 
 
 
 
 38 
 
 
 
 38 
Common stock dividends declared
 
 
 
 (383)
 
 
 
 
 
 (383)
 
 
 
 (383)
Preferred dividends of subsidiaries
 
 
 
 (10)
 
 
 
 
 
 (10)
 
 
 
 (10)
Issuance of common stock
 
 114 
 
 
 
 
 
 
 
 114 
 
 
 
 114 
Tax benefit related to share-based
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    compensation
 
 23 
 
 
 
 
 
 
 
 23 
 
 
 
 23 
Repurchases of common stock
 
 (22)
 
 
 
 
 
 
 
 (22)
 
 
 
 (22)
Common stock released from ESOP
 
 10 
 
 
 
 5 
 
 
 
 15 
 
 
 
 15 
Equity contributed by noncontrolling interests
 
 
 
 
 
 
 
 
 
 
 
 7 
 
 7 
Distributions to noncontrolling interests
 
 
 
 
 
 
 
 
 
 
 
 (9)
 
 (9)
Purchase of noncontrolling interest in
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    subsidiary
 
 (10)
 
 
 
 
 
 
 
 (10)
 
 (84)
 
 (94)
Balance at December 31, 2009
 
 2,418 
 
 6,971 
 
 (13)
 
 (369)
 
 9,007 
 
 244 
 
 9,251 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net income (loss)
 
 
 
 749 
 
 
 
 
 
 749 
 
 (16)
 
 733 
Comprehensive income adjustments:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    Foreign currency translation adjustments
 
 
 
 
 
 
 
 47 
 
 47 
 
 
 
 47 
    Available-for-sale securities
 
 
 
 
 
 
 
 (8)
 
 (8)
 
 
 
 (8)
    Pension and other postretirement benefits
 
 
 
 
 
 
 
 13 
 
 13 
 
 
 
 13 
    Financial instruments
 
 
 
 
 
 
 
 (13)
 
 (13)
 
 7 
 
 (6)
Comprehensive income (loss)
 
 
 
 
 
 
 
 39 
 
 788 
 
 (9)
 
 779 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Share-based compensation expense
 
 38 
 
 
 
 
 
 
 
 38 
 
 
 
 38 
Common stock dividends declared
 
 
 
 (381)
 
 
 
 
 
 (381)
 
 
 
 (381)
Preferred dividends of subsidiaries
 
 
 
 (10)
 
 
 
 
 
 (10)
 
 
 
 (10)
Issuance of common stock
 
 64 
 
 
 
 
 
 
 
 64 
 
 
 
 64 
Tax benefit related to share-based
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    compensation
 
 5 
 
 
 
 
 
 
 
 5 
 
 
 
 5 
Repurchases of common stock
 
 (502)
 
 
 
 
 
 
 
 (502)
 
 
 
 (502)
Common stock released from ESOP
 
 13 
 
 
 
 5 
 
 
 
 18 
 
 
 
 18 
Distributions to noncontrolling interests
 
 
 
 
 
 
 
 
 
 
 
 (24)
 
 (24)
Balance at December 31, 2010
$
 2,036 
$
 7,329 
$
 (8)
$
 (330)
$
 9,027 
$
 211 
$
 9,238 
See Notes to Consolidated Financial Statements.



SEMPRA ENERGY
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME AND CHANGES IN EQUITY (CONTINUED)
(Dollars in millions)
 
Years ended December 31, 2011, 2010 and 2009
 
 
 
 
 
Deferred
 
 
 
 
 
 
 
 
 
 
Compen-
Accumulated
 
 
 
 
 
 
 
 
sation
Other
Sempra
 
 
 
 
 
 
 
Relating
Compre-
Energy
Non-
 
 
Common
Retained
to
hensive
Shareholders’
controlling
Total
 
Stock
Earnings
ESOP
Income (Loss)
Equity
Interests
Equity
Balance at December 31, 2010
$
 2,036 
$
 7,329 
$
 (8)
$
 (330)
$
 9,027 
$
 211 
$
 9,238 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net income
 
 
 
 1,365 
 
 
 
 
 
 1,365 
 
 42 
 
 1,407 
Comprehensive income adjustments:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    Foreign currency translation adjustments
 
 
 
 
 
 
 
 (76)
 
 (76)
 
 6 
 
 (70)
    Reclassification to net income of foreign
 
 
 
 
 
 
 
 
 
 
 
 
 
 
        currency translation adjustment related
 
 
 
 
 
 
 
 
 
 
 
 
 
 
        to remeasurement of equity method
 
 
 
 
 
 
 
 
 
 
 
 
 
 
        investments
 
 
 
 
 
 
 
 (54)
 
 (54)
 
 
 
 (54)
    Available-for-sale securities
 
 
 
 
 
 
 
 (1)
 
 (1)
 
 
 
 (1)
    Pension and other postretirement benefits
 
 
 
 
 
 
 
 (12)
 
 (12)
 
 
 
 (12)
    Financial instruments
 
 
 
 
 
 
 
 (16)
 
 (16)
 
 (36)
 
 (52)
Comprehensive income (loss)
 
 
 
 
 
 
 
 (159)
 
 1,206 
 
 12 
 
 1,218 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Share-based compensation expense
 
 48 
 
 
 
 
 
 
 
 48 
 
 
 
 48 
Common stock dividends declared
 
 
 
 (461)
 
 
 
 
 
 (461)
 
 
 
 (461)
Preferred dividends of subsidiaries
 
 
 
 (8)
 
 
 
 
 
 (8)
 
 
 
 (8)
Issuance of common stock
 
 28 
 
 
 
 
 
 
 
 28 
 
 
 
 28 
Repurchases of common stock
 
 (18)
 
 
 
 
 
 
 
 (18)
 
 
 
 (18)
Common stock released from ESOP
 
 14 
 
 
 
 6 
 
 
 
 20 
 
 
 
 20 
Distributions to noncontrolling interests
 
 
 
 
 
 
 
 
 
 
 
 (16)
 
 (16)
Equity contributed by noncontrolling interests
 
 
 
 
 
 
 
 
 
 
 
 36 
 
 36 
Acquisition of South American entities
 
 
 
 
 
 
 
 
 
 
 
 279 
 
 279 
Purchase of noncontrolling interests in
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    subsidiary
 
 (4)
 
 
 
 
 
 
 
 (4)
 
 (39)
 
 (43)
Redemption of preferred stock of subsidiary
 
 
 
 
 
 
 
 
 
 
 
 (80)
 
 (80)
Balance at December 31, 2011
$
 2,104 
$
 8,225 
$
 (2)
$
 (489)
$
 9,838 
$
 403 
$
 10,241 
See Notes to Consolidated Financial Statements.


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



SAN DIEGO GAS & ELECTRIC COMPANY
CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
 
December 31,
December 31,
 
2011 
2010 
ASSETS
 
 
 
 
Current assets:
 
 
 
 
    Cash and cash equivalents
$
 29 
$
 127 
    Restricted cash
 
 21 
 
 116 
    Accounts receivable – trade, net
 
 267 
 
 248 
    Accounts receivable – other, net
 
 23 
 
 59 
    Due from unconsolidated affiliates
 
 67 
 
 12 
    Income taxes receivable
 
 102 
 
 37 
    Deferred income taxes
 
 ― 
 
 129 
    Inventories
 
 82 
 
 71 
    Regulatory balancing accounts, net
 
 38 
 
 ― 
    Regulatory assets arising from fixed-price contracts and other derivatives
 
 67 
 
 66 
    Other regulatory assets
 
 11 
 
 5 
    Fixed-price contracts and other derivatives
 
 27 
 
 28 
    Settlements receivable related to wildfire litigation
 
 10 
 
 300 
    Other
 
 51 
 
 50 
        Total current assets
 
 795 
 
 1,248 
 
 
 
 
 
Other assets:
 
 
 
 
    Restricted cash
 
 22 
 
 ― 
    Deferred taxes recoverable in rates
 
 570 
 
 502 
    Regulatory assets arising from fixed-price contracts and other derivatives
 
 191 
 
 233 
    Regulatory assets arising from pension and other postretirement
 
 
 
 
        benefit obligations
 
 309 
 
 279 
    Regulatory assets arising from wildfire litigation costs
 
 594 
 
 364 
    Other regulatory assets
 
 160 
 
 73 
    Nuclear decommissioning trusts
 
 804 
 
 769 
    Sundry
 
 70 
 
 56 
        Total other assets
 
 2,720 
 
 2,276 
 
 
 
 
 
Property, plant and equipment:
 
 
 
 
    Property, plant and equipment
 
 13,003 
 
 11,247 
    Less accumulated depreciation and amortization
 
 (2,963)
 
 (2,694)
        Property, plant and equipment, net ($494 and $516 at December 31, 2011
 
 
 
 
              and 2010, respectively, related to VIE)
 
 10,040 
 
 8,553 
Total assets
$
 13,555 
$
 12,077 
See Notes to Consolidated Financial Statements.



SAN DIEGO GAS & ELECTRIC COMPANY
CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
 
December 31,
December 31,
 
2011 
2010
LIABILITIES AND EQUITY
 
 
 
 
Current liabilities:
 
 
 
 
    Accounts payable
$
 375 
$
 292 
    Due to unconsolidated affiliate
 
 14 
 
 16 
    Deferred income taxes
 
 62 
 
 ― 
    Accrued compensation and benefits
 
 124 
 
 115 
    Regulatory balancing accounts, net
 
 ― 
 
 61 
    Current portion of long-term debt
 
 19 
 
 19 
    Fixed-price contracts and other derivatives
 
 55 
 
 51 
    Customer deposits
 
 62 
 
 54 
    Reserve for wildfire litigation
 
 586 
 
 639 
    Other
 
 139 
 
 136 
        Total current liabilities
 
 1,436 
 
 1,383 
Long-term debt ($345 and $355 at December 31, 2011 and 2010, respectively,
 
 
 
 
    related to VIE)
 
 4,058 
 
 3,479 
 
 
 
 
 
Deferred credits and other liabilities:
 
 
 
 
    Customer advances for construction
 
 20 
 
 21 
    Pension and other postretirement benefit obligations, net of plan assets
 
 342 
 
 309 
    Deferred income taxes
 
 1,167 
 
 1,001 
    Deferred investment tax credits
 
 26 
 
 25 
    Regulatory liabilities arising from removal obligations
 
 1,462 
 
 1,409 
    Asset retirement obligations
 
 693 
 
 619 
    Fixed-price contracts and other derivatives
 
 243 
 
 248 
    Deferred credits and other
 
 188 
 
 283 
        Total deferred credits and other liabilities
 
 4,141 
 
 3,915 
Contingently redeemable preferred stock
 
 79 
 
 79 
 
 
 
 
 
Commitments and contingencies (Note 15)
 
 
 
 
 
 
 
 
 
Equity:
 
 
 
 
    Common stock (255 million shares authorized; 117 million shares outstanding;
 
 
 
 
        no par value)
 
 1,338 
 
 1,138 
    Retained earnings
 
 2,411 
 
 1,980 
    Accumulated other comprehensive income (loss)
 
 (10)
 
 (10)
        Total SDG&E shareholder’s equity
 
 3,739 
 
 3,108 
    Noncontrolling interest
 
 102 
 
 113 
        Total equity
 
 3,841 
 
 3,221 
Total liabilities and equity
$
 13,555 
$
 12,077 
See Notes to Consolidated Financial Statements.



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



SAN DIEGO GAS & ELECTRIC COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS (CONTINUED)
(Dollars in millions)
 
Years ended December 31,
 
2011 
2010 
2009 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
 
 
 
 
 
 
    Interest payments, net of amounts capitalized
$
 131 
$
 120 
$
 99 
    Income tax payments, net of refunds
 
 59 
 
 108 
 
 148 
 
 
 
 
 
 
 
SUPPLEMENTAL DISCLOSURE OF NONCASH ACTIVITIES
 
 
 
 
 
 
    Increase in capital lease obligations for investments in property, plant
 
 
 
 
 
 
        and equipment
$
 ― 
$
 188 
$
 21 
    Accrued capital expenditures
 
 187 
 
 173 
 
 157 
    Dividends declared but not paid
 
 1 
 
 1 
 
 1 
See Notes to Consolidated Financial Statements.



SAN DIEGO GAS & ELECTRIC COMPANY
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME AND CHANGES IN EQUITY
(Dollars in millions)
 
Years ended December 2011, 2010 and 2009
 
 
 
 
Accumulated
 
 
 
 
 
 
 
Other
SDG&E
 
 
 
Common
Retained
Comprehensive
Shareholder’s
Noncontrolling
Total
 
Stock
Earnings
Income (Loss)
Equity
Interests
Equity
Balance at December 31, 2008
$
 1,138 
$
 1,417 
$
 (13)
$
 2,542 
$
 128 
$
 2,670 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net income
 
 
 
 349 
 
 
 
 349 
 
 24 
 
 373 
Comprehensive income adjustments:
 
 
 
 
 
 
 
 
 
 
 
 
    Pension and other postretirement benefits
 
 
 
 
 
 2 
 
 2 
 
 
 
 2 
    Financial instruments
 
 
 
 
 
 1 
 
 1 
 
 (3)
 
 (2)
Comprehensive income
 
 
 
 
 
 3 
 
 352 
 
 21 
 
 373 
 
 
 
 
 
 
 
 
 
 
 
 
 
Preferred stock dividends declared
 
 
 
 (5)
 
 
 
 (5)
 
 
 
 (5)
Common stock dividends declared
 
 
 
 (150)
 
 
 
 (150)
 
 
 
 (150)
Distributions to noncontrolling interest
 
 
 
 
 
 
 
 
 
 (9)
 
 (9)
Equity contributed by noncontrolling interest
 
 
 
 
 
 
 
 
 
 6 
 
 6 
Balance at December 31, 2009
 
 1,138 
 
 1,611 
 
 (10)
 
 2,739 
 
 146 
 
 2,885 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net income (loss)
 
 
 
 374 
 
 
 
 374 
 
 (16)
 
 358 
Comprehensive income adjustments:
 
 
 
 
 
 
 
 
 
 
 
 
    Financial instruments
 
 
 
 
 
 
 
 
 
 7 
 
 7 
Comprehensive income (loss)
 
 
 
 
 
 ― 
 
 374 
 
 (9)
 
 365 
 
 
 
 
 
 
 
 
 
 
 
 
 
Preferred stock dividends declared
 
 
 
 (5)
 
 
 
 (5)
 
 
 
 (5)
Distributions to noncontrolling interest
 
 
 
 
 
 
 
 
 
 (24)
 
 (24)
Balance at December 31, 2010
 
 1,138 
 
 1,980 
 
 (10)
 
 3,108 
 
 113 
 
 3,221 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net income
 
 
 
 436 
 
 
 
 436 
 
 19 
 
 455 
Comprehensive income adjustments:
 
 
 
 
 
 
 
 
 
 
 
 
    Financial instruments
 
 
 
 
 
 
 
 
 
 (36)
 
 (36)
Comprehensive income (loss)
 
 
 
 
 
 ― 
 
 436 
 
 (17)
 
 419 
 
 
 
 
 
 
 
 
 
 
 
 
 
Preferred stock dividends declared
 
 
 
 (5)
 
 
 
 (5)
 
 
 
 (5)
Capital contribution
 
 200 
 
 
 
 
 
 200 
 
 
 
 200 
Equity contributed by noncontrolling interest
 
 
 
 
 
 
 
 
 
 6 
 
 6 
Balance at December 31, 2011
$
 1,338 
$
 2,411 
$
 (10)
$
 3,739 
$
 102 
$
 3,841 
See Notes to Consolidated Financial Statements.


SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
 
Years ended December 31,
 
2011 
2010 
2009 
 
 
 
 
 
 
 
Operating revenues
$
 3,816 
$
 3,822 
$
 3,355 
Operating expenses
 
 
 
 
 
 
    Cost of natural gas
 
 1,568 
 
 1,699 
 
 1,343 
    Operation and maintenance
 
 1,305 
 
 1,174 
 
 1,138 
    Depreciation
 
 331 
 
 309 
 
 293 
    Franchise fees and other taxes
 
 126 
 
 124 
 
 105 
        Total operating expenses
 
 3,330 
 
 3,306 
 
 2,879 
Operating income
 
 486 
 
 516 
 
 476 
Other income, net
 
 13 
 
 12 
 
 7 
Interest income
 
 1 
 
 1 
 
 3 
Interest expense
 
 (69)
 
 (66)
 
 (68)
Income before income taxes
 
 431 
 
 463 
 
 418 
Income tax expense
 
 (143)
 
 (176)
 
 (144)
Net income
 
 288 
 
 287 
 
 274 
Preferred dividend requirements
 
 (1)
 
 (1)
 
 (1)
Earnings attributable to common shares
$
 287 
$
 286 
$
 273 
See Notes to Consolidated Financial Statements.
 
 
 
 

 
SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
 
December 31,
December 31,
 
2011 
2010 
ASSETS
 
 
 
 
Current assets:
 
 
 
 
    Cash and cash equivalents
$
 36 
$
 417 
    Accounts receivable – trade, net
 
 578 
 
 534 
    Accounts receivable – other, net
 
 63 
 
 49 
    Due from unconsolidated affiliates
 
 40 
 
 63 
    Income taxes receivable
 
 17 
 
 28 
    Inventories
 
 151 
 
 105 
    Regulatory assets
 
 9 
 
 12 
    Other
 
 28 
 
 39 
        Total current assets
 
 922 
 
 1,247 
 
 
 
 
 
Other assets:
 
 
 
 
    Regulatory assets arising from pension and other postretirement
 
 
 
 
        benefit obligations
 
 808 
 
 586 
    Other regulatory assets
 
 137 
 
 123 
    Sundry
 
 8 
 
 8 
        Total other assets
 
 953 
 
 717 
 
 
 
 
 
Property, plant and equipment:
 
 
 
 
    Property, plant and equipment
 
 10,565 
 
 9,824 
    Less accumulated depreciation and amortization
 
 (3,965)
 
 (3,802)
        Property, plant and equipment, net
 
 6,600 
 
 6,022 
Total assets
$
 8,475 
$
 7,986 
See Notes to Consolidated Financial Statements.



SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
 
December 31,
December 31,
 
2011 
2010 
LIABILITIES AND SHAREHOLDERS’ EQUITY
 
 
 
 
Current liabilities:
 
 
 
 
    Accounts payable – trade
$
 315 
$
 327 
    Accounts payable – other
 
 78 
 
 79 
    Due to unconsolidated affiliate
 
 2 
 
 11 
    Deferred income taxes
 
 44 
 
 17 
    Accrued compensation and benefits
 
 99 
 
 98 
    Regulatory balancing accounts, net
 
 105 
 
 180 
    Current portion of long-term debt
 
 257 
 
 262 
    Customer deposits
 
 75 
 
 73 
    Other
 
 172 
 
 163 
        Total current liabilities
 
 1,147 
 
 1,210 
Long-term debt
 
 1,064 
 
 1,320 
Deferred credits and other liabilities:
 
 
 
 
    Customer advances for construction
 
 110 
 
 133 
    Pension and other postretirement benefit obligations, net of plan assets
 
 833 
 
 613 
    Deferred income taxes
 
 576 
 
 418 
    Deferred investment tax credits
 
 23 
 
 25 
    Regulatory liabilities arising from removal obligations
 
 1,075 
 
 1,208 
    Asset retirement obligations
 
 1,161 
 
 788 
    Deferred taxes refundable in rates
 
 87 
 
 138 
    Deferred credits and other
 
 206 
 
 178 
        Total deferred credits and other liabilities
 
 4,071 
 
 3,501 
 
 
 
 
 
Commitments and contingencies (Note 15)
 
 
 
 
 
 
 
 
 
Shareholders’ equity:
 
 
 
 
    Preferred stock
 
 22 
 
 22 
    Common stock (100 million shares authorized; 91 million shares outstanding;
 
 
 
 
        no par value)
 
 866 
 
 866 
    Retained earnings
 
 1,326 
 
 1,089 
    Accumulated other comprehensive income (loss)
 
 (21)
 
 (22)
        Total shareholders’ equity
 
 2,193 
 
 1,955 
Total liabilities and shareholders’ equity
$
 8,475 
$
 7,986 
See Notes to Consolidated Financial Statements.



SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in millions)
 
Years ended December 31,
 
2011 
2010 
2009 
CASH FLOWS FROM OPERATING ACTIVITIES
 
 
 
 
 
 
    Net income
$
 288 
$
 287 
$
 274 
    Adjustments to reconcile net income to net cash provided by
 
 
 
 
 
 
        operating activities:
 
 
 
 
 
 
            Depreciation
 
 331 
 
 309 
 
 293 
            Deferred income taxes and investment tax credits
 
 130 
 
 107 
 
 70 
            Other
 
 (6)
 
 ― 
 
 8 
    Changes in other assets
 
 19 
 
 (7)
 
 7 
    Changes in other liabilities
 
 (7)
 
 8 
 
 (68)
    Changes in working capital components:
 
 
 
 
 
 
        Accounts receivable
 
 (57)
 
 18 
 
 (30)
        Inventories
 
 (46)
 
 (12)
 
 74 
        Other current assets
 
 5 
 
 (2)
 
 10 
        Accounts payable
 
 (7)
 
 52 
 
 (99)
        Income taxes
 
 (12)
 
 5 
 
 (2)
        Due to/from affiliates, net
 
 (18)
 
 11 
 
 (10)
        Regulatory balancing accounts
 
 (63)
 
 (56)
 
 10 
        Customer deposits
 
 2 
 
 (13)
 
 (28)
        Other current liabilities
 
 (5)
 
 29 
 
 (69)
            Net cash provided by operating activities
 
 554 
 
 736 
 
 440 
 
 
 
 
 
 
 
CASH FLOWS FROM INVESTING ACTIVITIES
 
 
 
 
 
 
    Expenditures for property, plant and equipment
 
 (683)
 
 (503)
 
 (480)
    Decrease (increase) in loans to affiliates, net
 
 49 
 
 (63)
 
 (16)
            Net cash used in investing activities
 
 (634)
 
 (566)
 
 (496)
 
 
 
 
 
 
 
CASH FLOWS FROM FINANCING ACTIVITIES
 
 
 
 
 
 
    Common dividends paid
 
 (50)
 
 (100)
 
 ― 
    Preferred dividends paid
 
 (1)
 
 (1)
 
 (1)
    Issuance of long-term debt
 
 ― 
 
 299 
 
 ― 
    Payment of long-term debt
 
 (250)
 
 ― 
 
 (100)
            Net cash (used in) provided by financing activities
 
 (301)
 
 198 
 
 (101)
 
 
 
 
 
 
 
(Decrease) increase in cash and cash equivalents
 
 (381)
 
 368 
 
 (157)
Cash and cash equivalents, January 1
 
 417 
 
 49 
 
 206 
Cash and cash equivalents, December 31
$
 36 
$
 417 
$
 49 
 
 
 
 
 
 
 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
 
 
 
 
 
 
    Interest payments, net of amounts capitalized
$
 65 
$
 54 
$
 59 
    Income tax payments, net of refunds
 
 25 
 
 64 
 
 76 
 
 
 
 
 
 
 
SUPPLEMENTAL DISCLOSURE OF NONCASH ACTIVITIES
 
 
 
 
 
 
    Accrued capital expenditures
$
 97 
$
 103 
$
 75 
    Increase in capital lease obligations for investments in property, plant and
 
 
 
 
 
 
        equipment
 
 ― 
 
 4 
 
 29 
See Notes to Consolidated Financial Statements.



SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME AND CHANGES IN SHAREHOLDERS’ EQUITY
(Dollars in millions)
 
Years ended December 31, 2011, 2010 and 2009
 
 
 
 
 
 
Accumulated
 
 
 
 
 
 
 
Other
Total
 
Preferred
Common
Retained
Comprehensive
Shareholders’
 
Stock
Stock
Earnings
Income (Loss)
Equity
Balance at December 31, 2008
$
 22 
$
 866 
$
 630 
$
 (28)
$
 1,490 
 
 
 
 
 
 
 
 
 
 
 
Net income
 
 
 
 
 
 274 
 
 
 
 274 
Comprehensive income adjustments:
 
 
 
 
 
 
 
 
 
 
    Financial instruments
 
 
 
 
 
 
 
 3 
 
 3 
Comprehensive income
 
 
 
 
 
 
 
 3 
 
 277 
 
 
 
 
 
 
 
 
 
 
 
Preferred stock dividends declared
 
 
 
 
 
 (1)
 
 
 
 (1)
Balance at December 31, 2009
 
 22 
 
 866 
 
 903 
 
 (25)
 
 1,766 
 
 
 
 
 
 
 
 
 
 
 
Net income
 
 
 
 
 
 287 
 
 
 
 287 
Comprehensive income adjustments:
 
 
 
 
 
 
 
 
 
 
    Financial instruments
 
 
 
 
 
 
 
 3 
 
 3 
Comprehensive income
 
 
 
 
 
 
 
 3 
 
 290 
 
 
 
 
 
 
 
 
 
 
 
Preferred stock dividends declared
 
 
 
 
 
 (1)
 
 
 
 (1)
Common stock dividends declared
 
 
 
 
 
 (100)
 
 
 
 (100)
Balance at December 31, 2010
 
 22 
 
 866 
 
 1,089 
 
 (22)
 
 1,955 
 
 
 
 
 
 
 
 
 
 
 
Net income
 
 
 
 
 
 288 
 
 
 
 288 
Comprehensive income adjustments:
 
 
 
 
 
 
 
 
 
 
    Pension and other postretirement benefits
 
 
 
 
 
 
 
 (1)
 
 (1)
    Financial instruments
 
 
 
 
 
 
 
 2 
 
 2 
Comprehensive income
 
 
 
 
 
 
 
 1 
 
 289 
 
 
 
 
 
 
 
 
 
 
 
Preferred stock dividends declared
 
 
 
 
 
 (1)
 
 
 
 (1)
Common stock dividends declared
 
 
 
 
 
 (50)
 
 
 
 (50)
Balance at December 31, 2011
$
 22 
$
 866 
$
 1,326 
$
 (21)
$
 2,193 
See Notes to Consolidated Financial Statements.



 
 
 
 

SEMPRA ENERGY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
 

 

NOTE 1. SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA
 

 
PRINCIPLES OF CONSOLIDATION
 
 
Sempra Energy
 
Sempra Energy’s Consolidated Financial Statements include the accounts of Sempra Energy, a California-based Fortune 500 holding company, and its consolidated subsidiaries and a variable interest entity (VIE). Sempra Energy’s principal subsidiaries are
 
§  
San Diego Gas & Electric Company (SDG&E) and Southern California Gas Company (SoCalGas); and
 
§  
Sempra Global, the holding company for our energy-related businesses, which are Sempra Generation, Sempra Pipelines & Storage, Sempra LNG and, prior to 2011, Sempra Commodities. Sempra Pipelines & Storage also owns utilities in the U.S., Mexico, and South America.
 
We refer to SDG&E and SoCalGas collectively as the Sempra Utilities, which do not include the utilities in our Sempra Pipelines & Storage business unit. All references in these Notes to “Sempra Generation,” “Sempra Pipelines & Storage,” and “Sempra LNG,” are to the respective principal business units of Sempra Global and are not intended to refer to any legal entity with the same or similar name.
 
Sempra Energy uses the equity method to account for investments in affiliated companies over which we have the ability to exercise significant influence, but not control. We discuss our investments in unconsolidated subsidiaries in Notes 3 and 4.
 
 
SDG&E
 
SDG&E’s Consolidated Financial Statements include its accounts and the accounts of a VIE of which SDG&E is the primary beneficiary, as we discuss below under “Variable Interest Entities.” SDG&E’s common stock is wholly owned by Enova Corporation, which is a wholly owned subsidiary of Sempra Energy.
 
 
SoCalGas
 
SoCalGas’ Consolidated Financial Statements include its subsidiaries, which comprise less than one percent of its consolidated financial position and results of operations. SoCalGas’ common stock is wholly owned by Pacific Enterprises (PE), which is a wholly owned subsidiary of Sempra Energy.
 
 
BASIS OF PRESENTATION
 
This is a combined report of Sempra Energy, SDG&E and SoCalGas. We provide separate information for SDG&E and SoCalGas as required. References in this report to “we,” “our” and “Sempra Energy Consolidated” are to Sempra Energy and its consolidated entities, unless otherwise indicated by the context. We have eliminated intercompany accounts and transactions within the consolidated financial statements of each reporting entity.
 
We evaluated events and transactions that occurred after December 31, 2011 through the date the financial statements were issued, and in the opinion of management, the accompanying statements reflect all adjustments necessary for a fair presentation.
 
As we discuss in Note 3, in April 2011, Sempra Pipelines & Storage acquired two electric distribution utilities in South America. Sempra Pipelines & Storage also owns Mobile Gas Service Corporation (Mobile Gas) in southwest Alabama and Ecogas Mexico, S de RL de CV (Ecogas) in Northern Mexico, both natural gas distribution utilities. In prior years, we provided separate revenue and cost of revenue information on our consolidated statements of operations for the Sempra Utilities only, as the amounts for Mobile Gas and Ecogas were immaterial. Due to the addition of the South American utilities, we are now providing separate revenue and cost of revenue information on the Consolidated Statements of Operations on a combined basis for all of our utilities. Accordingly, amounts in the prior periods have been reclassified to conform with the current year presentation.
 

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

 
REGULATORY MATTERS
 
 
Effects of Regulation
 
The accounting policies of our regulated utility subsidiaries in California, SDG&E and SoCalGas, conform with GAAP for regulated enterprises and reflect the policies of the California Public Utilities Commission (CPUC) and the Federal Energy Regulatory Commission (FERC).
 
The Sempra Utilities prepare their financial statements in accordance with GAAP provisions governing regulated operations. Under these provisions, a regulated utility records a regulatory asset if it is probable that, through the ratemaking process, the utility will recover that asset from customers. To the extent that recovery is no longer probable, the related regulatory assets are written off. Regulatory liabilities represent amounts collected from customers in advance of the actual expenditure by the utility. If the actual expenditures are less than amounts previously collected from ratepayers, the excess would be refunded to customers, generally by reducing future rates.
 
The following subsidiaries of Sempra Pipelines & Storage also apply GAAP for regulated utilities to their operations:
 
§  
Mobile Gas
§  
Ecogas

We provide information concerning regulatory assets and liabilities below in “Regulatory Balancing Accounts” and “Regulatory Assets and Liabilities.”
 
 
Regulatory Balancing Accounts
 
The following table summarizes our regulatory balancing accounts at December 31. The net payables (payables net of receivables) will be returned to customers by reducing future rates.
 

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

Over- and undercollected regulatory balancing accounts reflect the difference between customer billings and recorded or CPUC-authorized costs, primarily commodity costs. Amounts in the balancing accounts are recoverable or refundable in future rates, subject to CPUC approval. Balancing account treatment eliminates the impact on earnings from variances in the covered costs from authorized amounts. Absent balancing account treatment, variations in the cost of fuel supply and certain operating and maintenance costs from amounts approved by the CPUC would increase volatility in utility earnings.
 
We provide additional information about regulatory matters in Notes 14 and 15.
 

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

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

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

In the tables above:
 
§  
Regulatory assets arising from fixed-price contracts and other derivatives are offset by corresponding liabilities arising from purchased power and natural gas commodity and transportation contracts. The regulatory asset is increased/decreased based on changes in the fair market value of the contracts. It is also reduced as payments are made for commodities and services under these contracts.
§  
Deferred taxes recoverable/refundable in rates are based on current regulatory ratemaking and income tax laws. SDG&E and SoCalGas expect to recover/refund net regulatory assets/liabilities related to deferred income taxes over the lives of the assets that give rise to the accumulated deferred income tax liabilities/assets.
§  
Regulatory assets related to unamortized losses on reacquired debt are recovered over the remaining original amortization periods of the losses on reacquired debt. These periods range from 9 months to 16 years for SDG&E and from 2 years to 15 years for SoCalGas.
§  
Regulatory assets related to environmental costs represent the portion of our environmental liability recognized at the end of the period in excess of the amount that has been recovered through rates charged to customers. We expect this amount to be recovered in future rates as expenditures are made.
§  
Regulatory assets related to pension and other postretirement benefit obligations are offset by corresponding liabilities and are being recovered in rates as the plans are funded.
§  
Regulatory assets arising from costs related to wildfire litigation are costs in excess of liability insurance coverage and amounts recovered, and to be recovered, from other potentially responsible parties, as we discuss in Note 15 under “SDG&E—2007 Wildfire Litigation.”
§  
The regulatory asset related to the legacy meters removed from service and replaced under the Smart Meter Program is their undepreciated value. SDG&E expects to recover this asset over a remaining life of 28 years.
 
For substantially all of these assets, the cash has not yet been expended and the assets are offset by liabilities that do not incur a carrying cost.
 
 
FAIR VALUE MEASUREMENTS
 
We apply recurring fair value measurements to certain assets and liabilities, primarily nuclear decommissioning and benefit plan trust assets and other miscellaneous derivatives. “Fair value” is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price).
 
A fair value measurement reflects the assumptions market participants would use in pricing an asset or liability based on the best available information. These assumptions include the risk inherent in a particular valuation technique (such as a pricing model) and the risks inherent in the inputs to the model. Also, we consider an issuer’s credit standing when measuring its liabilities at fair value.
 
We establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows:
 
Level 1 – Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Our Level 1 financial instruments primarily consist of listed equities, U.S. government treasury securities and exchange-traded derivatives.
 
Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including:
 
§  
quoted forward prices for commodities
§  
time value
§  
current market and contractual prices for the underlying instruments
§  
volatility factors
§  
other relevant economic measures
 
Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Our financial instruments in this category include the Nuclear Decommissioning Trusts’ investments at SDG&E and non-exchange-traded derivatives such as interest rate instruments and over-the-counter (OTC) forwards and options.
 
Level 3 – Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value from the perspective of a market participant.
 
 
CASH AND CASH EQUIVALENTS
 
Cash equivalents are highly liquid investments with maturities of three months or less at the date of purchase.
 
 
RESTRICTED CASH
 
Restricted cash at Sempra Energy, including amounts at SDG&E discussed below, was $46 million and $158 million at December 31, 2011 and 2010, respectively. At December 31, 2010, it included long-term funds held in trust for construction financing of certain natural gas storage facilities of Sempra Pipelines & Storage of $27 million.
 
We held $3 million and $15 million, respectively, at December 31, 2011 and 2010 of cash collateral received as security for guarantees issued by Sempra Energy related to businesses sold by RBS Sempra Commodities.  We discuss RBS Sempra Commodities in Note 4 and our related guarantees in Note 5.
 
SDG&E had restricted cash at December 31, 2011 of $14 million related to the purchase of a power plant on January 1, 2012. SDG&E had $110 million of restricted cash at December 31, 2010 representing funds received from a wildfire litigation settlement that we describe in Note 15.  These funds were restricted to use for 2007 wildfire litigation expenditures.  In addition, restricted cash at SDG&E of $29 million and $6 million at December 31, 2011 and 2010, respectively, are funds held by a trustee for Otay Mesa VIE (see “Variable Interest Entities—Otay Mesa VIE” below) to pay certain operating costs.
 
 
COLLECTION ALLOWANCES
 
We record allowances for the collection of trade and other accounts and notes receivable which include allowances for doubtful customer accounts and for other receivables. We show the changes in these allowances in the table below:
 

COLLECTION ALLOWANCES
(Dollars in millions)
 
Years ended December 31,
 
2011 
2010 
2009 
Sempra Energy Consolidated
 
 
 
 
 
 
Allowances for collection of receivables at January 1
$
 29 
$
 27 
$
 29 
Provisions for uncollectible accounts
 
 20 
 
 22 
 
 25 
Write-offs of uncollectible accounts
 
 (20)
 
 (20)
 
 (27)
Allowances for collection of receivables at December 31
$
 29 
$
 29 
$
 27 
SDG&E
 
 
 
 
 
 
Allowances for collection of receivables at January 1
$
 5 
$
 4 
$
 6 
Provisions for uncollectible accounts
 
 8 
 
 7 
 
 8 
Write-offs of uncollectible accounts
 
 (7)
 
 (6)
 
 (10)
Allowances for collection of receivables at December 31
$
 6 
$
 5 
$
 4 
SoCalGas
 
 
 
 
 
 
Allowances for collection of receivables at January 1
$
 14 
$
 16 
$
 18 
Provisions for uncollectible accounts
 
 8 
 
 8 
 
 12 
Write-offs of uncollectible accounts
 
 (10)
 
 (10)
 
 (14)
Allowances for collection of receivables at December 31
$
 12 
$
 14 
$
 16 
 
INVENTORIES
 
The Sempra Utilities value natural gas inventory by the last-in first-out (LIFO) method. As inventories are sold, differences between the LIFO valuation and the estimated replacement cost are reflected in customer rates. Materials and supplies at the Sempra Utilities are generally valued at the lower of average cost or market.
 
At December 31, 2011 and 2010, Sempra Pipelines & Storage had $47 million and $35 million, respectively, of natural gas inventory recorded at lower of average cost or market and had $37 million and $2 million, respectively, of material and supplies valued at lower of average cost or market. At December 31, 2011 and 2010, Sempra LNG had $14 million and $26 million, respectively, of liquefied natural gas (LNG) inventory (categorized as natural gas below) valued by the first-in first-out method. At December 31, 2011 and 2010, Sempra Generation had $15 million and $18 million, respectively, of material and supplies valued at average cost or market.
 
INVENTORY BALANCES AT DECEMBER 31
(Dollars in millions)
 
 
Sempra Energy
 
 
 
 
Consolidated
SDG&E
SoCalGas
 
 
2011 
2010 
2011 
2010 
2011 
2010 
Natural gas
$
 195 
$
 152 
$
 6 
$
 5 
$
 128 
$
 86 
Materials and supplies
 
 151 
 
 106 
 
 76 
 
 66 
 
 23 
 
 19 
Total
$
 346 
$
 258 
$
 82 
$
 71 
$
 151 
$
 105 
 
INCOME TAXES
 
Income tax expense includes current and deferred income taxes from operations during the year. We record deferred income taxes for temporary differences between the book and the tax bases of assets and liabilities.  Investment tax credits from prior years are amortized to income by the Sempra Utilities over the estimated service lives of the properties as required by the CPUC, and represent regulatory liabilities. At Sempra Global and Parent, investment tax credits and production tax credits are recognized in income as earned.
 
The Sempra Utilities and Mobile Gas recognize
 
§  
regulatory assets to offset deferred tax liabilities if it is probable that the amounts will be recovered from customers; and
§  
regulatory liabilities to offset deferred tax assets if it is probable that the amounts will be returned to customers.
 
Other than local country withholding tax on current Peruvian earnings, we currently do not record deferred income taxes for basis differences between financial statement and income tax investment amounts in non-U.S. subsidiaries because their cumulative undistributed earnings are indefinitely reinvested.
 
When there are uncertainties related to potential income tax benefits, in order to qualify for recognition, the position we take has to have at least a “more likely than not” chance of being sustained (based on the position’s technical merits) upon challenge by the respective authorities. The term “more likely than not” means a likelihood of more than 50 percent. Otherwise, we may not recognize any of the potential tax benefit associated with the position. We recognize a benefit for a tax position that meets the “more likely than not” criterion at the largest amount of tax benefit that is greater than 50 percent likely of being realized upon its effective resolution.
 
Unrecognized tax benefits involve management’s judgment regarding the likelihood of the benefit being sustained. The final resolution of uncertain tax positions could result in adjustments to recorded amounts and may affect our results of operations, financial position and cash flows.
 
We provide additional information about income taxes in Note 7.
 
 
PROPERTY, PLANT AND EQUIPMENT
 
Property, plant and equipment primarily represents the buildings, equipment and other facilities used by the Sempra Utilities to provide natural gas and electric utility services, and by Sempra Generation, Sempra Pipelines & Storage and Sempra LNG. It also reflects projects included in construction work in progress at these business units.
 
Our plant costs include
 
§  
labor
 
§  
materials and contract services
 
§  
expenditures for replacement parts incurred during a major maintenance outage of a generating plant
 
In addition, the cost of our utility plant includes an allowance for funds used during construction (AFUDC). We discuss AFUDC below. The cost of non-utility plant includes capitalized interest.
 
Maintenance costs are expensed as incurred.  The cost of most retired depreciable utility plant minus salvage value is charged to accumulated depreciation.
 

PROPERTY, PLANT AND EQUIPMENT BY MAJOR FUNCTIONAL CATEGORY
(Dollars in millions)
 
 
Property, Plant
 
Depreciation rates for
 
 
and Equipment at
 
years ended
 
 
December 31,
 
December 31,
 
 
2011 
2010 
 
2011 
2010 
2009 
SDG&E:
 
 
 
 
 
 
 
 
 
 
 
    Natural gas operations
$
 1,349 
$
 1,280 
 
 3.15 
%
 3.00 
%
 2.84 
%
    Electric distribution
 
 4,894 
 
 4,700 
 
 4.13 
 
 4.06 
 
 3.97 
 
    Electric transmission
 
 1,938 
 
 1,795 
 
 2.74 
 
 2.70 
 
 2.67 
 
    Electric generation(1)
 
 2,166 
 
 1,737 
 
 4.92 
 
 4.30 
 
 3.84 
 
    Other electric(2)
 
 604 
 
 666 
 
 8.26 
 
 8.19 
 
 8.50 
 
    Construction work in progress
 
 2,052 
 
 1,069 
 
NA
 
NA
 
NA
 
        Total SDG&E
 
 13,003 
 
 11,247 
 
 
 
 
 
 
 
SoCalGas:
 
 
 
 
 
 
 
 
 
 
 
    Natural gas operations(3)
 
 10,055 
 
 9,376 
 
 3.62 
 
 3.54 
 
 3.50 
 
    Other non-utility
 
 129 
 
 126 
 
 1.62 
 
 1.74 
 
 1.41 
 
    Construction work in progress
 
 381 
 
 322 
 
NA
 
NA
 
NA
 
        Total SoCalGas
 
 10,565 
 
 9,824 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Sempra Global and parent(4):
 
 
 
 
 
Estimated Useful Lives
    Land and land rights
 
 292 
 
 194 
 
25 to 50 years(5)
    Machinery and equipment:
 
 
 
 
 
 
 
 
 
 
 
        Utility electric distribution operations
 
 1,267 
 
 ― 
 
10 to 50 years
        Generating plants
 
 1,389 
 
 1,668 
 
4 to 35 years
        LNG terminals
 
 2,059 
 
 2,049 
 
3 to 50 years
        Pipelines and storage
 
 1,510 
 
 1,375 
 
10 to 50 years
        Other
 
 168 
 
 97 
 
2 to 50 years
    Construction work in progress
 
 849 
 
 428 
 
 
 
N/A
 
 
 
    Other
 
 201 
 
 205 
 
3 to 50 years
 
 
 7,735 
 
 6,016 
 
 
 
 
 
 
 
        Total Sempra Energy Consolidated
$
 31,303 
$
 27,087 
 
 
 
 
 
 
 
(1)
Includes capital lease assets of $183 million and $182 million at December 31, 2011 and 2010, respectively.
(2)
Includes capital lease assets of $26 million at both December 31, 2011 and 2010.
(3)
Includes capital lease assets of $33 million at both December 31, 2011 and 2010.
(4)
December 31, 2011 balances include $163 million and $126 million of utility plant, primarily pipelines and other distribution assets, at Mobile Gas and Ecogas, respectively. December 31, 2010 balances include $156 million and $137 million of utility plant, primarily pipelines and other distribution assets, at Mobile Gas and Ecogas, respectively.
(5)
Estimated useful lives are for land rights.

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

The accumulated depreciation and decommissioning amounts on our Consolidated Balance Sheets are as follows:
 
ACCUMULATED DEPRECIATION AND DECOMMISSIONING AMOUNTS
(Dollars in millions)
 
 
December 31,
 
 
2011 
2010 
SDG&E:
 
 
 
 
    Accumulated depreciation and decommissioning of utility plant in service:
 
 
 
 
        Electric(1)
$
 2,387 
$
 2,152 
        Natural gas
 
 576 
 
 542 
            Total SDG&E
 
 2,963 
 
 2,694 
SoCalGas:
 
 
 
 
    Accumulated depreciation of natural gas utility plant in service(2)
 
 3,863 
 
 3,702 
    Accumulated depreciation – other non-utility
 
 102 
 
 100 
            Total SoCalGas
 
 3,965 
 
 3,802 
Sempra Global and parent:
 
 
 
 
    Accumulated depreciation – other non-utility(3)
 
 759 
 
 715 
    Accumulated depreciation of utility electric distribution operations
 
 44 
 
 ― 
 
 
 
 803 
 
 715 
Total Sempra Energy Consolidated
$
 7,731 
$
 7,211 
(1)
Includes accumulated depreciation for assets under capital lease of $16 million and $7 million at December 31, 2011 and 2010, respectively.
(2)
Includes accumulated depreciation for assets under capital lease of $22 million and $14 million at December 31, 2011 and 2010, respectively.
(3)
December 31, 2011 balances include $15 million and $28 million of accumulated depreciation for utility plant at Mobile Gas and Ecogas, respectively. December 31, 2010 balances include $9 million and $29 million of accumulated depreciation for utility plant at Mobile Gas and Ecogas, respectively.

The Sempra Utilities finance their construction projects with borrowed funds and equity funds. The CPUC and the FERC allow the recovery of the cost of these funds by the capitalization of AFUDC, calculated using rates authorized by the CPUC and the FERC, as a cost component of property, plant and equipment. The Sempra Utilities earn a return on the allowance after the utility property is placed in service and recover the AFUDC from their customers over the expected useful lives of the assets.
 
Sempra Global businesses capitalize interest costs incurred to finance capital projects.  The Sempra Utilities also capitalize certain interest costs.
 
CAPITALIZED FINANCING COSTS
(Dollars in millions)
 
Years ended December 31,
 
2011 
2010 
2009 
Sempra Energy Consolidated:
 
 
 
 
 
 
    AFUDC related to debt
$
 40 
$
 24 
$
 15 
    AFUDC related to equity
 
 99 
 
 57 
 
 39 
    Other capitalized financing costs
 
 26 
 
 33 
 
 73 
        Total Sempra Energy Consolidated
$
 165 
$
 114 
$
 127 
SDG&E:
 
 
 
 
 
 
    AFUDC related to debt
$
 33 
$
 18 
$
 10 
    AFUDC related to equity
 
 80 
 
 43 
 
 29 
    Other capitalized financing costs
 
 ― 
 
 ― 
 
 4 
        Total SDG&E
$
 113 
$
 61 
$
 43 
SoCalGas:
 
 
 
 
 
 
    AFUDC related to debt
$
 7 
$
 6 
$
 5 
    AFUDC related to equity
 
 19 
 
 14 
 
 10 
    Other capitalized financing costs
 
 ― 
 
 ― 
 
 1 
        Total SoCalGas
$
 26 
$
 20 
$
 16 

ASSETS HELD FOR SALE
 
At December 31, 2010, we held gas and steam turbine assets for sale of $40 million which were recorded in Other Current Assets on the Sempra Energy Consolidated Balance Sheet. In December 2011, management decided to hold these assets for future use in potential development projects at Sempra Generation. Accordingly, we have reclassified them from assets held for sale to construction work in progress. The assets held for sale had no effect on results of operations for any of the periods presented.
 
 
GOODWILL AND OTHER INTANGIBLE ASSETS
 
 
Goodwill
 
Goodwill is the excess of the purchase price over the fair value of the identifiable net assets of acquired companies. Goodwill is not amortized but is tested annually on October 1 for impairment. Impairment of goodwill occurs when the carrying amount (book value) of goodwill exceeds its implied fair value. If the carrying value of the reporting unit, including goodwill, exceeds its fair value, and the book value of goodwill is greater than its fair value on the test date, we record a goodwill impairment loss.
 
Sempra Pipelines & Storage recorded goodwill of $975 million in April 2011 in connection with the acquisition of AEI’s interests in Chilquinta Energía S.A. (Chilquinta Energía) in Chile, Luz del Sur S.A.A. (Luz del Sur) in Peru, and their subsidiaries and $18 million in April 2010 in connection with the acquisition of the Mexican pipeline and natural gas infrastructure assets of El Paso Corporation, which we discuss in Note 3.
 
Goodwill on the Sempra Energy Consolidated Balance Sheets is recorded as follows:
 
GOODWILL
 
 
 
 
 
 
(Dollars in millions)
 
 
 
 
 
 
 
 
 
Sempra
 
 
 
 
 
 
 
Pipelines &
 
Parent
 
 
 
 
 
Storage
 
and Other
 
Total
Balance as of December 31, 2009
$
 62 
$
 6 
$
 68 
Acquisition of Mexican pipeline and natural gas infrastructure assets and other
 
 19 
 
 ― 
 
 19 
Balance as of December 31, 2010
 
 81 
 
 6 
 
 87 
Acquisition of Chilquinta Energía and Luz del Sur
 
 975 
 
 ― 
 
 975 
Foreign currency translation(1)
 
 (26)
 
 ― 
 
 (26)
Balance at December 31, 2011
$
 1,030 
$
 6 
$
 1,036 
(1)
We record the offset of this fluctuation to other comprehensive income.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
We provide additional information concerning goodwill related to our equity method investments and the impairment of investments in unconsolidated subsidiaries in Note 4.
 
 
Other Intangible Assets
 
Sempra Pipelines & Storage recorded $460 million of intangible assets in connection with the acquisition of EnergySouth, Inc. in 2008. These intangible assets represent storage and development rights related to the natural gas storage facilities of Bay Gas Storage, LLC (Bay Gas) and Mississippi Hub, LLC (Mississippi Hub) and were recorded at estimated fair value as of the date of the acquisition using discounted cash flows analysis. Our important assumptions in determining fair value include estimated future cash flows, the estimated useful life of the intangible assets and our use of appropriate discount rates. We are amortizing these intangible assets over their estimated useful lives as shown in the table below.
 

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

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

Amortization expense related to the above intangible assets was $10 million in each of 2011, 2010 and 2009. We estimate the amortization expense for the next five years to be $10 million per year.
 
 
LONG-LIVED ASSETS
 
We periodically evaluate whether events or circumstances have occurred that may affect the recoverability or the estimated useful lives of long-lived assets, the definition of which includes intangible assets subject to amortization, but does not include unconsolidated subsidiaries. Impairment of long-lived assets occurs when the estimated future undiscounted cash flows are less than the carrying amount of the assets. If that comparison indicates that the assets’ carrying value may not be recoverable, the impairment is measured based on the difference between the carrying amount and the fair value of the assets. This evaluation is performed at the lowest level for which separately identifiable cash flows exist.
 
In the second quarter of 2009, we recorded a $132 million pretax write-off related to certain assets at one of Sempra Pipelines & Storage’s natural gas storage projects. This amount is recorded as Write-off of Long-Lived Assets on our Consolidated Statement of Operations for the year ended December 31, 2009. Sempra Pipelines & Storage owns 75 percent of Liberty Gas Storage, LLC (Liberty), the partnership that owns the project. Our partner’s 25-percent share of the pretax charge is $33 million, which is included in (Earnings) Losses Attributable to Noncontrolling Interests on our Consolidated Statement of Operations for the year ended December 31, 2009. The impact to our net income and to our earnings is $97 million and $64 million, respectively, for the year ended December 31, 2009. In September 2009, the members of the partnership unanimously voted to proceed with the abandonment of the assets that were written off. The abandonment work began in late 2010 and was completed in early 2011.
 
 
VARIABLE INTEREST ENTITIES (VIE)
 
We consolidate a VIE if we are the primary beneficiary of the VIE. Our determination of whether we are the primary beneficiary is based upon qualitative and quantitative analyses, which assess
 
§  
the purpose and design of the VIE;
 
§  
the nature of the VIE’s risks and the risks we absorb;
 
§  
the power to direct activities that most significantly impact the economic performance of the VIE; and
 
§  
the obligation to absorb losses or right to receive benefits that could be significant to the VIE.
 
 
SDG&E has agreements under which it purchases power generated by facilities for which it supplies all of the natural gas to fuel the power plant (i.e., tolling agreements).  SDG&E’s obligation to absorb natural gas costs may be a significant variable interest.  In addition, SDG&E has the power to direct the dispatch of electricity generated by these facilities. Based upon our analysis, the ability to direct the dispatch of electricity may have the most significant impacts on the economic performance of the entity owning the generating facility because of the associated exposure to the cost of natural gas, which fuels the plants, and the value of electricity produced. To the extent that SDG&E (1) is obligated to purchase and provide fuel to operate the facility, (2) has the power to direct the dispatch, and (3) purchases all of the output from the facility for a substantial portion of the facility’s useful life, SDG&E may be the primary beneficiary of the entity owning the generating facility. SDG&E determines if it is the primary beneficiary in these cases based on the operational characteristics of the facility, including its expected power generation output relative to its capacity to generate and the financial structure of the entity, among other factors. If we determine that SDG&E is the primary beneficiary, Sempra Energy and SDG&E consolidate the entity that owns the facility as a VIE, as we discuss below.
 
 
Otay Mesa VIE
 
SDG&E has a 10-year agreement to purchase power generated at the Otay Mesa Energy Center (OMEC), a 605-megawatt (MW) generating facility that began commercial operations in October 2009. In addition to tolling, the agreement provides SDG&E with the option to purchase the power plant at the end of the contract term in 2019, or upon earlier termination of the purchased-power agreement, at a predetermined price subject to adjustments based on performance of the facility. If SDG&E does not exercise its option, under certain circumstances, it may be required to purchase the power plant at a predetermined price.
 
The facility owner, Otay Mesa Energy Center LLC (OMEC LLC), is a VIE (Otay Mesa VIE), of which SDG&E is the primary beneficiary.  SDG&E has no OMEC LLC voting rights and does not operate OMEC. In addition to the risks absorbed under the tolling agreement, SDG&E absorbs separately through the put option a significant portion of the risk that the value of Otay Mesa VIE could decline. Sempra Energy and SDG&E have consolidated Otay Mesa VIE since the second quarter of 2007. Otay Mesa VIE’s equity of $102 million at December 31, 2011 and $113 million at December 31, 2010 is included on the Consolidated Balance Sheets in Other Noncontrolling Interests for Sempra Energy and in Noncontrolling Interest for SDG&E.
 
OMEC LLC has a loan outstanding of $355 million at December 31, 2011, the proceeds of which were used for the construction of OMEC. The loan is with third party lenders and is secured by OMEC’s property, plant and equipment. SDG&E is not a party to the loan agreement and does not have any additional implicit or explicit financial responsibility to OMEC LLC. The loan fully matures in April 2019 and bears interest at rates varying with market rates. In addition, OMEC LLC has entered into interest rate swap agreements to moderate its exposure to interest rate changes. We provide additional information concerning the interest rate swaps in Note 10.
 
Other Variable Interest Entities
 
SDG&E’s power procurement is subject to reliability requirements that may require SDG&E to enter into various power purchase arrangements which include variable interests. SDG&E evaluates the respective entities to determine if variable interests exist and, based on the qualitative and quantitative analyses described above, if SDG&E, and thereby Sempra Energy, is the primary beneficiary. SDG&E has determined that no contracts, other than the one relating to Otay Mesa VIE mentioned above, result in SDG&E being the primary beneficiary as of December 31, 2011. In addition to the tolling agreements described above, other variable interests involve various elements of fuel and power costs, including certain construction costs, tax credits, and other components of cash flow expected to be paid to or received by our counterparties. In most of these cases, the expectation of variability is not substantial, and SDG&E generally does not have the power to direct activities that most significantly impact the economic performance of the other VIEs. If our ongoing evaluation of these VIEs were to conclude that SDG&E becomes the primary beneficiary and consolidation by SDG&E becomes necessary, the effects are not expected to significantly affect the financial position, results of operations, or liquidity of SDG&E. SDG&E is not exposed to losses or gains as a result of these other VIEs, because all such variability would be recovered in rates.
 
Sempra Energy’s other business units also enter into arrangements which could include variable interests.  We evaluate these arrangements and applicable entities based upon the qualitative and quantitative analyses described above.  Certain of these entities are service companies that are VIEs.  As the primary beneficiary of these service companies, we consolidate them.  In all other cases, we have determined that these contracts are not variable interests in a VIE and therefore are not subject to the requirements of GAAP concerning the consolidation of VIEs.
 
The Consolidated Financial Statements of Sempra Energy and SDG&E include the following amounts associated with Otay Mesa VIE. The amounts are net of eliminations of transactions between SDG&E and Otay Mesa VIE. The financial statements of other consolidated VIEs are not material to the financial statements of Sempra Energy. The captions on the tables below correspond to SDG&E’s Consolidated Balance Sheets and Consolidated Statements of Operations.
 
 
AMOUNTS ASSOCIATED WITH OTAY MESA VIE
(Dollars in millions)
 
 
 
December 31,
 
 
 
2011 
2010
Cash and cash equivalents
$
 12 
$
 10 
Restricted cash
 
 
 
 
 
 7 
 
 6 
Accounts receivable - trade
 
 
 
 
 
 7 
 
 ― 
Accounts receivable - other
 
 
 
 
 
 ― 
 
 (1)
Inventories
 
 2 
 
 2 
Other
 
 1 
 
 1 
    Total current assets
 
 29 
 
 18 
Restricted cash
 
 
 
 
 
 22 
 
 ― 
Sundry
 
 6 
 
 6 
Property, plant and equipment, net
 
 494 
 
 516 
    Total assets
$
 551 
$
 540 
 
 
 
 
 
Current portion of long-term debt
$
 10 
$
 10 
Fixed-price contracts and other derivatives
 
 16 
 
 17 
Other
 
 9 
 
 1 
    Total current liabilities
 
 35 
 
 28 
Long-term debt
 
 345 
 
 355 
Fixed-price contracts and other derivatives
 
 65 
 
 41 
Deferred credits and other
 
 4 
 
 3 
Other noncontrolling interest
 
 102 
 
 113 
    Total liabilities and equity
$
 551 
$
 540 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Years ended December 31,
 
 
 
2011 
2010 
2009
 
 
 
 
 
 
 
Operating revenues
 
 
 
 
 
 
    Electric
 
 
$
 ― 
$
 (1)
$
 (1)
    Natural gas
 
 
 
 ― 
 
 (3)
 
 ― 
        Total operating revenues
 
 
 
 ― 
 
 (4)
 
 (1)
Operating expenses
 
 
 
 
 
 
    Cost of electric fuel and purchased power
 
 (72)
 
 (82)
 
 (13)
    Operation and maintenance
 19 
 
 20 
 
 7 
    Depreciation and amortization
 
 
 
 22 
 
 26 
 
 7 
        Total operating expenses
 
 
 
 (31)
 
 (36)
 
 1 
Operating income (loss)
 
 
 
 31 
 
 32 
 
 (2)
Other (expense) income, net
 
 
 
 (1)
 
 (34)
 
 27 
Interest expense
 
 
 
 (11)
 
 (14)
 
 (1)
Income (loss) before income taxes/Net income (loss)
 
 19 
 
 (16)
 
 24 
(Earnings) losses attributable to noncontrolling interest
 
 (19)
 
 16 
 
 (24)
    Earnings
$
 ― 
$
 ― 
$
 ― 
 
ASSET RETIREMENT OBLIGATIONS
 
For tangible long-lived assets, we record asset retirement obligations for the present value of liabilities of future costs expected to be incurred when assets are retired from service, if the retirement process is legally required and if a reasonable estimate of fair value can be made. We also record a liability if a legal obligation to perform an asset retirement exists and can be reasonably estimated, but performance is conditional upon a future event. We record the estimated retirement cost over the life of the related asset by depreciating the present value of the obligation (measured at the time of the asset’s acquisition) and accreting the discount until the liability is settled. Rate-regulated entities record regulatory assets or liabilities as a result of the timing difference between the recognition of costs in accordance with GAAP and costs recovered through the rate-making process. We have recorded a regulatory liability to show that the Sempra Utilities have collected funds from customers more quickly and for larger amounts than we would accrete the retirement liability and depreciate the asset in accordance with GAAP.
 
We have recorded asset retirement obligations related to various assets including:
 
SDG&E and SoCalGas
 
§  
fuel and storage tanks
 
§  
natural gas distribution system
 
§  
hazardous waste storage facilities
 
§  
asbestos-containing construction materials
 
SDG&E
 
§  
decommissioning of nuclear power facilities
 
§  
electric distribution and transmission systems
 
§  
site restoration of a former power plant
 
§  
power generation plant (natural gas)
 
SoCalGas
 
§  
natural gas transmission pipelines
 
§  
underground natural gas storage facilities and wells
 
Sempra Global
 
§  
certain power generation plants (natural gas and solar)
 
§  
natural gas distribution and transportation systems
 
§  
LNG terminal
 
The changes in asset retirement obligations are as follows:
 

CHANGES IN ASSET RETIREMENT OBLIGATIONS
(Dollars in millions)
 
 
Sempra Energy
 
 
 
 
 
 
 
 
Consolidated
 
SDG&E
 
SoCalGas
 
 
2011 
2010 
 
2011 
2010 
 
2011 
2010 
Balance as of January 1(1)
$
 1,468 
$
 1,313 
 
$
 623 
$
 590 
 
$
 803 
$
 676 
Accretion expense
 
 82 
 
 77 
 
 
 38 
 
 37 
 
 
 41 
 
 38 
Liabilities incurred
 
 12 
 
 10 
 
 
 3 
 
 ― 
 
 
 ― 
 
 ― 
Payments
 
 (1)
 
 (17)
 
 
 ― 
 
 ― 
 
 
 ― 
 
 (2)
Revisions(2,3)
 
 364 
 
 85 
 
 
 34 
 
 (4)
 
 
 331 
 
 91 
Balance as of December 31(1)
$
 1,925 
$
 1,468 
 
$
 698 
$
 623 
 
$
 1,175 
$
 803 
(1)
The current portions of the obligations are included in Other Current Liabilities on the Consolidated Balance Sheets.
(2)
The increase in obligations at SDG&E and SoCalGas for revisions in 2011 resulted from changes in assets in service and a decrease in the discount rate from 5.13 percent in 2010 to 4.00 percent in 2011, based on the risk-free rate plus an estimated credit spread.
(3)
The increase in obligations at SoCalGas for revisions in 2010 resulted from changes in assets in service and a decrease in the discount rate from 5.54 percent in 2009 to 5.13 percent in 2010, based on the risk-free rate plus an estimated credit spread.
 
CONTINGENCIES
 
We accrue losses for the estimated impacts of various conditions, situations or circumstances involving uncertain outcomes. For loss contingencies, we accrue the loss if an event has occurred on or before the balance sheet date and:
 
§  
information available through the date we file our financial statements indicates it is probable that a loss has been incurred, given the likelihood of uncertain future events; and
 
§  
the amounts of the loss can be reasonably estimated.
 
We do not accrue contingencies that might result in gains. We continuously assess contingencies for litigation claims, environmental remediation and other events.
 
 
LEGAL FEES
 
Legal fees that are associated with a past event for which a liability has been recorded are accrued when it is probable that fees also will be incurred.
 
 
COMPREHENSIVE INCOME
 
Comprehensive income includes all changes in the equity of a business enterprise (except those resulting from investments by owners and distributions to owners), including:
 
§  
foreign-currency translation adjustments
 
§  
changes in unamortized net actuarial gain or loss and prior service cost related to pension and other postretirement benefits plans
 
§  
unrealized gains or losses on available-for-sale securities
 
§  
certain hedging activities
 
The Consolidated Statements of Comprehensive Income and Changes in Shareholders’ Equity show the changes in the components of other comprehensive income (OCI), including the amounts attributable to noncontrolling interests. The components of Accumulated Other Comprehensive Income (Loss) (AOCI), shown net of income taxes on the Consolidated Balance Sheets, and the related income tax balances at December 31, 2011 and 2010 are as follows:
 

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


NONCONTROLLING INTERESTS
 
Ownership interests that are held by owners other than Sempra Energy and SDG&E in subsidiaries or entities consolidated by them are accounted for and reported as noncontrolling interests. As a result, noncontrolling interests are reported as a separate component of equity on the Consolidated Balance Sheets and Consolidated Statements of Comprehensive Income and Changes in Equity. Net income or loss attributable to the noncontrolling interests is separately identified on the Consolidated Statements of Operations.
 
At December 31, 2011 and 2010 we reported the following noncontrolling ownership interests held by others:
 

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

In addition, the preferred stock of subsidiaries at Sempra Energy is also presented as a noncontrolling interest at December 31, 2011 and 2010. We provide additional information concerning preferred stock in Note 12.
 
 
REVENUES
 
 
Utilities
 
Our Sempra Utilities generate revenues primarily from deliveries to their customers of electricity by SDG&E and natural gas by both SoCalGas and SDG&E and from related services. They record these revenues following the accrual method and recognize them upon delivery and performance. They also record revenue from CPUC-approved incentive awards, some of which require approval by the CPUC prior to being recognized. We provide additional discussion on utility incentive mechanisms in Note 14.
 
Under an operating agreement with the California Department of Water Resources (DWR), SDG&E acts as a limited agent on behalf of the DWR in the administration of energy contracts, including natural gas procurement functions under the DWR contracts allocated to SDG&E’s customers. The legal and financial responsibilities associated with these activities continue to reside with the DWR. Accordingly, the commodity costs associated with long-term contracts allocated to SDG&E from the DWR (and the revenues to recover those costs) are not included in our Consolidated Statements of Operations. We provide discussion on electric industry regulation related to the DWR in Note 14.
 
On a monthly basis, SoCalGas accrues natural gas storage contract revenues, which consist of storage reservation and variable charges based on negotiated agreements with terms of up to 15 years.
 
Sempra Pipelines & Storage’s natural gas utilities, Mobile Gas and Ecogas, apply GAAP for regulated utilities consistent with the Sempra Utilities.
 
Sempra Pipelines & Storage’s utilities in South America, which were consolidated beginning April 6, 2011 as we discuss in Note 3, are Chilquinta Energía and Luz del Sur. Chilquinta Energía is an electric distribution utility serving customers in the cities of Valparaiso and Viña del Mar in central Chile. Luz del Sur is an electric distribution utility in the southern zone of metropolitan Lima, Peru. The companies serve primarily regulated customers, and their revenues are based on tariffs that are set by the National Energy Commission (Comisión Nacional de Energía, or CNE) in Chile and the Energy and Mining Investment Supervisory Body (Organismo Supervisor de la Inversión en Energía y Minería, or OSINERGMIN) of the National Electricity Office under the Ministry of Energy and Mines in Peru.  
 
The tariffs charged are based on an efficient model distribution company defined by Chilean law in the case of Chilquinta Energía, and OSINERGMIN in the case of Luz del Sur. The tariffs include operation and maintenance costs, an internal rate of return on the new replacement value (Valor Nuevo de Reemplazo, or VNR) of depreciable assets, charges for the use of transmission systems, and a component for the value added by the distributor. Tariffs are designed to provide for a pass-through to customers of the main noncontrollable cost items (mainly power purchases and transmission charges), recovery of reasonable operating and administrative costs, incentives to reduce costs and make needed capital investments and a regulated rate of return on the distributor’s regulated asset base. Because the tariffs are based on a model and are intended to cover the costs of the model company, but are not based on the costs of the specific utility and may not result in full cost recovery, they do not meet the requirement necessary for treatment under applicable GAAP for regulatory accounting.
 
For Chilquinta Energía, rates for four-year periods related to distribution and transmission are reviewed separately on an alternating basis every two years. Their next review is scheduled to be completed, with tariff adjustments also going into effect, in November 2012 for distribution and November 2014 for transmission.
 
The components of tariffs above for Luz del Sur are reviewed and adjusted every four years. Their next review is scheduled to be completed, with tariff adjustments also going into effect, in November 2013.
 
The table below shows the total utilities revenues from the Sempra Utilities and Sempra Pipelines & Storage in Sempra Energy’s Consolidated Statements of Operations for each of the last three years. The revenues include amounts for services rendered but unbilled (approximately one-half month’s deliveries) at the end of each year.
 

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

As we discuss in Note 14, the SDG&E and SoCalGas core natural gas supply portfolios are combined. SoCalGas manages the combined portfolio and procures natural gas for SDG&E’s core customers. Core customers are primarily residential and small commercial and industrial customers. This core gas procurement function is considered a shared service, therefore amounts related to SDG&E are not included in SoCalGas’ Consolidated Statements of Operations.
 
We provide additional information concerning utility revenue recognition in “Regulatory Matters” above.
 
 
Energy-Related Businesses
 
Sempra Generation
 
Sempra Generation generates revenues primarily from selling electricity to governmental, public utility and wholesale power marketing entities. These revenues are recognized as the electricity is delivered. In each of 2011, 2010 and 2009, Sempra Generation’s electricity sales to the DWR accounted for a significant portion of its revenues. This contract ended September 30, 2011. Sempra Generation’s revenues also include net realized gains and losses and the net change in the fair value of unrealized gains and losses on derivative contracts for power and natural gas.
 
Sempra Pipelines & Storage
 
Sempra Pipelines & Storage’s pipeline operations in Mexico recognize revenues from the sale and transportation of natural gas as deliveries are made and from fixed capacity payments. Sempra Pipelines & Storage’s natural gas storage and transportation operations recognize revenues when they provide services in accordance with contractual agreements for the storage and transportation services. Sempra Pipelines & Storage’s revenues also include net realized gains and losses and the net change in the fair value of unrealized gains and losses on derivative contracts for natural gas.
 

Sempra LNG
 
Sempra LNG recognizes revenues from (1) the sale of LNG and natural gas as deliveries are made to counterparties and (2) from reservation and usage fees under terminal capacity agreements, nitrogen injection service agreements and tug service agreements. Sempra LNG reports revenue net of value added taxes in Mexico. Sempra LNG’s revenues also include net realized gains and losses and the net change in the fair value of unrealized gains and losses on derivative contracts for natural gas.
 
Sempra Commodities
 
On April 1, 2008, our commodities-marketing businesses, previously wholly owned subsidiaries of Sempra Energy, were sold into RBS Sempra Commodities LLP (RBS Sempra Commodities), a partnership jointly owned by Sempra Energy and The Royal Bank of Scotland. Therefore, beginning April 1, 2008, we have accounted for our earnings in the partnership under the equity method. In 2010 and early 2011, the partnership divested its principal businesses and assets. We provide more information on these matters in Notes 3 and 4.
 
RBS Sempra Commodities generated most of its revenues from trading and marketing activities in natural gas, electricity, petroleum, petroleum products, base metals and other commodities. RBS Sempra Commodities quoted bid and ask prices to end users and other market makers. It also earned trading profits as a dealer by structuring and executing transactions. Principal transaction revenues were recognized on a trade-date basis and included realized gains and losses and the net change in unrealized gains and losses.
 
RBS Sempra Commodities used derivative instruments to reduce its exposure to unfavorable changes in market prices. Non-derivative contracts were accounted for on an accrual basis and the related profit or loss was recognized as the contracts were settled.
 
 
OTHER COST OF SALES
 
Other Cost of Sales primarily includes pipeline capacity marketing costs incurred at Sempra Generation, pipeline transportation and natural gas marketing costs incurred at Sempra LNG and electrical construction costs at Sempra Pipelines & Storage.  The costs at Sempra Pipelines & Storage are related to the energy-services companies in South America that we discuss in Note 3.
 
OPERATION AND MAINTENANCE EXPENSES
 
Operation and Maintenance includes operating and maintenance costs, and general and administrative costs, which consist primarily of personnel costs, purchased materials and services, and rent. SDG&E’s and SoCalGas’ Operation and Maintenance includes litigation expense, which is shown separately on Sempra Energy’s Consolidated Statements of Operations.
 
 
FOREIGN CURRENCY TRANSLATION
 
Our operations in South America and our natural gas distribution utility in Mexico use their local currency as their functional currency. The assets and liabilities of their foreign operations are translated into U.S. dollars at current exchange rates at the end of the reporting period, and revenues and expenses are translated at average exchange rates for the year. The resulting noncash translation adjustments do not enter into the calculation of earnings or retained earnings (unless the operation is being discontinued), but are reflected in Comprehensive Income and in Accumulated Other Comprehensive Income (Loss), a component of shareholders’ equity.
 
To reflect the fluctuations in the values of functional currencies of Sempra Pipelines & Storage’s South American investments, which were accounted for under the equity method prior to April 6, 2011, the following adjustments were made to the carrying value of these investments (dollars in millions):
 
 
 
 
Upward (downward)
adjustment to investments
Investment
Currency
2011(1)
2010 
2009 
Chilquinta Energía
Chilean Peso
$
 (10)
$
 34 
$
 85 
Luz del Sur
Peruvian Nuevo Sol
 
 ― 
 
 5 
 
 13 
(1)
As discussed in Note 3, the cumulative foreign currency translation adjustment balances totaling $54 million in Accumulated Other Comprehensive Income (Loss) as of April 6, 2011 were reclassified to net income as a result of the gain on the remeasurement of our equity method investments in Chilquinta Energía and Luz del Sur during the second quarter of 2011.

Smaller adjustments have been made to other operations where the U.S. dollar is not the functional currency. We provide additional information concerning these investments in Note 4.
 
Currency transaction gains and losses in a currency other than the entity’s functional currency are included in the calculation of Other Income, Net, at Sempra Energy as follows:
 
 
Years ended December 31,
(Dollars in millions)
2011 
2010 
2009 
Currency transaction gain
$
 11 
$
 4 
$
 3 
 
TRANSACTIONS WITH AFFILIATES
 
 
Loans to Unconsolidated Affiliates
 
Sempra Pipelines & Storage has a U.S. dollar-denominated loan to Camuzzi Gas del Sur S.A., an affiliate of Sempra Pipelines & Storage’s Argentine investments which we discuss in Note 4. The loan has an $18 million principal balance outstanding plus $6 million of accumulated interest at a variable interest rate (7.377 percent at December 31, 2011). In June 2011, the maturity date of the loan was extended from June 2011 to June 30, 2012. The loan was fully reserved at December 31, 2010 and 2011.
 
 
Investments
 
Sempra Pipelines & Storage has an investment in bonds issued by Chilquinta Energía that we discuss in Note 5.
 
 
Other Affiliate Transactions
 
Sempra Energy, SDG&E and SoCalGas provide certain services to each other and are charged an allocable share of the cost of such services. Amounts due to/from affiliates are as follows:
 
AMOUNTS DUE TO AND FROM AFFILIATES AT SDG&E AND SOCALGAS
(Dollars in millions)
 
 
December 31,
 
2011 
2010 
SDG&E
 
 
 
 
Current:
 
 
 
 
    Due from SoCalGas
$
 2 
$
 11 
    Due from various affiliates
 
 65 
 
 1 
 
$
 67 
$
 12 
 
 
 
 
 
    Due to Sempra Energy
$
 14 
$
 16 
 
 
 
 
 
    Income taxes due from Sempra Energy(1)
$
 97 
$
 25 
 
 
 
 
 
SoCalGas
 
 
 
 
Current:
 
 
 
 
    Due from Sempra Energy
$
 23 
$
 60 
    Due from various affiliates
 
 17 
 
 ― 
    Due from RBS Sempra Commodities
 
 ― 
 
 3 
 
 
$
 40 
$
 63 
 
 
 
 
 
 
    Due to SDG&E
$
 2 
$
 11 
 
 
 
 
 
    Income taxes due from (to) Sempra Energy(1)
$
 17 
$
 (3)
(1)
SDG&E and SoCalGas are included in the consolidated income tax return of Sempra Energy and are allocated income tax expense from Sempra Energy in an amount equal to that which would result from the companies’ having always filed a separate return.
 
Revenues from unconsolidated affiliates at our utility businesses are as follows:
 
REVENUES FROM UNCONSOLIDATED AFFILIATES AT UTILITY BUSINESSES
(Dollars in millions)
 
Years ended December 31,
 
2011 
2010 
2009 
SDG&E
$
 7 
$
 8 
$
 8 
SoCalGas
 
 53 
 
 44 
 
 43 
 
Transactions with RBS Sempra Commodities
 
Several of our business units have engaged in transactions with RBS Sempra Commodities. As a result of the divestiture of substantially all of RBS Sempra Commodities’ businesses, transactions between our business units and RBS Sempra Commodities were assigned over time to the buyers of the joint venture businesses. The assignments of the related contracts were substantially completed by May 1, 2011.  Amounts in our Consolidated Financial Statements related to these transactions are as follows:
 
AMOUNTS RECORDED FOR TRANSACTIONS WITH RBS SEMPRA COMMODITIES
 
 
(Dollars in millions)
 
 
 
 
 
Years ended December 31,
 
 
 
2011(1)
2010
 
2009 
Revenues:
 
 
 
 
 
 
    SoCalGas
$
 ― 
$
 14 
$
 13 
    Sempra Generation
 
 4 
 
 19 
 
 11 
    Sempra Pipelines & Storage
 
 ― 
 
 ― 
 
 3 
    Sempra LNG
 
 40 
 
 247 
 
 60 
 
 
 
 
 
 
 
Cost of natural gas:
 
 
 
 
 
 
    SDG&E
$
 ― 
$
 3 
$
 4 
    SoCalGas
 
 ― 
 
 36 
 
 19 
    Sempra Generation
 
 30 
 
 87 
 
 1 
    Sempra Pipelines & Storage
 
 17 
 
 28 
 
 25 
    Sempra LNG
 
 30 
 
 255 
 
 61 
(1)
With the exception of Sempra Pipelines & Storage, whose contract with RBS Sempra Commodities expired in July 2011, amounts only include activities prior to May 1, 2011, the date by which substantially all the contracts with RBS Sempra Commodities were assigned to buyers of the joint venture businesses.
 
 
 
December 31,
 
 
 
 
 
 
 
2010 
 
 
 
 
Fixed-price contracts and other derivatives - Net Asset (Liability):
 
 
 
 
 
 
    Sempra Generation
$
 17 
 
 
 
 
    Sempra LNG
 
 (35)
 
 
 
 
        Total
$
 (18)
 
 
 
 
 
 
 
 
 
 
 
Due to unconsolidated affiliates:
 
 
 
 
 
 
    Sempra Generation
$
 11 
 
 
 
 
    Sempra LNG
 
 13 
 
 
 
 
    Sempra Commodities
 
 
 11 
 
 
 
 
        Total
$
 35 
 
 
 
 
 
 
 
 
 
 
 
Due from unconsolidated affiliates:
 
 
 
 
 
 
    SoCalGas
 
$
 3 
 
 
 
 
    Sempra Generation
 
 13 
 
 
 
 
    Sempra LNG
 
 13 
 
 
 
 
    Parent and other
 
 5 
 
 
 
 
        Total
$
 34 
 
 
 
 
 
 
 
 
 
RESTRICTED NET ASSETS
 
 
Sempra Energy Consolidated
 
As we discuss below, the Sempra Utilities have restrictions on the amount of funds that can be transferred to Sempra Energy by dividend, advance or loan as a result of conditions imposed by various regulators. Additionally, certain other Sempra Energy subsidiaries are subject to various financial and other covenants and other restrictions contained in debt and credit agreements described in Note 5 and in other agreements that limit the amount of funds that can be transferred to Sempra Energy. At December 31, 2011, Sempra Energy was in compliance with all covenants related to its debt agreements.
 
At December 31, 2011, the amount of restricted net assets of wholly owned subsidiaries of Sempra Energy, including the Sempra Utilities discussed below, that may not be distributed to Sempra Energy in the form of a loan or dividend is $4.8 billion. Although the restrictions cap the amount of funding that the various operating subsidiaries can provide to Sempra Energy, we do not believe these restrictions will have a significant impact on our ability to access cash to pay dividends.
 
As we discuss in Note 4, $78 million of Sempra Energy’s consolidated retained earnings balance represents undistributed earnings of equity method investments at December 31, 2011.
 
Significant restrictions of subsidiaries include
 
§  
Wholly owned Mobile Gas has long-term debt instruments containing restrictions relating to the payment of dividends and other distributions with respect to capital stock.  Under these restrictions, net assets of approximately $116 million are restricted at December 31, 2011.
 
§  
91-percent owned Bay Gas has long-term debt instruments containing restrictions relating to the payment of dividends and other distributions if Bay Gas does not maintain a specified debt service coverage ratio.  Bay Gas had no restricted net assets at December 31, 2011.
 
§  
50-percent owned Fowler Ridge 2 Wind Farm (Fowler Ridge 2) and Cedar Creek 2 Wind Farm (Cedar Creek 2) have debt agreements which require each joint venture to maintain reserve accounts in order to pay the projects’ debt service and operation and maintenance requirements. As a result of these requirements, total joint venture net assets of approximately $23 million at Fowler Ridge 2 and $18 million at Cedar Creek 2, respectively, are restricted at December 31, 2011. We discuss Sempra Energy guarantees associated with these requirements in Note 5.
 
§  
Peru and Mexico require domestic corporations to maintain minimum reserves for future litigation expense as a percentage of capital stock, resulting in restricted net assets of $35 million at Luz del Sur and $22 million at Sempra Energy’s Mexican subsidiaries as of December 31, 2011.
 
 
Sempra Utilities
 
The CPUC’s regulation of the Sempra Utilities’ capital structures limits the amounts that are available for dividends and loans to Sempra Energy. At December 31, 2011, Sempra Energy could have received combined loans and dividends of approximately $969 million from SoCalGas and approximately $400 million from SDG&E.
 
The payment and amount of future dividends for SDG&E and SoCalGas are within the discretion of their board of directors.  The following restrictions limit the amount of retained earnings that may be dividended or loaned to Sempra Energy from either utility:
 
§  
The CPUC requires that SDG&E’s and SoCalGas’ common equity ratios be no lower than one percentage point below the CPUC authorized percentage of each entity’s authorized capital structure, which is currently:
 
§  
49 percent at SDG&E
 
§  
48 percent at SoCalGas
 
§  
The FERC requires SDG&E to maintain a common equity ratio of 30 percent or above
 
§  
The Sempra Utilities have a combined revolving credit line that requires each utility to maintain a ratio of consolidated indebtedness to consolidated capitalization (as defined in the agreement) of no more than 65 percent, as we discuss in Note 5
 
Based upon these restrictions, $3.3 billion of SDG&E’s and $1.2 billion of SoCalGas’ net assets are restricted as of December 31, 2011 and may not be transferred to Sempra Energy.
 
 
OTHER INCOME, NET
 
Other Income, Net on the Consolidated Statements of Operations consists of the following:
 

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

 
 
 

NOTE 2. NEW ACCOUNTING STANDARDS
 

We describe below recent pronouncements that have had or may have a significant effect on our financial statements. We do not discuss recent pronouncements that are not anticipated to have an impact on or are unrelated to our financial condition, results of operations, cash flows or disclosures.
 
 
SEMPRA ENERGY, SDG&E AND SOCALGAS
 
Accounting Standards Update (ASU) 2011-04, “Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and International Financial Reporting Standards (IFRSs)” (ASU 2011-04): ASU 2011-04 amends Accounting Standards Codification (ASC) Topic 820, Fair Value Measurements and Disclosures, and provides changes in the wording used to describe the requirements for measuring fair value and disclosing information about fair value measurement.  ASU 2011-04 results in common fair value measurement and disclosure requirements under both GAAP and IFRSs.
 
ASU 2011-04 expands fair value measurement disclosures for Level 3 instruments to require
 
§  
quantitative information about the unobservable inputs
 
§  
a description of the valuation process
 
§  
a qualitative discussion about the sensitivity of the measurements
 
We will adopt ASU 2011-04 on January 1, 2012 as required and do not expect it to affect our financial position, results of operations or cash flows.  We will provide the additional disclosure in our 2012 interim financial statements.
 
ASU 2011-05, “Presentation of Comprehensive Income” (ASU 2011-05) and ASU 2011-12, “Deferral of the Effective Date for Amendments to the Presentation of Reclassifications of Items Out of Accumulated Other Comprehensive Income in Accounting Standards Update No. 2011-05” (ASU 2011-12): ASU 2011-05 amends ASC Topic 220, Comprehensive Income, and eliminates the option to report other comprehensive income and its components in the statement of changes in equity.  The ASU allows an entity an option to present the components of net income and other comprehensive income in one continuous statement, referred to as the statement of comprehensive income, or in two separate, but consecutive, statements.
 
ASU 2011-05 does not change the items that must be reported in other comprehensive income, when an item of other comprehensive income must be reclassified to net income, or the earnings per share computation.
 
ASU 2011-12 defers the requirement to separately present on the face of the financial statements reclassification adjustments for items that are reclassified from other comprehensive income to net income.
 
We will adopt ASU 2011-05 and ASU 2011-12 on January 1, 2012 and present our 2012 interim financial statements as required.
 
ASU 2011-08, “Testing Goodwill for Impairment” (ASU 2011-08): ASU 2011-08 amends ASC Topic 350, Intangibles—Goodwill and Other, to provide an option to first make a qualitative assessment of whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount before applying the two-step, quantitative goodwill impairment test.  An entity is required to perform the two-step, quantitative impairment test only if it determines that it is more likely than not that the fair value of a reporting unit is less than its carrying amount.
 
We adopted ASU 2011-08 for our annual goodwill impairment testing as of October 1, 2011.  It did not significantly affect our testing of goodwill.
 
ASU 2011-11, “Disclosures about Offsetting Assets and Liabilities” (ASU 2011-11): In order to allow for balance sheet comparison between GAAP and IFRSs, ASU 2011-11 requires enhanced disclosures related to financial assets and liabilities eligible for offsetting in the statement of financial position.  An entity will have to disclose both gross and net information about financial instruments and transactions subject to a master netting arrangement and eligible for offset, including cash collateral received and posted.
 
We will adopt ASU 2011-11 on January 1, 2013 as required and do not expect it to affect our financial position, results of operations or cash flows. We will provide the additional disclosure in our 2013 interim financial statements.
 

 

NOTE 3.  ACQUISITION AND INVESTMENT ACTIVITY
 

 
SEMPRA GENERATION
 
We provide information about investment activity at Sempra Generation in Note 4.
 
 
SEMPRA PIPELINES & STORAGE
 
 
Chilquinta Energía and Luz del Sur
 
On April 6, 2011, Sempra Pipelines & Storage acquired from AEI its interests in Chilquinta Energía in Chile and Luz del Sur in Peru, and their subsidiaries. Prior to the acquisition, Sempra Pipelines & Storage and AEI each owned 50 percent of Chilquinta Energía and approximately 38 percent of Luz del Sur. Upon completion of the acquisition, Sempra Pipelines & Storage owned 100 percent of Chilquinta Energía and approximately 76 percent of Luz del Sur, with the remaining shares of Luz del Sur held by institutional investors and the general public. As part of the transaction, Sempra Pipelines & Storage also acquired AEI’s interests in two energy-services companies, Tecnored S.A. and Tecsur S.A. The adjusted purchase price of $888 million resulted from valuing the net assets in Chile, Peru and other holding companies at $495 million, $385 million and $8 million, respectively. We paid $611 million in cash ($888 million less $245 million of cash acquired and $32 million of consideration withheld for a liability related to the purchase).
 
As part of our acquisition of AEI’s interest in Luz del Sur, we were required to launch a tender offer to the minority shareholders of Luz del Sur to purchase their shares (up to a maximum 14.73 percent interest in Luz del Sur). On August 8, 2011, we initiated a public tender offer for up to 14.73 percent of Luz del Sur’s stock that began on August 9, 2011 and concluded on September 6, 2011 at a price of $2.29 per share. The per share value, computed according to procedures established by the local securities regulatory agency, was based on an independent appraiser’s valuation of $2.22 per share as of April 6, 2011, the date of acquisition, adjusted by an interest rate factor to the value as of August 1, 2011. The interest rate factor is published daily by the Central Bank of Peru. On September 13, 2011, we purchased 18,918,954 additional Luz del Sur shares for $43 million in settlement of the mandatory public tender offer, bringing Sempra Pipelines & Storage’s ownership to 79.82 percent.  This equity transaction is presented as Purchase of Noncontrolling Interests on our Consolidated Statement of Cash Flows.
 
We expect the acquisition to be accretive to our earnings per share in 2012 and beyond, based on historically strong operating performance of the companies and assuming the continuation of sound regulatory environments within stable, growing countries. We provide additional information about Sempra Pipelines & Storage’s investments in Chilquinta Energía and Luz del Sur in Note 4.
 
We allocated the purchase price on a preliminary basis in the second quarter of 2011. In the third and fourth quarters of 2011, we adjusted the preliminary allocation for additional assets and liabilities identified, including an $11 million premium related to long-term debt at Chilquinta Energía. The retrospective application of these adjustments to prior quarters was de minimus.  During the measurement period, up to one year from the acquisition date, we may obtain additional information that allows us to more accurately allocate the purchase price.  We will make appropriate adjustments to the purchase price allocation during the measurement period as required.  At this time, we do not expect material changes to the value of the assets acquired or liabilities assumed in conjunction with this transaction as presented below.  The following table summarizes the consideration paid in the acquisition and the recognized amounts of the assets acquired and liabilities assumed, as well as the fair value at the acquisition date of the noncontrolling interests:

PURCHASE PRICE ALLOCATION
(Dollars in millions)
 
 
 
At April 6, 2011
 
 
 
 
 
 
 
 
Other
 
 
 
 
 
 
 
 
 
 
Chilean
 
Peruvian
 
holding
 
Preliminary
 
Adjust-
 
Adjusted
 
 
 entities
 
entities
 
companies
 
Allocation
 
ments
 
Allocation
Fair value of businesses acquired:
 
 
 
 
 
 
 
 
 
 
 
 
 
Cash consideration (fair value of total
 
 
 
 
 
 
 
 
 
 
 
 
 
    consideration)
$
 495 
$
 385 
$
 8 
$
 888 
$
 ― 
$
 888 
 
Fair value of equity method
 
 
 
 
 
 
 
 
 
 
 
 
 
    investments immediately prior to
 
 
 
 
 
 
 
 
 
 
 
 
 
    the acquisition
 
 495 
 
 385 
 
 2 
 
 882 
 
 ― 
 
 882 
 
Fair value of noncontrolling interests
 
 37 
 
 242 
 
 ― 
 
 279 
 
 ― 
 
 279 
Total fair value of businesses acquired
 
 1,027 
 
 1,012 
 
 10 
 
 2,049 
 
 ― 
 
 2,049 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Recognized amounts of identifiable assets
 
 
 
 
 
 
 
 
 
 
 
 
 
acquired and liabilities assumed:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Cash
 
 219 
 
 22 
 
 4 
 
 245 
 
 ― 
 
 245 
 
 
Accounts receivable(1)
 
 159 
 
 101 
 
 6 
 
 266 
 
 (2)
 
 264 
 
 
Other current assets
 
 20 
 
 19 
 
 ― 
 
 39 
 
 2 
 
 41 
 
 
Property, plant and equipment
 
 554 
 
 931 
 
 ― 
 
 1,485 
 
 1 
 
 1,486 
 
 
Other noncurrent assets
 
 66 
 
 ― 
 
 ― 
 
 66 
 
 1 
 
 67 
 
 
Accounts payable
 
 (79)
 
 (59)
 
 ― 
 
 (138)
 
 6 
 
 (132)
 
 
Short-term debt and current portion
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    of long-term debt
 
 ― 
 
 (47)
 
 ― 
 
 (47)
 
 ― 
 
 (47)
 
 
Other current liabilities
 
 (29)
 
 (56)
 
 ― 
 
 (85)
 
 (4)
 
 (89)
 
 
Long-term debt
 
 (294)
 
 (179)
 
 ― 
 
 (473)
 
 (11)
 
 (484)
 
 
Other noncurrent liabilities
 
 (90)
 
 (178)
 
 ― 
 
 (268)
 
 (9)
 
 (277)
Total identifiable net assets
 
 526 
 
 554 
 
 10 
 
 1,090 
 
 (16)
 
 1,074 
Goodwill
$
 501 
$
 458 
$
 ― 
$
 959 
$
 16 
$
 975 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Acquisition-related costs (included in Other
 
 
 
 
 
 
 
 
 
 
 
 
 
Operation and Maintenance expense on
 
 
 
 
 
 
 
 
 
 
 
 
 
the Consolidated Statement of
 
 
 
 
 
 
 
 
 
 
 
 
 
Operations for the year ended
 
 
 
 
 
 
 
 
 
 
 
 
 
December 31, 2011)
$
 1 
$
 1 
$
 ― 
$
 2 
$
 ― 
$
 2 
(1)
We expect acquired accounts receivable to be substantially realizable in cash. Accounts receivable are net of collection allowances of $6 million for Chile and $1 million for Peru.

Our results for the year ended December 31, 2011 include a $277 million gain (both pretax and after-tax) related to the remeasurement of equity method investments, included as Remeasurement of Equity Method Investments on our Consolidated Statement of Operations. We calculated the gain as the difference between the acquisition-date fair value ($882 million) and the book value ($605 million) of our equity interests in Chilquinta Energía and Luz del Sur immediately prior to the acquisition date. This book value of our equity interests included currency translation adjustment balances in Accumulated Other Comprehensive Income (Loss). The valuation techniques we used to allocate the purchase price to the businesses included discounted cash flow analysis and the market multiple approach (enterprise value to earnings before interest, taxes, depreciation and amortization (EBITDA)). Our assumptions for these measures included estimated future cash flows, use of appropriate discount rates, market trading multiples and market transaction multiples. Discount rates used reflect consideration of risk free rates, as well as country and company risk. Methodologies used to determine fair values of material assets as of the date of the acquisition included
 
§  
the replacement cost approach for property, plant and equipment; and
 
§  
goodwill associated primarily with the value of residual future cash flows that we believe these businesses will generate, to be tested annually for impairment.  For income tax purposes, none of the goodwill recorded is deductible in Chile, Peru or the United States.
 
For substantially all other assets and liabilities, our analysis of fair value factors indicated that book value approximates fair value. We valued noncontrolling interests based on the fair value of tangible assets and an allocation of goodwill based on relative enterprise value.
 
Our Consolidated Statement of Operations includes 100 percent of the acquired companies’ revenues, net income and earnings from the date of acquisition of $1.1 billion, $160 million and $135 million, respectively, for the year ended December 31, 2011. These amounts do not include the remeasurement gain.
 
Following are pro forma revenues and earnings for Sempra Energy had the acquisition occurred on January 1, 2010, which primarily reflect the incremental increase to revenues and earnings from our increased ownership and consolidation of the entities acquired. Although some short-term debt borrowings may have resulted from the actual acquisition in 2011, we have not assumed any additional interest expense in the pro forma impact on earnings below, as the amounts would be immaterial due to the low interest rates available to us on commercial paper.  The pro forma amounts do not include the impact of the increased ownership in Luz del Sur resulting from the tender offer completed in September 2011 discussed above.
 
 
 
Years ended December 31,
(Dollars in millions)
2011 
2010 
Revenues
$
 10,379 
$
 10,277 
Earnings(1)
 
 1,105 
 
 1,092 
(1)
Pro forma earnings for 2010 include the $277 million gain related to the remeasurement of equity method investments, and accordingly, pro forma earnings for 2011 exclude the gain.
The companies use their local currency, the Chilean Peso or the Peruvian Nuevo Sol, as their functional currency, and we account for them as discussed above in Note 1 under “Foreign Currency Translation.”
 
 
Acquisition of Mexican Pipeline and Natural Gas Infrastructure
 
On April 30, 2010, Sempra Pipelines & Storage completed an acquisition resulting in the purchase of the Mexican pipeline and natural gas infrastructure assets of El Paso Corporation for $307 million ($292 million, net of cash acquired).
 
The acquisition consists of El Paso Corporation’s wholly owned natural gas pipeline and compression assets in the Mexican border state of Sonora and its 50-percent interest in Gasoductos de Chihuahua, a joint venture with PEMEX, the Mexican state-owned oil company. The joint venture operates two natural gas pipelines and a propane system in northern Mexico. The acquisition expands our scale and geographic footprint in a strong growth region in Mexico. The pipeline assets are backed substantially by long-term contracts with a history of consistent revenue streams, allowing us to expand our natural gas infrastructure business in northern Mexico.
 

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

(Dollars in millions)
At April 30, 2010
Cash consideration (fair value of total consideration)
$
 307 
Recognized amounts of identifiable assets acquired and liabilities assumed:
 
 
 
Cash
 
 15 
 
Accounts receivable
 
 4 
 
Investment in equity method investee
 
 256 
 
Property, plant & equipment
 
 25 
 
Other liabilities
 
 (11)
Total identifiable net assets
 
 289 
Goodwill(1)
$
 18 
 
 
 
 
 
Acquisition-related costs (included in Other Operation and Maintenance expense
 
 
 
on the Consolidated Statement of Operations for the year ended
 
 
 
December 31, 2010)
$
 1 
(1)
The goodwill, which represents the residual of the consideration paid over the identifiable net assets, is assigned to the Sempra Pipelines & Storage segment and is attributed to the strategic value of the transaction.  None of the goodwill recorded is deductible in Mexico for income tax purposes.
 
Included in our Consolidated Statements of Operations are revenues and earnings of $10 million and $33 million, respectively, for the year ended December 31, 2011 and $6 million and $21 million, respectively, for the period May 1, 2010 to December 31, 2010 related to the assets acquired from El Paso Corporation. Proforma impacts on revenues and earnings for Sempra Energy had the acquisition occurred on January 1, 2009 were: additional revenues of $3 million and earnings of $7 million in 2010 and additional revenues of $10 million and earnings of $24 million for 2009.
 
 
Purchase of Noncontrolling Interest in Mississippi Hub
 
In October 2008, Sempra Pipelines & Storage acquired EnergySouth, Inc., an energy-services holding company based in Mobile, Alabama.  The principal holdings of EnergySouth, Inc. were EnergySouth Midstream and Mobile Gas.  In December 2008, EnergySouth Midstream changed its name to Sempra Midstream.
 
Sempra Midstream owned 60 percent of Mississippi Hub through December 31, 2008. On January 16, 2009, Sempra Midstream purchased the remaining 40-percent ownership interest of Mississippi Hub for $94 million in cash.
 
 
Rockies Express
 
We discuss Sempra Pipelines & Storage’s investment in Rockies Express Pipeline LLC (Rockies Express) in Note 4.
 
 
SEMPRA COMMODITIES
 
In 2010 and early 2011, Sempra Energy and The Royal Bank of Scotland plc (RBS) sold substantially all of the businesses and assets within RBS Sempra Commodities, a partnership formed in 2008.
 
We provide additional information concerning RBS Sempra Commodities and these transactions in Notes 4 and 5.
 

 

NOTE 4. INVESTMENTS IN UNCONSOLIDATED ENTITIES
 

We generally account for investments under the equity method when we have an ownership interest of 20 to 50 percent. In these cases, our pro rata shares of the subsidiaries’ net assets are included in Other Investments and in Investment in RBS Sempra Commodities LLP on the Consolidated Balance Sheets. These investments are adjusted for our share of each investee’s earnings or losses, dividends, and other comprehensive income or loss.
 
The carrying value of unconsolidated subsidiaries is evaluated for impairment under the GAAP provisions for equity method investments. We account for certain investments in housing partnerships made before May 19, 1995 under the cost method, whereby the costs were amortized over ten years down to the expected residual value.
 
We summarize our investment balances and earnings below:
 
EQUITY METHOD AND OTHER INVESTMENTS ON THE CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
 
 
Investment at December 31,
 
 
2011 
2010 
Parent and other:
 
 
 
 
    Investment in RBS Sempra Commodities LLP
$
 126 
$
 787 
Other equity method investments:
 
 
 
 
    Sempra Generation:
 
 
 
 
        Auwahi Wind
$
 11 
$
 ― 
        Cedar Creek 2 Wind Farm
 
 95 
 
 113 
        Fowler Ridge 2 Wind Farm
 
 50 
 
 72 
        Flat Ridge 2 Wind Farm
 
 146 
 
 ― 
        Mehoopany Wind Farm
 
 88 
 
 ― 
    Sempra Pipelines & Storage:
 
 
 
 
        Rockies Express
 
 800 
 
 854 
        Gasoductos de Chihuahua
 
 302 
 
 275 
        Chilquinta Energía(1)
 
 ― 
 
 432 
        Luz del Sur(1)
 
 ― 
 
 216 
    Parent and other:
 
 
 
 
        Housing partnerships
 
 11 
 
 16 
Total other equity method investments
 
 1,503 
 
 1,978 
Cost method investments - housing partnerships
 
 10 
 
 12 
Other(2)
 
 32 
 
 174 
Total
$
 1,545 
$
 2,164 
(1)
Sempra Pipelines & Storage’s interests in Chilquinta Energía and Luz del Sur are no longer recorded as equity method investments, but are consolidated effective April 6, 2011 (discussed below and in Note 3).
(2)
Other includes Sempra Pipelines & Storage’s investments in bonds, which include $57 million in Chilquinta Energía bonds at December 31, 2010 (discussed in Note 5); $21 million and $117 million in industrial development bonds at Mississippi Hub at December 31, 2011 and 2010, respectively (discussed in Note 5); and $11 million in real estate investments held by Sempra Pipelines & Storage at December 31, 2011.


EQUITY METHOD INVESTMENTS ON THE CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
 
 
Years ended December 31,
 
 
2011 
2010 
2009 
Earnings (losses) recorded before income tax:
 
 
 
 
 
 
Sempra Generation:
 
 
 
 
 
 
    Fowler Ridge 2 Wind Farm
$
 (4)
$
 1 
$
 1 
    Cedar Creek 2 Wind Farm
 
 (2)
 
 ― 
 
 ― 
    Elk Hills Power
 
 ― 
 
 (13)
 
 (3)
Sempra Pipelines & Storage:
 
 
 
 
 
 
    Rockies Express
 
 43 
 
 43 
 
 50 
Parent and other:
 
 
 
 
 
 
    RBS Sempra Commodities LLP
 
 (24)
 
 (314)
 
 463 
All other:
 
 
 
 
 
 
    Housing partnerships
 
 (4)
 
 (9)
 
 (12)
 
 
$
 9 
$
 (292)
$
 499 
 
 
 
 
 
 
 
 
Earnings (losses) recorded net of income tax:
 
 
 
 
 
 
Sempra Pipelines & Storage:
 
 
 
 
 
 
    Sodigas Pampeana and Sodigas Sur
$
 (1)
$
 (44)
$
 7 
    Gasoductos de Chihuahua
 
 29 
 
 19 
 
 ― 
    Chilquinta Energía(1)
 
 12 
 
 33 
 
 23 
    Luz del Sur(1)
 
 12 
 
 41 
 
 38 
 
 
$
 52 
$
 49 
$
 68 
(1)
These investments were accounted for under the equity method until April 6, 2011, when they became consolidated entities upon our acquisition of additional ownership interests.
 
Our share of the undistributed earnings of equity method investments was $78 million and $570 million at December 31, 2011 and 2010, respectively. Our undistributed earnings decreased in 2011 due to our consolidation of Chilquinta Energía and Luz del Sur. The December 31, 2011 balance also does not include remaining distributions of $126 million associated with our investment in RBS Sempra Commodities, which we expect to receive from the partnership in 2012.  However, minor amounts may be retained by the partnership beyond 2012 to help offset unanticipated future general and administrative costs necessary to complete the dissolution of the partnership.
 
Equity method goodwill related to our unconsolidated subsidiaries located in Mexico and in South America (prior to the acquisition of AEI’s interests in Chilquinta Energía and Luz del Sur, as discussed in Note 3), is included in Other Investments on the Sempra Energy Consolidated Balance Sheets. These amounts, before foreign currency translation adjustments, were $64 million at December 31, 2011 and $317 million at December 31, 2010. Including foreign currency translation adjustments, these amounts were
 
§  
$64 million at December 31, 2011
 
§  
$333 million at December 31, 2010
 
We discuss our equity method investments below.
 
 
SEMPRA GENERATION
 
Sempra Generation accounts for its investments in all of the following projects using the equity method.
 
In December 2011, Sempra Generation invested $146 million in a joint venture with BP Wind Energy, a wholly owned subsidiary of BP p.l.c., to develop the planned 419-MW Flat Ridge 2 Wind Farm project near Wichita, Kansas.
 
In December 2011, Sempra Generation invested $88 million in a joint venture with BP Wind Energy to develop the planned 141-MW Mehoopany Wind Farm project near Wyoming County, Pennsylvania.
 
In October 2011, Sempra Generation formed a joint venture with BP Wind Energy to develop the Auwahi Wind project in the southeastern region of Maui, a project that was previously wholly owned by Sempra Generation.
 
The 550-MW Elk Hills Power (Elk Hills) plant located near Bakersfield, California began commercial operations in July 2003. On December 31, 2010, Sempra Generation sold its 50-percent interest to Occidental Petroleum Corporation, Inc. for a cash purchase price plus year-end cash distribution totaling $179 million. In connection with the sale, Sempra Generation recorded a $10 million pretax loss that is included in Equity Earnings (Losses), Before Income Tax — Other on the Consolidated Statement of Operations for the year ended December 31, 2010.
 
In October 2010, Sempra Generation invested $209 million to become an equal partner with BP Wind Energy to develop the 250-MW Cedar Creek 2 project near New Raymer, Colorado, which became operational in June 2011.  Upon obtaining a construction loan in December 2010, the joint venture returned $96 million of Sempra Generation’s investment.
 
During 2009, Sempra Generation invested $235 million to become an equal partner with BP Wind Energy to develop the 200-MW Fowler Ridge 2 project near Indianapolis, Indiana, which became operational in December 2009.  In August 2010, Sempra Generation received a $180 million return of capital from Fowler Ridge 2.
 
We discuss Cedar Creek 2 and Fowler Ridge 2 further in Note 5.
 
 
SEMPRA PIPELINES & STORAGE
 
As discussed in Note 3, on April 6, 2011, Sempra Pipelines & Storage acquired from AEI its interests in Chilquinta Energía in Chile and Luz del Sur in Peru, and their subsidiaries.  Prior to the acquisition, Sempra Pipelines & Storage and AEI each owned 50 percent of Chilquinta Energía and approximately 38 percent of Luz del Sur.  Chilquinta Energía and Luz del Sur are consolidated effective April 6, 2011 and are no longer recorded as equity method investments.
 
Sempra Pipelines & Storage owns a 25-percent interest in Rockies Express, a partnership that operates a natural gas pipeline, the Rockies Express Pipeline (REX), that links producing areas in the Rocky Mountain region to the upper Midwest and the eastern United States. Kinder Morgan Energy Partners, L.P. (KMP) and ConocoPhillips (Conoco) own the remaining interests of 50 percent and 25 percent, respectively. Our total investment in Rockies Express is accounted for as an equity method investment.  We made investments in Rockies Express of $65 million in 2010 and $625 million in 2009.
 
Sempra Pipelines & Storage owns a 50-percent interest in Gasoductos de Chihuahua, a joint venture with PEMEX. The joint venture operates two natural gas pipelines and a propane system in northern Mexico. Sempra Pipelines & Storage acquired its investment in Gasoductos de Chihuahua as part of the purchase of Mexican pipeline and natural gas infrastructure assets that we discuss in Note 3.
 
Sempra Pipelines & Storage owns 43 percent of two Argentine natural gas utility holding companies, Sodigas Pampeana and Sodigas Sur. As a result of the devaluation of the Argentine peso at the end of 2001 and subsequent changes in the value of the peso, Sempra Pipelines & Storage reduced the carrying value of its investment by a cumulative total of $270 million as of December 31, 2011. These noncash adjustments, based on fluctuations in the value of the Argentine peso, did not affect earnings, but were recorded in Comprehensive Income and Accumulated Other Comprehensive Income (Loss). The Argentine economic decline and government responses (including Argentina’s unilateral, retroactive abrogation of utility agreements early in 2002) continue to adversely affect the operations of these Argentine utilities. In 2002, Sempra Pipelines & Storage initiated arbitration proceedings at the International Center for the Settlement of Investment Disputes (ICSID) under the 1994 Bilateral Investment Treaty between the United States and Argentina for recovery of the diminution of the value of its investments that has resulted from Argentine governmental actions. In September 2007, the tribunal awarded us compensation of $172 million, which included interest up to the award date. In January 2008, Argentina filed an action at the ICSID seeking to annul the award. In June 2010, the Annulment Committee granted Argentina’s petition for annulment of the award. This action did not impact our earnings, as we did not record the original award pending assurance of collectability. On November 3, 2010, Sempra Pipelines & Storage resubmitted arbitration proceedings against Argentina before the ICSID on the same and similar grounds as the 2002 filing.
 
In a separate but related proceeding related to our political risk insurance policy, we negotiated a $48 million settlement that was collected in September 2010. The proceeds from the settlement are reported in Other Income, Net, on the Consolidated Statement of Operations for the year ended December 31, 2010.
 
In December 2006, we decided to sell our Argentine investments, and we continue to actively pursue their sale. We adjusted our investments to estimated fair value and recorded a noncash impairment charge to 2006 earnings of $221 million. In September 2010, we concluded that, although the ICSID claim had been annulled as discussed above, rate increases sought in Argentina would continue to be delayed. We believe this continued uncertainty has impacted the fair value of our net investment in the two Argentine companies, and recorded a noncash impairment charge of $24 million in the third quarter of 2010. The Sodigas Pampeana and Sodigas Sur fair value was significantly impacted by unobservable inputs (i.e., Level 3 inputs) as defined by the accounting guidance for fair value measurements, which we discuss in Note 11. The inputs included discount rates and estimated future cash flows. Such cash flows considered the value of those businesses with positive cash flows, the value of the non-operating assets, and the probability-weighted value of anticipated rate increases, considering both the timing and magnitude of such increases. In the fourth quarter of 2010, based on our continuing intention to sell the investments and recent comparable transactions in the Argentine energy market, we recorded an additional noncash impairment charge of $20 million. Also in the fourth quarter of 2010, we recorded an income tax benefit of $15 million related to the impairment charges. These pretax adjustments to fair value are reported in Equity Earnings, Net of Income Tax, while the related tax benefit is reported in Income Tax Expense on the Consolidated Statement of Operations for the year ended December 31, 2010.
 
 
RBS SEMPRA COMMODITIES
 
RBS Sempra Commodities is a United Kingdom limited liability partnership formed by Sempra Energy and RBS in 2008 to own and operate the commodities-marketing businesses previously operated through wholly owned subsidiaries of Sempra Energy. We account for our investment in RBS Sempra Commodities under the equity method.  Our share of partnership earnings is reported in the Parent and Other business unit. Prior to September 1, 2010, subject to certain limited exceptions, partnership pretax income was allocated each year as follows:
 
§  
First, we received a preferred 15-percent return on our adjusted equity capital.
 
§  
Next, RBS received a preferred 15-percent return on any capital in excess of capital attributable to us that was required by the U.K. Financial Services Authority to be maintained by RBS in respect of the operations of the partnership.
 
§  
Next, we received 70 percent of the next $500 million in pretax income; RBS received the remaining 30 percent.
 
§  
Then, we received 30 percent and RBS received 70 percent of any remaining pretax income.
 
§  
Any losses of the partnership were shared equally between us and RBS.
 
Subsequent to September 1, 2010, partnership pretax income or loss is allocated equally between us and RBS.
 
Pretax equity earnings (losses) from RBS Sempra Commodities were $(24) million, $(314) million, and $463 million for the years ended December 31, 2011, 2010 and 2009, respectively. The partnership income that is distributable to us on an annual basis is computed on the partnership’s basis of accounting, IFRS, as adopted by the European Union. For the year ended December 31, 2011, our share of net loss on an IFRS basis was $30 million.  For the years ended December 31, 2010, and 2009 our share of distributable income, on an IFRS basis, was $53 million and $300 million, respectively. Included in our pretax equity losses are impairment charges of $16 million in 2011 and $305 million in 2010.  These impairments resulted from adjustments to the carrying value of our investment in the partnership at certain reporting dates.  We recorded the $305 million charge ($139 million after-tax) to reduce the investment in the partnership in the third quarter of 2010, as projected cash distributions from RBS Sempra Commodities, including proceeds from the sale of the partnership’s businesses and net of expected transition costs, were not expected to fully recover the goodwill included in the carrying value of our investment in the partnership.  We recorded a pretax noncash charge of $16 million ($10 million after-tax) in the third quarter of 2011 to further reduce our investment, primarily to reflect additional amounts incurred to conclude the sales of the partnership’s businesses.  These charges are included in Equity Earnings (Losses), Before Income Tax — RBS Sempra Commodities LLP, on our Consolidated Statements of Operations.  In 2011 and 2010, the fair value of our investment in RBS Sempra Commodities was significantly impacted by unobservable inputs (i.e. Level 3 inputs) as defined by the accounting guidance for fair value measurements, which we discuss in Note 11.  The inputs included estimated future cash distributions expected from the partnership, excluding the impact of costs anticipated for transactions that had not closed at the time of fair value measurement.  The investment balance of $126 million at December 31, 2011 reflects remaining distributions expected to be received from the partnership in 2012, although minor amounts may be retained by the partnership beyond 2012 to help offset unanticipated future general and administrative costs necessary to complete the dissolution of the partnership.
 
In November 2009, our partner in the joint venture, RBS, announced its intention to divest its interest in RBS Sempra Commodities in connection with a directive from the European Commission to dispose of certain assets. In February 2010, Sempra Energy, RBS and the partnership entered into an agreement with J.P. Morgan Ventures Energy Corporation (J.P. Morgan Ventures), a unit of J.P. Morgan Chase & Co. (JP Morgan), for J.P. Morgan Ventures to purchase the global metals and oil businesses and the European natural gas and power business from the joint venture. This transaction was completed on July 1, 2010, and we received our share of the proceeds in the third quarter of 2010. The purchase price was $1.6 billion, and our share of the proceeds was approximately $1 billion, including distributions of 2009 partnership income attributable to the businesses sold, which were $134 million of the $198 million in distributions we received in April 2010 discussed below.
 
This sale to J.P. Morgan Ventures did not include RBS Sempra Commodities’ North American power and natural gas trading businesses and its retail energy solutions business. In September 2010, Noble Group Ltd. (Noble Group) agreed to acquire the U.S. retail commodity marketing business of the RBS Sempra Commodities joint venture for $318 million in cash, plus assumption of all debt, and the transaction closed on November 1, 2010. In October 2010, J.P. Morgan Ventures agreed to purchase most of the remaining assets of RBS Sempra Commodities. The assets sold included the joint venture’s wholesale natural gas and power trading agreements, as well as over-the-counter and exchange-traded transactions, with counterparties across North America.  This transaction closed on December 1, 2010 and essentially completed the divestiture of the joint venture’s principal businesses and assets. In February 2011, the partnership’s remaining trading systems and certain residual assets were sold to Société Générale.  Distributions in 2010 related to the completed sales transactions were $849 million.
 
On April 15, 2011, we and RBS entered into a letter agreement (Letter Agreement) which amended certain provisions of the agreements that formed RBS Sempra Commodities.  The Letter Agreement addresses the wind-down of the partnership and the distribution of the partnership’s remaining assets.  In accordance with the Letter Agreement, we received distributions of $623 million in 2011.  These distributions included sales proceeds and our portion of 2010 distributable income totaling $651 million, less amounts to settle certain liabilities that we owed to RBS of $28 million.  We received cash distributions of earnings from the partnership of $198 million and $407 million in 2010 and 2009, respectively. The Letter Agreement affirms that RBS Sempra Commodities will consider additional distributions of capital after taking into account various factors including available cash, the need for prudent reserves, potential payouts to the purchasers of the partnership’s businesses, and any accrued or projected future operating losses or other wind-down expenses of the partnership.  At December 31, 2011, the transfer of trading accounts to the buyers of the businesses, including J.P. Morgan Ventures, is essentially complete, including the collection of accounts receivable and trading margin, as applicable.  Accordingly, cash availability is not significantly impacted by remaining trading accounts.  Under the Letter Agreement, future distributions will generally be made 51 percent to RBS, and 49 percent to us. The Letter Agreement also allows RBS Sempra Commodities to make capital calls to us, subject to certain limits, if necessary to support the remaining operations, for other liabilities or for other payments owed in connection with the sales transactions (subject to additional limitations). We do not anticipate any such capital calls.
 
In connection with the Letter Agreement described above, we also released RBS from its indemnification obligations with respect to the items for which JP Morgan has agreed to indemnify us.
 
The following table shows summarized financial information for RBS Sempra Commodities (on a GAAP basis):
 

RBS SEMPRA COMMODITIES SUMMARIZED FINANCIAL INFORMATION
 
 
(Dollars in millions)
 
 
 
Years ended December 31,
 
 
2011 
 
2010 
 
2009 
Gross revenues and fee income
$
 59 
$
 1,028 
$
 2,179 
Gross profit
 
 8 
 
 553 
 
 1,461 
Partnership net (loss) income
 
 (14)
 
 (169)
 
 639 
 
 
 
 
 
 
 
 
At December 31,
 
 
 
2011 
2010 
 
Current assets
$
 389 
$
 4,522 
 
 
Noncurrent assets
 
 2 
 
 27 
 
 
Current liabilities
 
 152 
 
 2,898 
 
 
Members’ capital
 
 239 
 
 1,651 
 
 
 
SEMPRA FINANCIAL
 
Prior to June 2006, Sempra Financial (a former Sempra Energy business unit) invested as a limited partner in affordable-housing properties. Sempra Financial’s portfolio included 1,300 properties throughout the United States that provided income tax benefits (primarily from income tax credits). In June 2006, Sempra Financial effectively sold the majority of its interests in affordable-housing projects to an unrelated party subject to certain guarantees. Because of the guarantees, the transaction was recorded as a financing transaction rather than as a sale, and we continue to consolidate the investments in the housing partnerships. The transaction almost completely eliminated the income tax benefits from the investments.
 

OTHER EQUITY METHOD INFORMATION
 
We present aggregated information below for:
 
§  
Chilquinta Energía (prior to acquisition in April 2011)
 
§  
Luz del Sur (prior to acquisition in April 2011)
 
§  
Auwahi Wind
 
§  
Cedar Creek 2
 
§  
Fowler Ridge 2
 
§  
Flat Ridge 2 Wind Farm
 
§  
Mehoopany Wind Farm
 
§  
Elk Hills Power (through December 31, 2010)
 
§  
Gasoductos de Chihuahua
 
§  
Rockies Express
 
§  
Sodigas Pampeana and Sodigas Sur
 
§  
Sempra Energy’s housing partnerships (accounted for under the equity method)
 
OTHER EQUITY METHOD INFORMATION
(Dollars in millions)
 
 
Years ended December 31,
 
 
2011 
2010 
2009 
Gross revenues
$
 798 
$
 1,829 
$
 1,433 
Gross profit
 
 391 
 
 728 
 
 529 
Income from operations
 
 189 
 
 332 
 
 224 
Gain on sale of assets
 
 4 
 
 2 
 
 1 
Net income
 
 155 
 
 256 
 
 192 
 
 
 
 
 
 
 
 
 
 
 
 
At December 31,
 
 
 
 
2011 
2010 
Current assets
$
 506 
$
 1,372 
Noncurrent assets
 
 2,750 
 
 4,264 
Current liabilities
 
 234 
 
 503 
Noncurrent liabilities
 
 750 
 
 1,458 


 

NOTE 5. DEBT AND CREDIT FACILITIES
 

 
COMMITTED LINES OF CREDIT
 
At December 31, 2011, Sempra Energy Consolidated had $3.8 billion in committed lines of credit to provide liquidity and to support commercial paper and variable-rate demand notes, the major components of which we detail below. Available unused credit on these lines at December 31, 2011 was $2.7 billion.
 
 
Sempra Energy
 
Sempra Energy has a $1 billion, four-year syndicated revolving credit agreement expiring in October 2014. Citibank, N.A. serves as administrative agent for the syndicate of 23 lenders. No single lender has greater than a 7-percent share.
 
Borrowings bear interest at benchmark rates plus a margin that varies with market index rates and Sempra Energy’s credit ratings. The facility requires Sempra Energy to maintain a ratio of total indebtedness to total capitalization (as defined in the agreement) of no more than 65 percent at the end of each quarter. The actual ratio at December 31, 2011, calculated as defined in the agreement, was 50.9 percent. The facility also provides for issuance of up to $400 million of letters of credit on behalf of Sempra Energy with the amount of borrowings otherwise available under the facility reduced by the amount of outstanding letters of credit.
 
At December 31, 2011, Sempra Energy had $8 million of variable-rate demand notes outstanding supported by the facility.
 
 
Sempra Global
 
Sempra Global has a $2 billion, four-year syndicated revolving credit agreement expiring in October 2014. Citibank, N.A. serves as administrative agent for the syndicate of 23 lenders. No single lender has greater than a 7-percent share.
 
Sempra Energy guarantees Sempra Global’s obligations under the credit facility. Borrowings bear interest at benchmark rates plus a margin that varies with market index rates and Sempra Energy’s credit ratings. The facility requires Sempra Energy to maintain a ratio of total indebtedness to total capitalization (as defined in the agreement) of no more than 65 percent at the end of each quarter.
 
At December 31, 2011, Sempra Global had $821 million of commercial paper outstanding supported by the facility. At December 31, 2011 and 2010, respectively, $400 million and $800 million of commercial paper outstanding is classified as long-term debt based on management’s intent and ability to maintain this level of borrowing on a long-term basis either supported by this credit facility or by issuing long-term debt. This classification has no impact on cash flows.
 
 
Sempra Utilities
 
SDG&E and SoCalGas have a combined $800 million, four-year syndicated revolving credit agreement expiring in October 2014. JPMorgan Chase Bank serves as administrative agent for the syndicate of 22 lenders. No single lender has greater than a 7-percent share. The agreement permits each utility to individually borrow up to $600 million, subject to a combined limit of $800 million for both utilities. It also provides for the issuance of letters of credit on behalf of each utility subject to a combined letter of credit commitment of $200 million for both utilities. The amount of borrowings otherwise available under the facility is reduced by the amount of outstanding letters of credit.
 
Borrowings under the facility bear interest at benchmark rates plus a margin that varies with market index rates and the borrowing utility’s credit ratings. The agreement requires each utility to maintain a ratio of total indebtedness to total capitalization (as defined in the agreement) of no more than 65 percent at the end of each quarter. The actual ratios for SDG&E and SoCalGas at December 31, 2011, calculated as defined in the agreement, were 49.2 percent and 37.6 percent, respectively.
 
Each utility’s obligations under the agreement are individual obligations, and a default by one utility would not constitute a default by the other utility or preclude borrowings by, or the issuance of letters of credit on behalf of, the other utility.
 
At December 31, 2011, SDG&E and SoCalGas had no outstanding borrowings and SDG&E had $237 million variable-rate demand notes outstanding supported by the facility. Available unused credit on the lines at December 31, 2011 was $363 million at SDG&E and $563 million at SoCalGas. SoCalGas’ availability reflects the impact of SDG&E’s use of the combined credit available on the line.
 

GUARANTEES
 
 
RBS Sempra Commodities
 
As we discuss in Note 4, in 2010 and early 2011, Sempra Energy, RBS and RBS Sempra Commodities sold substantially all of the businesses and assets within the partnership in four separate transactions. In connection with each of these transactions, the buyers were, subject to certain qualifications, obligated to replace any guarantees that we had issued in connection with the applicable businesses sold with guarantees of their own. At December 31, 2011, the buyers have substantially completed this process for those counterparties with existing, open positions. For those guarantees which have not been replaced, the buyers are obligated to indemnify us in accordance with the applicable transaction documents for any claims or losses in connection with the guarantees that we issued associated with the businesses sold. We provide additional information in Note 1.
 
At December 31, 2011, RBS Sempra Commodities no longer requires significant working capital support. However, we have provided back-up guarantees for a portion of RBS Sempra Commodities’ remaining trading obligations.  A few of these back-up guarantees may continue for a prolonged period of time. RBS has fully indemnified us for any claims or losses in connection with these arrangements, with the exception of those obligations for which JP Morgan has agreed to indemnify us. We discuss the indemnification release in Note 4.
 
RBS Sempra Commodities’ net trading liabilities supported by Sempra Energy’s guarantees at December 31, 2011 were $1 million, consisting of guaranteed trading obligations net of collateral. The amount of guaranteed net trading liabilities varies from day to day with the value of the trading obligations and related collateral.
 
 
Other Guarantees
 
Sempra Generation and BP Wind Energy currently hold 50-percent interests in Fowler Ridge 2 and Cedar Creek 2. After completion of these projects and obtaining term financing in 2010, proceeds from the term loans were used to return $180 million and $95 million, respectively, of each owner’s investments in the joint venture. The term loan of $348 million obtained by Fowler Ridge 2 expires in August 2022, and the $275 million term loan obtained by Cedar Creek 2 expires in June 2029. The term loan agreements require Sempra Generation and BP Wind Energy to return cash to the projects in the event that the projects do not meet certain cash flow criteria or in the event that the projects’ debt service and operation and maintenance reserve accounts are not maintained at specific thresholds. Sempra Generation recorded liabilities of $9 million in 2010 and $3 million in 2011 for the fair value of its obligations associated with the cash flow requirements, which constitute guarantees. The liabilities are being amortized over their expected lives. The outstanding loans are not guaranteed by the partners.
 
 
WEIGHTED AVERAGE INTEREST RATES
 
The weighted average interest rates on the total short-term debt outstanding at Sempra Energy were 0.93 percent and 0.46 percent at December 31, 2011 and December 31, 2010, respectively. The weighted average interest rates at December 31, 2011 and 2010 include interest rates for commercial paper borrowings classified as long-term, as we discuss above.
 
 
LONG-TERM DEBT
 
The following tables show the detail and maturities of long-term debt outstanding:
 

LONG-TERM DEBT
(Dollars in millions)
 
 
December 31,
 
 
2011 
2010 
SDG&E
 
 
 
 
First mortgage bonds:
 
 
 
 
 
6.8% June 1, 2015
$
 14 
$
 14 
 
5.3% November 15, 2015
 
 250 
 
 250 
 
Variable rate (0.08% at December 31, 2011) July 1, 2018(1)
 
 161 
 
 161 
 
5.85% June 1, 2021(1)
 
 60 
 
 60 
 
3% August 15, 2021
 
 350 
 
 ― 
 
6% June 1, 2026
 
 250 
 
 250 
 
5% to 5.25% December 1, 2027(1)
 
 150 
 
 150 
 
5.875% January and February 2034(1)
 
 176 
 
 176 
 
5.35% May 15, 2035
 
 250 
 
 250 
 
6.125% September 15, 2037
 
 250 
 
 250 
 
Variable rate (0.90% at December 31, 2011) May 1, 2039(1)
 
 75 
 
 75 
 
6% June 1, 2039
 
 300 
 
 300 
 
5.35% May 15, 2040
 
 250 
 
 250 
 
4.5% August 15, 2040
 
 500 
 
 500 
 
3.95% November 15, 2041
 
 250 
 
 ― 
 
 
 
 3,286 
 
 2,686 
Other long-term debt (unsecured unless otherwise noted):
 
 
 
 
 
5.9% Notes June 1, 2014
 
 130 
 
 130 
 
5.3% Notes July 1, 2021(1)
 
 39 
 
 39 
 
5.5% Notes December 1, 2021(1)
 
 60 
 
 60 
 
4.9% Notes March 1, 2023(1)
 
 25 
 
 25 
 
OMEC LLC loan at variable rates (5.2925% at December 31, 2011)
 
 
 
 
 
    payable 2012 through April 2019 (secured by plant assets)
 
 355 
 
 365 
Capital lease obligations:
 
 
 
 
 
Purchased-power agreements
 
 180 
 
 182 
 
Other
 
 13 
 
 20 
 
 
 
 802 
 
 821 
 
 
 
 4,088 
 
 3,507 
Current portion of long-term debt
 
 (19)
 
 (19)
Unamortized discount on long-term debt
 
 (11)
 
 (9)
Total SDG&E
 
 4,058 
 
 3,479 
 
 
 
 
 
 
SoCalGas
 
 
 
 
First mortgage bonds:
 
 
 
 
 
4.375% January 15, 2011, including $150 at variable rates after
 
 
 
 
 
    fixed-to-floating rate swaps
 
 ― 
 
 250 
 
4.8% October 1, 2012
 
 250 
 
 250 
 
5.5% March 15, 2014
 
 250 
 
 250 
 
5.45% April 15, 2018
 
 250 
 
 250 
 
5.75% November 15, 2035
 
 250 
 
 250 
 
5.125% November 15, 2040
 
 300 
 
 300 
 
 
 
 1,300 
 
 1,550 
Other long-term debt (unsecured):
 
 
 
 
 
4.75% Notes May 14, 2016(1)
 
 8 
 
 8 
 
5.67% Notes January 18, 2028
 
 5 
 
 5 
Capital lease obligations
 
 11 
 
 19 
Market value adjustments for interest rate swap, net (expired January 18, 2011)
 
 ― 
 
 3 
 
 
 
 24 
 
 35 
 
 
 
 1,324 
 
 1,585 
Current portion of long-term debt
 
 (257)
 
 (262)
Unamortized discount on long-term debt
 
 (3)
 
 (3)
Total SoCalGas
 
 1,064 
 
 1,320 



LONG-TERM DEBT (Continued)
(Dollars in millions)
 
 
December 31,
 
 
2011 
2010 
Sempra Energy
 
 
 
 
Other long-term debt (unsecured):
 
 
 
 
 
6% Notes February 1, 2013
 
 400 
 
 400 
 
8.9% Notes November 15, 2013, including $200 at variable rates after fixed-to-floating
 
 
 
 
 
    rate swaps effective January 2011 (8.19% at December 31, 2011)
 
 250 
 
 250 
 
2% Notes March 15, 2014
 
 500 
 
 ― 
 
Notes at variable rates (1.22% at December 31, 2011) March 15, 2014
 
 300 
 
 ― 
 
6.5% Notes June 1, 2016, including $300 at variable rates after fixed-to-floating
 
 
 
 
 
    rate swaps effective January 2011 (4.86% at December 31, 2011)
 
 750 
 
 750 
 
6.15% Notes June 15, 2018
 
 500 
 
 500 
 
9.8% Notes February 15, 2019
 
 500 
 
 500 
 
6% Notes October 15, 2039
 
 750 
 
 750 
 
Employee Stock Ownership Plan Bonds at variable rates payable on demand
 
 
 
 
 
    (0.40% at December 31, 2011) November 1, 2014(1)
 
 8 
 
 32 
Market value adjustments for interest rate swaps, net (expire November 2013 and June 2016)
 
 16 
 
 ― 
 
 
 
 
 
 
Sempra Global
 
 
 
 
Other long-term debt (unsecured):
 
 
 
 
 
Commercial paper borrowings at variable rates, classified as long-term debt
 
 
 
 
 
    (0.74% weighted average at December 31, 2011)
 
 400 
 
 800 
 
 
 
 
 
 
Sempra Pipelines & Storage
 
 
 
 
Other long-term debt (unsecured unless otherwise noted):
 
 
 
 
    Chilquinta Energía
 
 
 
 
 
2.75% Series A Bonds October 30, 2014(1)
 
 24 
 
 ― 
 
4.25% Series B Bonds October 30, 2030(1)
 
 202 
 
 ― 
    Luz del Sur
 
 
 
 
 
Notes at 5.72% to 7.91% payable 2012 through 2021
 
 185 
 
 ― 
 
Bank loans 5.45% to 6.75% payable 2012 through 2016
 
 41 
 
 ― 
    Other
 
 
 
 
 
Notes at 2.87% to 5.05% payable 2012 through 2013(1)
 
 24 
 
 52 
 
9% Notes May 13, 2013
 
 1 
 
 1 
 
8.45% Notes payable 2012 through 2017, secured
 
 29 
 
 32 
 
4.5% Notes July 1, 2024, secured(1)
 
 21 
 
 117 
 
Industrial development bonds at variable rates (0.08% at December 31, 2011)
 
 
 
 
 
    August 1, 2037, secured(1)
 
 55 
 
 55 
First mortgage bonds (Mobile Gas):
 
 
 
 
 
6.9% payable 2011 through 2017
 
 ― 
 
 7 
 
8.75% payable 2011 through 2022
 
 ― 
 
 8 
 
7.48% payable 2011 through 2023
 
 ― 
 
 5 
 
4.14% September 30, 2021
 
 20 
 
 ― 
 
5% September 30, 2031
 
 42 
 
 ― 
 
 
 
 5,018 
 
 4,259 
Current portion of long-term debt
 
 (60)
 
 (68)
Unamortized discount on long-term debt
 
 (9)
 
 (10)
Unamortized premium on long-term debt
 
 7 
 
 ― 
Total other Sempra Energy
 
 4,956 
 
 4,181 
Total Sempra Energy Consolidated
$
 10,078 
$
 8,980 
(1)
Callable long-term debt.



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

Various long-term obligations totaling $5.1 billion at Sempra Energy at December 31, 2011 are unsecured. This includes unsecured long-term obligations totaling $254 million at SDG&E and $13 million at SoCalGas.
 
 
CALLABLE LONG-TERM DEBT
 
At the option of Sempra Energy, SDG&E and SoCalGas, certain debt is callable subject to premiums at various dates:
 

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

In addition, the OMEC LLC project financing loan discussed in Note 1, with $355 million of borrowings at December 31, 2011, may be prepaid at the borrowers’ option.
 
 
FIRST MORTGAGE BONDS
 
The Sempra Utilities issue first mortgage bonds which are secured by a lien on utility plant. The Sempra Utilities may issue additional first mortgage bonds upon compliance with the provisions of their bond agreements (indentures). These indentures require, among other things, the satisfaction of pro forma earnings-coverage tests on first mortgage bond interest and the availability of sufficient mortgaged property to support the additional bonds, after giving effect to prior bond redemptions. The most restrictive of these tests (the property test) would permit the issuance, subject to CPUC authorization, of an additional $3.3 billion of first mortgage bonds at SDG&E and $817 million at SoCalGas at December 31, 2011.
 
Mobile Gas also issues first mortgage bonds secured by utility plant.
 
In August 2011, SDG&E publicly offered and sold $350 million of 3-percent first mortgage bonds maturing in 2021. In November 2011, SDG&E publicly offered and sold $250 million of 3.95-percent first mortgage bonds maturing in 2041.
 
In September 2011, Mobile Gas privately placed $20 million of 4.14-percent first mortgage bonds and $42 million of 5-percent first mortgage bonds, maturing in 2021 and 2031, respectively.
 
 
INDUSTRIAL DEVELOPMENT BONDS
 
 
SDG&E
 
In June 2009, SDG&E remarketed $176 million of industrial development bonds at a fixed rate of 5.875 percent, maturing in 2034. The bonds were initially issued as insured, auction-rate securities, the proceeds of which were loaned to SDG&E, and are repaid with payments on SDG&E first mortgage bonds that have terms corresponding to those of the industrial development bonds that they secure. Prior to SDG&E’s remarketing of the remaining bonds in 2009, SDG&E had purchased $152 million of the bonds from Sempra Energy. SDG&E also has $161 million of industrial development bonds outstanding with a variable interest rate that resets on a weekly basis.
 
 
Sempra Pipelines & Storage
 
To secure an approved exemption from sales and use tax, Sempra Pipelines & Storage has incurred through December 31, 2011, $201 million ($84 million in 2011, $42 million in 2010, and $75 million in 2009) out of a maximum available $265 million of long-term debt related to the construction and equipping of its Mississippi Hub natural gas storage facility. After a redemption of $180 million in December 2011, the debt balance remaining at December 31, 2011, is $21 million. The debt is payable to the Mississippi Business Finance Corporation (MBFC), and we recorded bonds receivable from the MBFC for the same amount. Both the financing obligation and the bonds receivable have interest rates of 4.5 percent and are due on July 1, 2024.
 

 
OTHER LONG-TERM DEBT
 
In March 2011, Sempra Energy publicly offered and sold $500 million of 2-percent notes and $300 million of floating rate notes (1.22 percent as of December 31, 2011), both maturing in 2014. The floating rate notes bear interest at a rate equal to the three-month London interbank offered rate (LIBOR) plus 0.76 percent. The interest rate is reset quarterly.
 
Chilquinta Energía has outstanding Series A and Series B Chilean public bonds with maturity dates in 2014 and 2030, respectively, and stated interest rates of 2.75 percent and 4.25 percent, respectively. The bonds and related interest are denominated in Chilean Unidades de Fomento. The Chilean Unidad de Fomento is a unit of account used in Chile that is adjusted for inflation, and its value is quoted in Chilean Pesos. In 2009, Sempra Pipelines & Storage purchased $58 million of the 2.75-percent bonds, which are eliminated in consolidation.  Net of this elimination, as of December 31, 2011, the outstanding balance on these bonds was $226 million ($24 million of Series A and $202 million of Series B).
 
Luz del Sur has outstanding Peruvian corporate bonds, denominated in the local currency, with maturity dates ranging from 2012 through 2021 at fixed interest rates ranging from 5.72 percent to 7.91 percent.  As of December 31, 2011, the outstanding balance on these bonds was $185 million. Additionally, Luz del Sur has outstanding bank loans with maturity dates ranging from 2012 through 2016 at interest rates ranging from 5.45 percent to 6.75 percent. As of December 31, 2011, the outstanding balance on the bank loans was $41 million.
 
 
DEBT OF EMPLOYEE STOCK OWNERSHIP PLAN (ESOP) AND TRUST (TRUST)
 
The ESOP covers substantially all U.S. based Sempra Energy employees, including those of SDG&E and SoCalGas. The Trust is used to fund part of the retirement savings plan described in Note 8. The bonds of the ESOP are payable by the Trust and mature in 2014. Because the bonds outstanding at December 31, 2011 are payable on demand, we have classified them as short-term.
 
The remaining $8 million of these bonds are being repriced weekly through maturity. ESOP debt was paid down by a total of $64 million during the last three years when 1 million shares of Sempra Energy common stock were released from the Trust in order to fund employer contributions to the Sempra Energy savings plan trust. Interest on the ESOP debt was a negligible amount in 2011, $2 million in 2010 and $3 million in 2009. Dividends used for debt service amounted to $1 million in 2011, $1 million in 2010 and $2 million in 2009.
 
 
INTEREST RATE SWAPS
 
We discuss our fair value interest rate swaps and interest rate swaps to hedge cash flows in Note 10.
 

 

NOTE 6. FACILITIES UNDER JOINT OWNERSHIP
 

San Onofre Nuclear Generating Station (SONGS) and the Southwest Powerlink transmission line are owned jointly by SDG&E with other utilities. SDG&E’s interests at December 31, 2011 were as follows:
 
 
 
Southwest
(Dollars in millions)
SONGS
Powerlink
Percentage ownership
 
 20 
%
 
 91 
%
Utility plant in service
$
 308 
 
$
 323 
 
Accumulated depreciation and amortization
 
 59 
 
 
 191 
 
Construction work in progress
 
 129 
 
 
 22 
 

SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for financing its share of each project and participates in decisions concerning operations and capital expenditures.
 
SDG&E’s share of operating expenses is included in Sempra Energy’s and SDG&E’s Consolidated Statements of Operations.
 
 
SONGS DECOMMISSIONING
 
Objectives, work scope, and procedures for the dismantling and decontamination of SONGS’ three units must meet the requirements of the Nuclear Regulatory Commission (NRC), the Environmental Protection Agency (EPA), the U.S. Department of the Navy (the land owner), the CPUC and other regulatory bodies.
 
SDG&E’s asset retirement obligation related to decommissioning costs for the SONGS units was $524 million at December 31, 2011. That amount includes the cost to decommission Units 2 and 3, and the remaining cost to complete the decommissioning of Unit 1, which is substantially complete. The remaining work on Unit 1 will be completed when Units 2 and 3 are decommissioned. Southern California Edison Company (Edison), the operator of SONGS, updates decommissioning cost studies every three years. Rate recovery of decommissioning costs is allowed until the time that the costs are fully recovered and is subject to adjustment every three years based on the costs allowed by regulators. Collections are authorized to continue until 2022. The most recent cost study was approved by the CPUC in July 2010. SDG&E’s share of decommissioning costs under the approved study is approximately $768 million.
 
Unit 1 was permanently shut down in 1992, and physical decommissioning began in January 2000. Most structures, foundations and large components have been dismantled, removed and disposed of. Spent nuclear fuel has been removed from the Unit 1 Spent Fuel Pool and stored on-site in an independent spent fuel storage installation (ISFSI) licensed by the NRC. The decommissioning of Unit 1 remaining structures (subsurface and intake/discharge) will take place when Units 2 and 3 are decommissioned. The ISFSI will be decommissioned after a permanent storage facility becomes available and the U.S. Department of Energy (DOE) removes the spent fuel from the site. The Unit 1 reactor vessel is expected to remain on site until Units 2 and 3 are decommissioned.
 
 
SPENT NUCLEAR FUEL
 
SONGS owners are responsible for interim storage of spent nuclear fuel generated at SONGS until the DOE accepts it for final disposal. Spent nuclear fuel has been stored in the SONGS Units 1, 2 and 3 spent fuel pools and in the ISFSI, as follows:
 
§  
Movement of all Unit 1 spent fuel to the ISFSI was completed in 2005.
 
§  
Spent fuel for Unit 2 is being stored in both the Unit 2 spent fuel pool and the ISFSI.
 
§  
Spent fuel for Unit 3 is being stored in both the Unit 3 spent fuel pool and the ISFSI.
 
A second ISFSI pad, completed in 2009, will provide sufficient storage capacity to allow for the continued operation of SONGS through 2022.
 
The amounts collected in rates for SONGS’ decommissioning are invested in externally managed trust funds. Amounts held by the trusts are invested in accordance with CPUC regulations. These trusts are shown on the Sempra Energy and SDG&E Consolidated Balance Sheets at fair value with the offsetting credits recorded in Regulatory Liabilities Arising from Removal Obligations.
 
The following table shows the fair values and gross unrealized gains and losses for the securities held in the trust funds.
 
NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
 
 
 
Gross
Gross
Estimated
 
 
 
Unrealized
Unrealized
Fair
 
 
Cost
Gains
Losses
Value
As of December 31, 2011:
 
 
 
 
 
 
 
 
Debt securities:
 
 
 
 
 
 
 
 
    Debt securities issued by the U.S. Treasury and other
 
 
 
 
 
 
 
 
         U.S. government corporations and agencies(1)
$
 157 
$
 13 
$
 ― 
$
 170 
    Municipal bonds(2)
 
 72 
 
 5 
 
 ― 
 
 77 
    Other securities(3)
 
 76 
 
 3 
 
 (1)
 
 78 
Total debt securities
 
 305 
 
 21 
 
 (1)
 
 325 
Equity securities
 
 246 
 
 227 
 
 (5)
 
 468 
Cash and cash equivalents
 
 11 
 
 ― 
 
 ― 
 
 11 
Total
$
 562 
$
 248 
$
 (6)
$
 804 
 
 
 
 
 
 
 
 
 
 
As of December 31, 2010:
 
 
 
 
 
 
 
 
Debt securities:
 
 
 
 
 
 
 
 
    Debt securities issued by the U.S. Treasury and other
 
 
 
 
 
 
 
 
         U.S. government corporations and agencies
$
 162 
$
 14 
$
 (2)
$
 174 
    Municipal bonds
 
 101 
 
 2 
 
 (3)
 
 100 
    Other securities
 
 22 
 
 3 
 
 ― 
 
 25 
Total debt securities
 
 285 
 
 19 
 
 (5)
 
 299 
Equity securities
 
 219 
 
 242 
 
 (1)
 
 460 
Cash and cash equivalents
 
 10 
 
 ― 
 
 ― 
 
 10 
Total
$
 514 
$
 261 
$
 (6)
$
 769 
(1)
Maturity dates are 2012-2042
 
 
 
 
 
 
 
 
(2)
Maturity dates are 2012-2057
 
 
 
 
 
 
 
 
(3)
Maturity dates are 2012-2051
 
 
 
 
 
 
 
 

The following table shows the proceeds from sales of securities in the trusts and gross realized gains and losses on those sales.
 
SALES OF SECURITIES
(Dollars in millions)
 
 
Years ended December 31,
 
 
2011 
2010 
2009 
Proceeds from sales(1)
$
 715 
$
 351 
$
 224 
Gross realized gains
 
 75 
 
 11 
 
 6 
Gross realized losses
 
 (52)
 
 (11)
 
 (33)
(1)
Excludes securities that are held to maturity.

The increase in sales in 2011 was predominantly due to a restructuring of investments within the trust to achieve a more broadly diversified asset mix. Within the fixed income portfolio, the allocation to U.S. Treasury debt-securities was reduced, while holdings of other fixed income securities, including corporate and municipal bonds, and investments in mortgage- and asset-backed securities, were increased. The international equity portfolio was restructured to invest in both developed and emerging market equity securities.
 
Net unrealized gains (losses) are included in Regulatory Liabilities Arising from Removal Obligations on the Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification.
 
Customer contribution amounts are determined by the CPUC using estimates of after-tax investment returns, decommissioning costs, and decommissioning cost escalation rates. Changes in investment returns and decommissioning costs may result in a change in future customer contributions.
 
We discuss the impact of asset retirement obligations in Note 1. We provide additional information about SONGS in Notes 14 and 15.
 

 

NOTE 7. INCOME TAXES
 

Reconciliation of net U.S. statutory federal income tax rates to the effective income tax rates is as follows:
 
RECONCILIATION OF FEDERAL INCOME TAX RATES TO EFFECTIVE INCOME TAX RATES
 
 
Years ended December 31,
 
2011 
2010
2009
Sempra Energy Consolidated
 
 
 
 
 
 
U.S. federal statutory income tax rate
 35 
%
 35 
%
 35 
%
Utility depreciation
 3 
 
 6 
 
 3 
 
State income taxes, net of federal income tax benefit
 2 
 
 ― 
 
 3 
 
Tax credits
 (3)
 
 (7)
 
 (1)
 
Allowance for equity funds used during construction
 (2)
 
 (3)
 
 (1)
 
Non-U.S. earnings taxed at lower statutory income tax rates
 (8)
 
 (12)
 
 (5)
 
Adjustments to prior years’ tax issues
 ― 
 
 (3)
 
 (2)
 
Utility repair allowance
 (1)
 
 (2)
 
 (1)
 
Self-developed software expenditures
 (3)
 
 (5)
 
 (3)
 
Mexican foreign exchange and inflation effects
 (1)
 
 2 
 
 1 
 
Variable interest entities
 ― 
 
 1 
 
 (1)
 
Noncontrolling interests
 ― 
 
 ― 
 
 1 
 
Impact of change in income tax law
 ― 
 
 2 
 
 ― 
 
Impact of impairment of an equity method investment
 ― 
 
 (2)
 
 ― 
 
Other, net
 (1)
 
 1 
 
 ― 
 
    Effective income tax rate
 21 
%
 13 
%
 29 
%
SDG&E
 
 
 
 
 
 
U.S. federal statutory income tax rate
 35 
%
 35 
%
 35 
%
Depreciation
 4 
 
 5 
 
 4 
 
State income taxes, net of federal income tax benefit
 5 
 
 4 
 
 4 
 
Allowance for equity funds used during construction
 (4)
 
 (3)
 
 (2)
 
Adjustments to prior years’ tax issues
 ― 
 
 (3)
 
 (1)
 
Utility repair allowance
 (1)
 
 (2)
 
 (1)
 
Self-developed software expenditures
 (3)
 
 (2)
 
 (2)
 
Variable interest entity
 (1)
 
 1 
 
 (2)
 
Impact of change in income tax law
 ― 
 
 1 
 
 ― 
 
Other, net
 (1)
 
 (3)
 
 (3)
 
    Effective income tax rate
 34 
%
 33 
%
 32 
%
SoCalGas
 
 
 
 
 
 
U.S. federal statutory income tax rate
 35 
%
 35 
%
 35 
%
Depreciation
 6 
 
 5 
 
 6 
 
State income taxes, net of federal income tax benefit
 4 
 
 4 
 
 4 
 
Self-developed software expenditures
 (7)
 
 (6)
 
 (6)
 
Allowance for equity funds used during construction
 (2)
 
 (1)
 
 (1)
 
Impact of change in income tax law
 ― 
 
 3 
 
 ― 
 
Other, net
 (3)
 
 (2)
 
 (4)
 
    Effective income tax rate
 33 
%
 38 
%
 34 
%


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

§  
the equity portion of AFUDC
 
§  
cost of removal of utility plant assets
 
§  
self-developed software costs
 
§  
depreciation on a certain portion of utility plant assets
 
The geographic components of Income Before Income Taxes and Equity Earnings of Certain Unconsolidated Subsidiaries at Sempra Energy are as follows:
 
 
Years ended December 31,
(Dollars in millions)
2011 
2010
2009
U.S.
$
 1,009 
$
 447 
$
 1,007 
Non-U.S.
 
 712 
 
 339 
 
 469 
Total
$
 1,721 
$
 786 
$
 1,476 


The components of income tax expense are as follows:
 
INCOME TAX EXPENSE
(Dollars in millions)
 
Years ended December 31,
 
2011 
2010 
2009 
Sempra Energy Consolidated
 
 
 
 
 
 
Current:
 
 
 
 
 
 
    U.S. Federal
$
75 
$
 27 
$
 39 
    U.S. State
 
 (3)
 
 (3)
 
 40 
    Non-U.S.
 
 149 
 
 30 
 
 48 
        Total
 
 221 
 
 54 
 
 127 
Deferred:
 
 
 
 
 
 
    U.S. Federal
 
 146 
 
 (11)
 
 216 
    U.S. State
 
46 
 
 36 
 
 24 
    Non-U.S.
 
 (45)
 
 27 
 
 58 
        Total
 
 147 
 
 52 
 
 298 
Deferred investment tax credits
 
 (2)
 
 (4)
 
 (3)
        Total income tax expense
$
 366 
$
 102 
$
 422 
SDG&E
 
 
 
 
 
 
Current:
 
 
 
 
 
 
    U.S. Federal
$
 (59)
$
 69 
$
 70 
    U.S. State
 
 6 
 
 52 
 
 34 
        Total
 
 (53)
 
 121 
 
 104 
Deferred:
 
 
 
 
 
 
    U.S. Federal
 
 253 
 
 75 
 
 75 
    U.S. State
 
 36 
 
 (21)
 
 (2)
        Total
 
 289 
 
 54 
 
 73 
Deferred investment tax credits
 
 1 
 
 (2)
 
 ― 
        Total income tax expense
$
 237 
$
 173 
$
 177 
SoCalGas
 
 
 
 
 
 
Current:
 
 
 
 
 
 
    U.S. Federal
$
 (6)
$
 43 
$
 52 
    U.S. State
 
 19 
 
 26 
 
 22 
        Total
 
 13 
 
 69 
 
 74 
Deferred:
 
 
 
 
 
 
    U.S. Federal
 
 128 
 
 108 
 
 67 
    U.S. State
 
 5 
 
 2 
 
 6 
        Total
 
 133 
 
 110 
 
 73 
Deferred investment tax credits
 
 (3)
 
 (3)
 
 (3)
        Total income tax expense
$
 143 
$
 176 
$
 144 


We show the components of deferred income taxes at December 31 for Sempra Energy, SDG&E and SoCalGas in the tables below:
 
DEFERRED INCOME TAXES FOR SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
 
December 31,
 
2011 
2010 
Deferred income tax liabilities:
 
 
 
 
    Differences in financial and tax bases of depreciable and amortizable assets
$
 2,394 
$
 1,965 
    Regulatory balancing accounts
 
 456 
 
 535 
    Unrealized revenue
 
 13 
 
 23 
    Loss on reacquired debt
 
 12 
 
 15 
    Property taxes
 
 43 
 
 38 
    Difference in financial and tax bases of partnership interests
 
 152 
 
 ― 
    Other deferred income tax liabilities
 
 30 
 
 72 
        Total deferred income tax liabilities
 
 3,100 
 
 2,648 
Deferred income tax assets:
 
 
 
 
    Investment tax credits
 
 22 
 
 34 
    Equity losses
 
 16 
 
 3 
    Net operating losses
 
 811 
 
 40 
    Compensation-related items
 
 140 
 
 158 
    Postretirement benefits
 
 361 
 
 467 
    Difference in financial and tax bases of partnership interests
 
 ― 
 
 83 
    Other deferred income tax assets
 
 34 
 
 52 
    State income taxes
 
 58 
 
 73 
    Bad debt allowance
 
 8 
 
 10 
    Litigation and other accruals not yet deductible
 
 5 
 
 304 
        Deferred income tax assets before valuation allowances
 
 1,455 
 
 1,224 
        Less: valuation allowances
 
 82 
 
 62 
            Total deferred income tax assets
 
 1,373 
 
 1,162 
Net deferred income tax liability
$
 1,727 
$
 1,486 
Our policy is to show deferred taxes of VIEs on a net basis, including valuation allowances. See table “Amounts Associated with Otay Mesa VIE” in Note 1 for further information on VIEs.



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

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

NET DEFERRED INCOME TAX LIABILITY
(Dollars in millions)
 
Sempra Energy
 
 
 
 
 
Consolidated
SDG&E
SoCalGas
 
2011 
2010 
2011 
2010 
2011 
2010 
Current (asset) liability
$
 173 
$
 (75)
$
 62 
$
 (129)
$
 44 
$
 17 
Noncurrent liability
 
 1,554 
 
 1,561 
 
 1,167 
 
 1,001 
 
 576 
 
 418 
Total
$
 1,727 
$
 1,486 
$
 1,229 
$
 872 
$
 620 
$
 435 

At December 31, 2011, Sempra Energy has recorded a valuation allowance against a portion of its total deferred income tax assets, as shown above in the “Deferred Income Taxes for Sempra Energy Consolidated” table. A valuation allowance is recorded when, based on more-likely-than-not criteria, negative evidence outweighs positive evidence with regard to our ability to realize a deferred tax asset in the future. Of the valuation allowances recorded to date, the negative evidence outweighs the positive evidence primarily due to cumulative pretax losses in various U.S. state and non-U.S. jurisdictions resulting in net operating losses (NOLs), as discussed below, that we currently do not believe will be realized. At both Sempra Energy and SDG&E, deferred income taxes for variable interest entities are shown on a net basis. Therefore, a valuation allowance of $116 million related to variable interest entities is not reflected in the tables above. Of Sempra Energy’s total valuation allowance of $82 million, $14 million is related to non-U.S. NOLs, $8 million to other future non-U.S. deductions, and $60 million to U.S. state NOLs. The total valuation allowance increased by $20 million during 2011 when compared to 2010, primarily due to the increase in the valuation allowance established for U.S. state NOLs. We believe that it is more likely than not that the remainder of the total deferred income tax asset is realizable.
 
At December 31, 2011, Sempra Energy’s non-U.S. subsidiaries had $52 million of unused NOLs available to utilize in the future to reduce Sempra Energy’s future non-U.S. income tax expense, which is in Denmark, Mexico, the Netherlands and Spain. The carryforward periods for our non-U.S. unused NOLs are as follows: $7 million does not expire and $45 million expires between 2012 and 2026. As of December 31, 2011, our Mexican subsidiaries have NOLs of $176 million, of which $163 million have been utilized on a consolidated level. These NOLs are subject to recapture between 2012 and 2016 if the Mexican subsidiary that generated them does not have sufficient taxable income itself to realize them within 5 years. These NOLs expire between 2016 and 2021. Sempra Energy’s U.S. subsidiaries had $768 million of unused U.S. state NOLs, primarily in Alabama, Connecticut, District of Columbia, Indiana, Louisiana, Minnesota, New Jersey, New York and Oklahoma. These U.S. state NOLs expire between 2012 and 2031. We have not recorded income tax benefits on a portion of Sempra Energy’s total NOLs because they were incurred in jurisdictions where we currently believe they will not be realized, as discussed above. Sempra Energy’s consolidated U.S. subsidiaries had $1.8 billion of unused U.S. federal consolidated NOLs and $798 million of unused California combined NOLs. We have recorded income tax benefits on these NOLs, in total, because they were incurred in jurisdictions where we currently believe they will be realized.
 
At December 31, 2011, Sempra Energy had not recognized a U.S. deferred income tax liability related to a $2.6 billion basis difference between its financial statement and tax investment amount in its non-U.S. subsidiaries. This basis difference consists of $2.6 billion of cumulative undistributed earnings that we expect to reinvest indefinitely outside of the U.S., which includes the $0.3 billion gain related to the remeasurement of equity method investments in Chilquinta Energía and Luz del Sur, as we discuss in Note 3. These cumulative undistributed earnings have previously been reinvested or will be reinvested in active non-U.S. operations, thus we do not intend to use these earnings as a source of funding for U.S. operations. It is not practical to determine the amount of U.S. income taxes that might be payable if the cumulative undistributed earnings were eventually distributed or the investments were sold. U.S. deferred income taxes would be recorded on $2.6 billion of the basis difference related to cumulative undistributed earnings if we no longer intend to indefinitely reinvest all, or a part, of the cumulative undistributed earnings.
 
Following is a summary of unrecognized income tax benefits:
 
SUMMARY OF UNRECOGNIZED INCOME TAX BENEFITS
(Dollars in millions)
 
Sempra Energy
 
 
 
 
 
 
 
 
 
 
 
 
 
Consolidated
SDG&E
SoCalGas
 
2011 
2010 
2009 
2011 
2010 
2009 
2011 
2010 
2009 
Total
$
 72 
$
 97 
$
 94 
$
 7 
$
 5 
$
 14 
$
 ― 
$
 8 
$
 11 
Of the total, amounts related to tax
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
   positions that, if recognized, in
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
   future years, would:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
       decrease the effective tax rate
$
 (72)
$
 (76)
$
 (76)
$
 (7)
$
 (5)
$
 (13)
$
 ― 
$
 (1)
$
 (1)
       increase the effective tax rate
 
 7 
 
 5 
 
 13 
 
 7 
 
 5 
 
 13 
 
 ― 
 
 ― 
 
 ― 


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

It is reasonably possible that within the next 12 months unrecognized income tax benefits could decrease due to the following:
 
POSSIBLE DECREASES IN UNRECOGNIZED INCOME TAX BENEFITS WITHIN 12 MONTHS
(Dollars in millions)
 
At December 31,
 
2011 
2010 
2009 
Sempra Energy Consolidated:
 
 
 
 
 
 
Expiration of statutes of limitations on tax assessments
$
 (7)
$
 (6)
$
 (7)
Potential resolution of audit issues with various
 
 
 
 
 
 
     U.S. federal, state and local and non-U.S. taxing authorities
 
 ― 
 
 (35)
 
 (24)
 
$
 (7)
$
 (41)
$
 (31)
SDG&E
$
 ― 
$
 ― 
$
 ― 
SoCalGas:
 
 
 
 
 
 
Expiration of statutes of limitations on tax assessments
$
 ― 
$
 (5)
$
 (6)
Potential resolution of audit issues with various
 
 
 
 
 
 
     U.S. federal, state and local taxing authorities
 
 ― 
 
 ― 
 
 (1)
 
$
 ― 
$
 (5)
$
 (7)


Amounts accrued for interest expense and penalties associated with unrecognized income tax benefits are included in income tax expense in the Consolidated Statements of Operations for the years ended December 31 as follows:
 
INTEREST EXPENSE AND PENALTIES ASSOCIATED WITH UNRECOGNIZED INCOME TAX BENEFITS
(Dollars in millions)
 
Sempra Energy
 
 
 
 
 
 
 
 
 
 
 
 
 
Consolidated
 
SDG&E
 
SoCalGas
 
2011 
2010 
2009 
 
2011 
2010 
2009 
 
2011 
2010 
2009 
Interest expense (benefit)
$
 (3)
$
 4 
$
 (16)
 
$
 ― 
$
 3 
$
 (4)
 
$
 (1)
$
 1 
$
 (3)
Penalties
 
 (1)
 
 ― 
 
 3 
 
 
 ― 
 
 ― 
 
 ― 
 
 
 ― 
 
 ― 
 
 1 

Amounts accrued at December 31 on the Consolidated Balance Sheets for interest expense and penalties associated with unrecognized income tax benefits are as follows:
 
ACCRUED INTEREST EXPENSE AND PENALTIES ASSOCIATED WITH UNRECOGNIZED INCOME TAX BENEFITS
(Dollars in millions)
 
Sempra Energy
 
 
 
 
 
 
 
 
 
 
Consolidated
 
SDG&E
 
SoCalGas
 
2011 
2010 
 
2011 
2010 
 
2011 
2010 
Interest expense (benefit)
$
 3 
$
 6 
 
$
 1 
$
 1 
 
$
 1 
$
 2 
Penalties
 
 3 
 
 4 
 
 
 ― 
 
 ― 
 
 
 ― 
 
 ― 
 
INCOME TAX AUDITS
 
Sempra Energy is subject to U.S. federal income tax as well as to income tax of multiple state and non-U.S. jurisdictions. We remain subject to examination for U.S. federal tax years after 2006. We are subject to examination by major state tax jurisdictions for tax years after 2005. Certain major non-U.S. income tax returns from 2002 through the present are open to examination.
 
In addition, we have filed state refund claims for tax years back to 1998, and PE has filed state refund claims for tax years back to 1993. The pre-2006 tax years are closed to new issues; therefore, no additional tax may be assessed by the taxing authorities for these years.
 
SDG&E and SoCalGas are subject to U.S. federal income tax as well as income tax of state jurisdictions. They remain subject to examination for U.S. federal years after 2006 and by major state tax jurisdictions for years after 2005.
 

 

NOTE 8. EMPLOYEE BENEFIT PLANS
 

We are required by applicable GAAP to:
 
§  
recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status in the statement of financial position;
§  
measure a plan’s assets and its obligations that determine its funded status as of the end of the fiscal year (with limited exceptions); and
§  
recognize changes in the funded status of a defined benefit postretirement plan in the year in which the changes occur. Generally, those changes are reported in other comprehensive income and as a separate component of shareholders’ equity.
 
The information presented below covers the employee benefit plans of Sempra Energy and its principal subsidiaries, as detailed following.
 
Sempra Energy has funded and unfunded noncontributory defined benefit plans, including separate plans for SDG&E and SoCalGas, which collectively cover all domestic and certain foreign employees, and Sempra Energy’s board of directors. The plans generally provide defined benefits based on years of service and either final average or career salary.
 
Chilquinta Energía, which was acquired by Sempra Energy in 2011, has an unfunded contributory defined benefit plan covering all employees hired before October 1, 1981 and an unfunded noncontributory termination indemnity obligation covering all employees. The plans generally provide defined benefits to retirees based on date of hire, years of service and final average salary.
 
Sempra Energy also has other postretirement benefit plans (PBOP), including separate plans for SDG&E and SoCalGas, which collectively cover all domestic and certain foreign employees, and Sempra Energy’s board of directors. The life insurance plans are both contributory and noncontributory, and the health care plans are contributory. Participants’ contributions are adjusted annually. Other postretirement benefits include medical benefits for retirees’ spouses.
 
Chilquinta Energía also has two noncontributory postretirement benefit plans which cover substantially all employees – a health care plan and an energy subsidy plan that provides for reduced energy rates. The health care plan includes benefits for retirees’ spouses and dependents.
 
Pension and other postretirement benefits costs and obligations are dependent on assumptions used in calculating such amounts. These assumptions include
 
§  
discount rates
§  
expected return on plan assets
§  
health-care cost trend rates
§  
mortality rates
§  
compensation increase rates
§  
payout elections (lump sum or annuity)
 
We review these assumptions on an annual basis prior to the beginning of each year and update them as appropriate. We consider current market conditions, including interest rates, in making these assumptions. We use a December 31 measurement date for all of our plans.
 
In support of its Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans, Sempra Energy maintains dedicated assets, including investments in life insurance contracts, which totaled $478 million and $442 million at December 31, 2011 and 2010, respectively.
 
 
PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS
 

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

 
Benefit Obligations and Assets
 
The following three tables provide a reconciliation of the changes in the plans’ projected benefit obligations and the fair value of assets during 2011 and 2010, and a statement of the funded status at December 31, 2011 and 2010:
 
PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
(Dollars in millions)
 
 
Pension Benefits
 
Other Postretirement
Benefits
Sempra Energy Consolidated
2011 
2010 
 
2011 
2010 
CHANGE IN PROJECTED BENEFIT OBLIGATION:
 
 
 
 
 
 
 
 
 
Net obligation at January 1
$
 3,124 
$
 3,083 
 
$
 1,139 
$
 985 
Service cost
 
 83 
 
 83 
 
 
 31 
 
 26 
Interest cost
 
 168 
 
 167 
 
 
 65 
 
 57 
Plan amendments
 
 ― 
 
 1 
 
 
 4 
 
 ― 
Impact of PPACA excise tax
 
 ― 
 
 ― 
 
 
 ― 
 
 31 
Actuarial loss (gain)
 
 224 
 
 ― 
 
 
 (42)
 
 81 
Contributions from plan participants
 
 ― 
 
 ― 
 
 
 15 
 
 13 
Benefit payments
 
 (177)
 
 (210)
 
 
 (59)
 
 (56)
Acquisitions
 
 20 
 
 ― 
 
 
 5 
 
 ― 
Foreign currency adjustments
 
 (2)
 
 ― 
 
 
 ― 
 
 ― 
Settlements
 
 (34)
 
 ― 
 
 
 ― 
 
 ― 
Federal subsidy (Medicare Part D)
 
 ― 
 
 ― 
 
 
 2 
 
 2 
Net obligation at December 31
 
 3,406 
 
 3,124 
 
 
 1,160 
 
 1,139 
 
 
 
 
 
 
 
 
 
 
CHANGE IN PLAN ASSETS:
 
 
 
 
 
 
 
 
 
Fair value of plan assets at January 1
 
 2,354 
 
 2,130 
 
 
 746 
 
 658 
Actual return on plan assets
 
 (23)
 
 275 
 
 
 4 
 
 79 
Employer contributions
 
 212 
 
 159 
 
 
 72 
 
 52 
Contributions from plan participants
 
 ― 
 
 ― 
 
 
 15 
 
 13 
Benefit payments
 
 (177)
 
 (210)
 
 
 (59)
 
 (56)
Settlements
 
 (34)
 
 ― 
 
 
 ― 
 
 ― 
Fair value of plan assets at December 31
 
 2,332 
 
 2,354 
 
 
 778 
 
 746 
Funded status at December 31
$
 (1,074)
$
 (770)
 
$
 (382)
$
 (393)
Net recorded liability at December 31
$
 (1,074)
$
 (770)
 
$
 (382)
$
 (393)
 
 



PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
(Dollars in millions)
 
Pension Benefits
 
Other Postretirement
Benefits
SDG&E
2011 
2010 
 
2011 
2010 
CHANGE IN PROJECTED BENEFIT OBLIGATION:
 
 
 
 
 
 
 
 
 
Net obligation at January 1
$
 949 
$
 908 
 
$
 175 
$
 160 
Service cost
 
 28 
 
 27 
 
 
 7 
 
 6 
Interest cost
 
 49 
 
 47 
 
 
 10 
 
 9 
Plan amendments
 
 ― 
 
 ― 
 
 
 2 
 
 ― 
Actuarial loss (gain)
 
 27 
 
 1 
 
 
 (5)
 
 3 
Settlements
 
 (1)
 
 ― 
 
 
 ― 
 
 ― 
Transfer of liability (to) from other plans
 
 (19)
 
 17 
 
 
 (2)
 
 2 
Contributions from plan participants
 
 ― 
 
 ― 
 
 
 7 
 
 6 
Benefit payments
 
 (52)
 
 (51)
 
 
 (12)
 
 (11)
Net obligation at December 31
 
 981 
 
 949 
 
 
 182 
 
 175 
 
 
 
 
 
 
 
 
 
 
CHANGE IN PLAN ASSETS:
 
 
 
 
 
 
 
 
 
Fair value of plan assets at January 1
 
 713 
 
 615 
 
 
 99 
 
 81 
Actual return on plan assets
 
 (7)
 
 79 
 
 
 (1)
 
 7 
Employer contributions
 
 69 
 
 61 
 
 
 15 
 
 15 
Transfer of assets (to) from other plans
 
 (10)
 
 9 
 
 
 (2)
 
 1 
Settlements
 
 (1)
 
 ― 
 
 
 ― 
 
 ― 
Contributions from plan participants
 
 ― 
 
 ― 
 
 
 7 
 
 6 
Benefit payments
 
 (52)
 
 (51)
 
 
 (12)
 
 (11)
Fair value of plan assets at December 31
 
 712 
 
 713 
 
 
 106 
 
 99 
Funded status at December 31
$
 (269)
$
 (236)
 
$
 (76)
$
 (76)
Net recorded liability at December 31
$
 (269)
$
 (236)
 
$
 (76)
$
 (76)



PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
(Dollars in millions)
 
 
Pension Benefits
 
Other Postretirement
Benefits
SoCalGas
2011 
2010 
 
2011 
2010 
CHANGE IN PROJECTED BENEFIT OBLIGATION:
 
 
 
 
 
 
 
 
 
Net obligation at January 1
$
 1,786 
$
 1,764 
 
$
 920 
$
 780 
Service cost
 
 46 
 
 46 
 
 
 22 
 
 18 
Interest cost
 
 99 
 
 98 
 
 
 53 
 
 46 
Plan amendments
 
 ― 
 
 ― 
 
 
 1 
 
 ― 
Impact of PPACA excise tax
 
 ― 
 
 ― 
 
 
 ― 
 
 31 
Actuarial loss (gain)
 
 171 
 
 (3)
 
 
 (46)
 
 77 
Contributions from plan participants
 
 ― 
 
 ― 
 
 
 9 
 
 8 
Benefit payments
 
 (107)
 
 (126)
 
 
 (45)
 
 (43)
Settlements
 
 (4)
 
 ― 
 
 
 ― 
 
 ― 
Transfer of liability from other plans
 
 26 
 
 7 
 
 
 5 
 
 1 
Federal subsidy (Medicare Part D)
 
 ― 
 
 ― 
 
 
 2 
 
 2 
Net obligation at December 31
 
 2,017 
 
 1,786 
 
 
 921 
 
 920 
 
 
 
 
 
 
 
 
 
 
CHANGE IN PLAN ASSETS:
 
 
 
 
 
 
 
 
 
Fair value of plan assets at January 1
 
 1,456 
 
 1,332 
 
 
 632 
 
 562 
Actual return on plan assets
 
 (12)
 
 171 
 
 
 4 
 
 70 
Employer contributions
 
 95 
 
 71 
 
 
 55 
 
 35 
Transfer of assets from other plans
 
 15 
 
 7 
 
 
 3 
 
 ― 
Settlements
 
 (4)
 
 ― 
 
 
 ― 
 
 ― 
Contributions from plan participants
 
 ― 
 
 ― 
 
 
 9 
 
 8 
Benefit payments
 
 (107)
 
 (125)
 
 
 (45)
 
 (43)
Fair value of plan assets at December 31
 
 1,443 
 
 1,456 
 
 
 658 
 
 632 
Funded status at December 31
$
 (574)
$
 (330)
 
$
 (263)
$
 (288)
Net recorded liability at December 31
$
 (574)
$
 (330)
 
$
 (263)
$
 (288)
 
 
 
The actuarial losses for pension plans in 2011 were primarily due to a decrease in the weighted average discount rate and the rate used to convert monthly annuity-type benefits to a lump sum benefit payment.
 
The actuarial gains for other postretirement plans in 2011 resulted from a decrease in assumed participation rates and claims costs and the impact of the adoption of the Employer Group Waiver Plan, partially offset by actuarial losses from a decrease in the weighted average discount rate. The Employer Group Waiver Plan is an alternative means of providing the existing pharmacy benefit.
 
The actuarial losses in 2010 for other postretirement plans were primarily due to higher medical premiums and higher health care trend rates for the SoCalGas other postretirement benefit plans.
 
 
Net Assets and Liabilities
 
The assets and liabilities of the pension and other postretirement benefit plans are affected by changing market conditions as well as when actual plan experience is different than assumed. Such events result in investment gains and losses, which we defer and recognize in pension and other postretirement benefit costs over a period of years.  Sempra Energy uses the asset smoothing method for its pension and other postretirement plans, except for the SDG&E plans. This method develops an asset value that recognizes realized and unrealized investment gains and losses over a three-year period. This adjusted asset value, known as the market-related value of assets, is used in conjunction with an expected long-term rate of return to determine the expected return-on-assets component of net periodic cost. SoCalGas also uses the asset smoothing method.
 
The 10-percent corridor accounting method is used at Sempra Energy, SDG&E and SoCalGas. Under the corridor accounting method, if as of the beginning of a year, unrecognized net gain or loss exceeds 10 percent of the greater of the projected benefit obligation or the market-related value of plan assets, the excess is amortized over the average remaining service period of active participants. The asset smoothing and 10-percent corridor accounting methods help mitigate volatility of net periodic costs from year to year.
 
We recognize the overfunded or underfunded status of defined benefit pension and other postretirement plans as assets or liabilities, respectively; unrecognized changes in these assets and/or liabilities are normally recorded to other comprehensive income (loss) on the balance sheet. The Sempra Utilities and Mobile Gas record regulatory assets and liabilities that offset the funded pension and other postretirement plans’ assets or liabilities, as these costs are expected to be recovered in future utility rates based on agreements with regulatory agencies.
 
The Sempra Utilities record annual pension and other postretirement net periodic benefit costs equal to the contributions to their plans as authorized by the CPUC. The annual contributions to the pension plans are limited to a minimum required funding amount as determined by the Internal Revenue Service. The annual contributions to the other postretirement plans are equal to the lesser of the maximum tax deductible amount or the net periodic cost calculated in accordance with GAAP for pension and other postretirement benefit plans. Mobile Gas records annual pension and other postretirement net periodic benefit costs based on an estimate of the net periodic cost at the beginning of the year calculated in accordance with GAAP for pension and other postretirement benefit plans, as authorized by the Alabama Public Service Commission. Any differences between booked net periodic benefit cost and amounts contributed to the pension and other postretirement plans for the Sempra Utilities are disclosed as regulatory adjustments in accordance with GAAP for regulated entities.
 
The net liability is included in the following captions on the Consolidated Balance Sheets at December 31:
 
 
Pension Benefits
 
Other Postretirement
Benefits
(Dollars in millions)
2011 
2010 
 
2011 
2010 
Sempra Energy Consolidated
 
 
 
 
 
 
 
 
 
Current liabilities
$
 (31)
$
 (57)
 
$
 (2)
$
 (1)
Noncurrent liabilities
 
 (1,043)
 
 (713)
 
 
 (380)
 
 (392)
Net recorded liability
$
 (1,074)
$
 (770)
 
$
 (382)
$
 (393)
SDG&E
 
 
 
 
 
 
 
 
 
Current liabilities
$
 (3)
$
 (3)
 
$
 ― 
$
 ― 
Noncurrent liabilities
 
 (266)
 
 (233)
 
 
 (76)
 
 (76)
Net recorded liability
$
 (269)
$
 (236)
 
$
 (76)
$
 (76)
SoCalGas
 
 
 
 
 
 
 
 
 
Current liabilities
$
 (4)
$
 (5)
 
$
 ― 
$
 ― 
Noncurrent liabilities
 
 (570)
 
 (325)
 
 
 (263)
 
 (288)
Net recorded liability
$
 (574)
$
 (330)
 
$
 (263)
$
 (288)

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

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


The accumulated benefit obligation for defined benefit pension plans at December 31, 2011 and 2010 was as follows:
 
 
Sempra Energy Consolidated
 
SDG&E
 
SoCalGas
(Dollars in millions)
2011 
2010 
 
2011 
2010 
 
2011 
2010 
Accumulated benefit obligation
$
 3,176 
$
 2,933 
 
$
 962 
$
 935 
 
$
 1,845 
$
 1,623 

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

(Dollars in millions)
2011 
2010 
Sempra Energy Consolidated
 
 
 
 
Projected benefit obligation
$
 3,150 
$
 2,880 
Accumulated benefit obligation
 
 2,958 
 
 2,702 
Fair value of plan assets
 
 2,332 
 
 2,354 
SDG&E
 
 
 
 
Projected benefit obligation
$
 944 
$
 917 
Accumulated benefit obligation
 
 928 
 
 906 
Fair value of plan assets
 
 712 
 
 713 
SoCalGas
 
 
 
 
Projected benefit obligation
$
 1,987 
$
 1,755 
Accumulated benefit obligation
 
 1,818 
 
 1,594 
Fair value of plan assets
 
 1,443 
 
 1,456 
 
Net Periodic Benefit Cost, 2009-2011
 
The following three tables provide the components of net periodic benefit cost and amounts recognized in other comprehensive income for the years ended December 31:
 
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME
(Dollars in millions)
 
Pension Benefits
 
Other Postretirement Benefits
Sempra Energy Consolidated
2011 
2010 
2009 
 
2011 
2010 
2009 
Net Periodic Benefit Cost
 
 
 
 
 
 
 
 
 
 
 
 
 
Service cost
$
 83 
$
 83 
$
 74 
 
$
 31 
$
 26 
$
 26 
Interest cost
 
 168 
 
 167 
 
 170 
 
 
 65 
 
 57 
 
 56 
Expected return on assets
 
 (144)
 
 (143)
 
 (139)
 
 
 (48)
 
 (46)
 
 (45)
Amortization of:
 
 
 
 
 
 
 
 
 
 
 
 
 
    Prior service cost (credit)
 
 4 
 
 4 
 
 7 
 
 
 
 
 (1)
 
 (1)
    Actuarial loss
 
 34 
 
 30 
 
 23 
 
 
17 
 
 8 
 
 3 
Regulatory adjustment
 
 43 
 
 19 
 
 28 
 
 
 7 
 
 7 
 
 7 
Settlement charge
 
 13 
 
 ― 
 
 14 
 
 
 ― 
 
 ― 
 
 ― 
Total net periodic benefit cost
 
 201 
 
 160 
 
 177 
 
 
 72 
 
 51 
 
 46 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Other Changes in Plan Assets and Benefit Obligations
 
 
 
 
 
 
 
 
 
 
 
 
 
    Recognized in Other Comprehensive Income
 
 
 
 
 
 
 
 
 
 
 
 
 
Net loss (gain)
 
 23 
 
 (12)
 
 9 
 
 
 7 
 
 (1)
 
 3 
Amortization of prior service credit
 
 ― 
 
 ― 
 
 ― 
 
 
 ― 
 
 1 
 
 1 
Amortization of actuarial loss
 
 (10)
 
 (10)
 
 (8)
 
 
 ― 
 
 ― 
 
 ― 
    Total recognized in other comprehensive income
 
 13 
 
 (22)
 
 1 
 
 
 7 
 
 ― 
 
 4 
    Total recognized in net periodic benefit cost and other
        comprehensive income
$
 214 
$
 138 
$
 178 
 
$
 79 
$
 51 
$
 50 



NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME
(Dollars in millions)
 
Pension Benefits
 
Other Postretirement Benefits
SDG&E
2011 
2010 
2009 
 
2011 
2010 
2009 
Net Periodic Benefit Cost
 
 
 
 
 
 
 
 
 
 
 
 
 
Service cost
$
 28 
$
 27 
$
 23 
 
$
 7 
$
 6 
$
 5 
Interest cost
 
 49 
 
 47 
 
 48 
 
 
 10 
 
 9 
 
 9 
Expected return on assets
 
 (46)
 
 (40)
 
 (32)
 
 
 (8)
 
 (5)
 
 (3)
Amortization of:
 
 
 
 
 
 
 
 
 
 
 
 
 
    Prior service cost
 
 1 
 
 1 
 
 4 
 
 
 4 
 
 4 
 
 4 
    Actuarial loss
 
 9 
 
 12 
 
 16 
 
 
 ― 
 
 ― 
 
 ― 
Regulatory adjustment
 
 31 
 
 13 
 
 2 
 
 
 2 
 
 2 
 
 2 
Settlement charge
 
 1 
 
 ― 
 
 2 
 
 
 ― 
 
 ― 
 
 ― 
Total net periodic benefit cost
 
 73 
 
 60 
 
 63 
 
 
 15 
 
 16 
 
 17 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Other Changes in Plan Assets and Benefit Obligations
 
 
 
 
 
 
 
 
 
 
 
 
 
    Recognized in Other Comprehensive Income
 
 
 
 
 
 
 
 
 
 
 
 
 
Net loss (gain)
 
 1 
 
 2 
 
 (1)
 
 
 ― 
 
 ― 
 
 ― 
Amortization of actuarial loss
 
 (1)
 
 (1)
 
 (2)
 
 
 ― 
 
 ― 
 
 ― 
    Total recognized in other comprehensive income
 
 ― 
 
 1 
 
 (3)
 
 
 ― 
 
 ― 
 
 ― 
    Total recognized in net periodic benefit cost and other
        comprehensive income
$
 73 
$
 61 
$
 60 
 
$
 15 
$
 16 
$
 17 

NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME
(Dollars in millions)
 
Pension Benefits
 
Other Postretirement Benefits
SoCalGas
2011 
2010 
2009 
 
2011 
2010 
2009 
Net Periodic Benefit Cost
 
 
 
 
 
 
 
 
 
 
 
 
 
Service cost
$
 46 
$
 46 
$
 42 
 
$
 22 
$
 18 
$
 18 
Interest cost
 
 99 
 
 98 
 
 98 
 
 
 53 
 
 46 
 
 45 
Expected return on assets
 
 (85)
 
 (90)
 
 (94)
 
 
 (40)
 
 (40)
 
 (41)
Amortization of:
 
 
 
 
 
 
 
 
 
 
 
 
 
    Prior service cost (credit)
 
 2 
 
 2 
 
 2 
 
 
 (4)
 
 (4)
 
 (4)
    Actuarial loss
 
 17 
 
 10 
 
 1 
 
 
 17 
 
 7 
 
 3 
Settlement charge
 
 1 
 
 ― 
 
 1 
 
 
 ― 
 
 ― 
 
 ― 
Regulatory adjustment
 
 12 
 
 6 
 
 28 
 
 
 5 
 
 5 
 
 6 
Total net periodic benefit cost
 
 92 
 
 72 
 
 78 
 
 
 53 
 
 32 
 
 27 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Other Changes in Plan Assets and Benefit Obligations
 
 
 
 
 
 
 
 
 
 
 
 
 
    Recognized in Other Comprehensive Income
 
 
 
 
 
 
 
 
 
 
 
 
 
Net loss
 
 2 
 
 ― 
 
 1 
 
 
 ― 
 
 ― 
 
 ― 
Amortization of actuarial loss
 
 (1)
 
 (1)
 
 (1)
 
 
 ― 
 
 ― 
 
 ― 
    Total recognized in other comprehensive income
 
 1 
 
 (1)
 
 ― 
 
 
 ― 
 
 ― 
 
 ― 
    Total recognized in net periodic benefit cost and other
        comprehensive income
$
 93 
$
 71 
$
 78 
 
$
 53 
$
 32 
$
 27 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
The estimated net loss for the pension plans that will be amortized from Accumulated Other Comprehensive Income (Loss) into net periodic benefit cost in 2012 is $10 million for Sempra Energy Consolidated and $1 million at both SDG&E and SoCalGas. Negligible amounts of prior service credit for the pension plans will be similarly amortized in 2012.
 
The estimated net loss for the PBOP plans that will be amortized from Accumulated Other Comprehensive Income (Loss) into net periodic cost benefit in 2012 is $1 million for Sempra Energy Consolidated.
 
Negligible amounts of estimated prior service credit for the other postretirement benefit plans will be amortized from Accumulated Other Comprehensive Income (Loss) into net periodic benefit cost in 2012 at Sempra Energy Consolidated.
 
 
Patient Protection and Affordable Care Act (PPACA) of 2010
 
The PPACA was enacted in March 2010. The key aspects of this legislation affecting Sempra Energy’s cost of providing retiree medical benefits are
 
§  
Availability of subsidies from the Early Retiree Reinsurance Program (ERRP)
 
§  
Mandatory coverage for adult children until age 26 beginning in 2011
 
§  
Changes to the Prescription Drug Plan and Medicare Advantage programs beginning in 2011 and extending through 2020
 
§  
Loss of the tax free status of the Retiree Drug Subsidy (RDS) beginning in 2013
 
§  
Availability of coverage through health care exchanges beginning in 2014
 
§  
Excise tax on high-cost plans, as defined in the legislation, beginning in 2018
 
In determining the projected benefit obligation for our other postretirement benefit plans, we took mandatory coverage for adult children, changes to the Prescription Drug Plan and Medicare Advantage programs, and availability of health care exchanges into consideration in the development of future claims costs and health care trend rates as of December 31, 2011 and 2010. Subsidies received through the ERRP will be reflected when received. We measured loss of the tax free status of RDS separately as described in the following section. We determined the impact of the excise tax provision separately for each of Sempra Energy’s plans, as explained below.
 
With the exception of SoCalGas’ represented employees and Mobile Gas, we provide most of our employer subsidy in the form of a defined dollar benefit. Once the premium exceeds our stated benefit level, the retirees pay the difference between the premium amount and the subsidy. Under this arrangement, our obligation doesn’t change with the excise tax, since by 2018 the premium both before and after inclusion of the excise tax will exceed our defined dollar benefit.
 
SoCalGas’ union retirees are provided a subsidy as a percentage of the premium. For those retirees, we estimated an increase in SoCalGas’ and Sempra Energy’s obligations as of December 31, 2010 for the excise tax. However, it is likely that some retirees will move to less expensive plans as a result of the excise tax and lower Sempra Energy’s composite plan cost. The net effect of the increase in obligation from the excise tax, partially offset by the lower composite plan cost, was estimated to be $31 million.
 
Mobile Gas offers only a pre-age 65 plan. As such, future retirees will only have a limited period when the excise tax may apply. All current retirees will no longer be eligible for benefits once the excise tax is effective in 2018.
 
 
Medicare Prescription Drug, Improvement and Modernization Act of 2003
 
The Medicare Prescription Drug, Improvement and Modernization Act of 2003 establishes a prescription drug benefit under Medicare (Medicare Part D) and a tax-exempt federal subsidy to sponsors of retiree health-care benefit plans that provide a benefit that actuarially is at least equivalent to Medicare Part D. We have determined that benefits provided to certain participants actuarially will be at least equivalent to Medicare Part D. Thus, we are entitled to a tax-exempt subsidy that reduced our accumulated postretirement benefit obligation under our plans at January 1, 2011 and reduced the net periodic cost for 2011 by the following amounts:
 
 
Sempra Energy
 
 
(Dollars in millions)
Consolidated
SDG&E
SoCalGas
Net periodic benefit cost reduction
$
 4 
$
 ― 
$
 4 
 
Assumptions for Pension and Other Postretirement Benefit Plans
 
 
Benefit Obligation and Net Periodic Benefit Cost
 
Except for the Chilquinta Energía plans, we develop the discount rate assumptions based on the results of a third party modeling tool that develops the discount rate by matching each plan’s expected cash flows to interest rates and expected maturity values of individually selected bonds in a hypothetical portfolio. The model controls the level of accumulated surplus that may result from the selection of bonds based solely on their premium yields by limiting the number of years to look back for selection to 3 years for pre-30-year and 6 years for post-30-year benefit payments. Additionally, the model ensures that an adequate number of bonds are selected in the portfolio by limiting the amount of the plan’s benefit payments that can be met by a single bond to 7.5 percent.
 
We selected individual bonds from a universe of Bloomberg AA-rated bonds which:
 
§  
have an outstanding issue of at least $50 million;
 
§  
are non-callable (or callable with make whole provisions);
 
§  
exclude collateralized bonds; and
 
§  
exclude the top and bottom 10 percent of yields to avoid relying on bonds which might be mispriced or misgraded.
 
This selection methodology also mitigates the impact of market volatility on the portfolio by excluding bonds with the following characteristics:
 
§  
The issuer is on review for downgrade by a major rating agency if the downgrade would eliminate the issuer from the portfolio.
 
§  
Recent events have caused significant price volatility to which rating agencies have not reacted.
 
§  
Lack of liquidity is causing price quotes to vary significantly from broker to broker.
 
We believe that this bond selection approach provides the best estimate of discount rates to estimate settlement values for our plans’ benefit obligations as required by the applicable GAAP.
 
We develop the discount rate assumptions for the plans at Chilquinta Energía based on 10-year Chilean government bond yields and the expected local long-term rate of inflation. This method for developing the discount rate is required when there is no deep market for high quality corporate bonds.

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

The significant assumptions affecting benefit obligation and net periodic benefit cost are as follows:
 
WEIGHTED-AVERAGE ASSUMPTIONS
 
 
 
Pension Benefits
 
Other Postretirement
Benefits
 
 
2011 
2010 
 
2011 
2010 
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE
 
 
 
 
 
 
 
 
 
    BENEFIT OBLIGATION AS OF DECEMBER 31:
 
 
 
 
 
 
 
 
 
Discount rate
 4.95 
%
 5.61 
%
 
 5.11 
%
 5.77 
%
Rate of compensation increase
 4.50 
%
 4.50 
%
 
 (1)
 
 (1)
 
 
 
 
 
 
 
 
 
 
 
 
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET
 
 
 
 
 
 
 
 
 
    PERIODIC BENEFIT COST FOR YEARS ENDED DECEMBER 31:
 
 
 
 
 
 
 
 
 
Sempra Energy Consolidated
 
 
 
 
 
 
 
 
 
Discount rate
 (2)
 
 (3)
 
 
 (4)
 
 (5)
 
Expected return on plan assets
 7.00 
%
 7.00 
%
 
 6.25 
%
 6.22 
%
Rate of compensation increase
 (6)
 
 (6)
 
 
 (1)
 
 (1)
 
SDG&E
 
 
 
 
 
 
 
 
 
Discount rate
 (7)
 
 5.40 
%
 
 5.05 
%
 5.75 
%
Expected return on plan assets
 7.00 
%
 7.00 
%
 
 6.69 
%
 6.49 
%
Rate of compensation increase
 (8)
 
 (8)
 
 
N/A
 
N/A
 
SoCalGas
 
 
 
 
 
 
 
 
 
Discount rate
(9)
 
 5.75 
%
 
 5.15 
%
 5.90 
%
Expected return on plan assets
 7.00 
%
 7.00 
%
 
 7.00 
%
 7.00 
%
Rate of compensation increase
 (6)
 
 (6)
 
 
 (1)
 
 (1)
 
(1)
4.50% and 4.00% as of December 31, 2011 and 2010, respectively, for the life insurance and Health Reimbursement Arrangement benefits for SoCalGas’ represented employees. No other PBOP benefits are compensation-based.
(2)
In addition to rates for SDG&E and SoCalGas plans, 5.14% for Mobile Gas pension plan, 4.40% for Directors’ plan, 4.70% for other unfunded plans, and 4.90% for Sempra Energy funded plan.
(3)
In addition to rates for SDG&E and SoCalGas plans, 5.95% for Mobile Gas pension plans, 4.85% for Directors’ plan, 5.45% for other unfunded plans, and 5.55% for Sempra Energy funded plan.
(4)
In addition to rates for SDG&E and SoCalGas plans, 4.10% for the Executive Life Plan, 4.80% for Mobile Gas, and 4.65% for Sempra Energy.
(5)
In addition to rates for SDG&E and SoCalGas plans, 4.60% for the Executive Life Plan, 5.70% for Mobile Gas, and 5.40% for Sempra Energy.
(6)
4.50% for the unfunded pension plans. 3.50% to 5.00% for the funded pension plan for SoCalGas’ represented participants and 3.50% to 8.50% for all the other funded pension plans’ participants using an age-based formula.
(7)
4.70% for the unfunded pension plan. 4.80% for the funded pension plan.
(8)
4.50% for the unfunded pension plan. 3.50% to 8.50% for the funded pension plan using an age-based formula.
(9)
4.70% for the unfunded pension plan. 5.05% for the funded pension plan.
 
Health Care Cost Trend Rates
 
Assumed health-care cost trend rates have a significant effect on the amounts that we report for the health care plan costs. Following are the health-care cost trend rates applicable to our postretirement benefit plans:
 
 
 
2011 
2010 
ASSUMED HEALTH CARE COST TREND RATES AT DECEMBER 31:
 
 
 
 
Health-care cost trend rate
 10.00 
%
 8.50 
%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)
 5.00 
%
 5.50 
%
Year that the rate reaches the ultimate trend
2019 
 
2016 
 
 
 

 

A one-percent change in assumed health care cost trend rates would have the following effects:
 
 
Sempra Energy
 
 
 
 
 
Consolidated
 
SDG&E
 
SoCalGas
 
1%
1%
 
1%
1%
 
1%
1%
(Dollars in millions)
Increase
Decrease
 
Increase
Decrease
 
Increase
Decrease
Effect on total of service and interest
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    cost components of net periodic
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    postretirement health care benefit cost
$
 13 
$
 (10)
 
$
 1 
$
 (1)
 
$
 12 
$
 (9)
Effect on the health care component of the
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    accumulated other postretirement
 
 
 
 
 
 
 
 
 
 
 
 
 
 
    benefit obligations
$
 116 
$
 (95)
 
$
 9 
$
 (8)
 
$
 105 
$
 (85)
 
Plan Assets
 
 
Investment Allocation Strategy for Sempra Energy’s Pension Master Trust
 
Sempra Energy’s pension master trust holds the investments for the pension and other postretirement benefit plans. We maintain additional trusts as we discuss below for certain of the Sempra Utilities’ other postretirement plans. Other than index weight, the trusts do not invest in securities of Sempra Energy.
 
The current asset allocation objective for the pension master trust is to protect the funded status of the plans while generating sufficient returns to cover future benefit payments and accruals. We assess the portfolio performance by comparing actual returns with relevant benchmarks, such as the Morgan Stanley Capital International (MSCI) US Investable Index, the MSCI Pacific Rim and Europe Indices, the MSCI Emerging Markets Index, and the Barclays Aggregate and Long Government Credit Indices.
 
Primarily passive investment strategies were used for both the equity and fixed income portions of the asset allocation in 2010, and active management was added in 2011 to achieve risk and return exposures consistent with these indices. The fixed income asset allocation consists of some longer-duration fixed income securities in order to reduce plan exposure to interest rate variation. The foreign equity components provide a growth element, diversification and exposure to different currencies and economies.
 
The asset allocation of the plans is reviewed by our Pension and Benefits Investment Committee (the Committee) on a regular basis. When evaluating its strategic asset allocation, the Committee considers many variables, including:
 
§  
long-term cost
 
§  
variability and level of contributions
 
§  
funded status
 
§  
a range of expected outcomes over varying confidence levels
 
We maintain allocations at strategic levels with reasonable bands of variance. When asset class exposure reaches a minimum or maximum level, we generally rebalance the portfolio back to target allocations, unless the Committee determines otherwise.
 
 
Rate of Return Assumption
 
For all plans except the SDG&E postretirement health plans, we base the long-term rate of return assumption on the asset-weighted-average of the expected return for each asset class. We develop the expected returns from examining periods of historical returns and expectations for future returns from several investment and actuarial consultants. Specifically, we reached a 7.0 percent return expectation by assuming a 4.5 percent yield/return on a risk-free bond portfolio (treasury securities), adding a 50 basis point risk premium for our investment grade bond portfolio and another 300 basis point risk premium for equity securities. A 65 percent equity/35 percent fixed income mix results in a total portfolio return expectation of approximately 7.0 percent.
 
The expected rate of return for the SDG&E postretirement health plan assets is the weighted average of the assumed rate of return for those plan assets in the pension master trust and the Voluntary Employee Beneficiary Association (VEBA) trust for the collectively bargained plan developed using the methodology described above, and the rate of return for the assets of the non-collectively bargained plans described below. The rate of return for the assets of the non-collectively bargained plan is based on the weighted average after-tax expected return of the portfolio’s target asset allocation of 35 percent equity/65 percent fixed income. The fixed-income portfolio is invested in tax-exempt municipal bond securities, while the equity portfolio is invested 25 percent Standard & Poor’s (S&P) 500 index/5 percent MSCI Index for equity market performance in Europe, Australasia and Far East (MSCI EAFE index).
 
 
Concentration of Risk
 
Plan assets are fully diversified across global equity and bond markets, and other than what is indicated by the target asset allocations, contain no concentration of risk in any one economic, industry, maturity, or geographic sector.
 
 
Investment Strategy for SoCalGas’ Other Postretirement Benefit Plans
 
SoCalGas’ other postretirement benefit plans are funded by cash contributions from SoCalGas and current retirees. The assets of these plans are placed in the pension master trust and other VEBA trusts, as we detail below. The assets in the VEBA trusts are invested at identical allocations to the pension master trust, 65 percent equities/35 percent fixed income, using primarily index funds. This allocation has been formulated to best suit the long-term nature of the obligations.
 
 
Investment Strategy for SDG&E’s Postretirement Health Plans
 
SDG&E’s postretirement health plans are funded by cash contributions from SDG&E and current retirees. The assets are placed in the pension master trust and a VEBA trust, as we detail below. Assets in the pension master trust are invested at the 70 percent equity/30 percent fixed income mix using index funds. Assets in the VEBA trust for non-collectively bargained post retirement health and welfare benefit plans are taxable and therefore have a different asset allocation strategy. These assets are invested with a target asset allocation of 30 percent equity/70 percent fixed income, with a large portion of the bond portfolio placed in actively managed tax-exempt municipal bonds. The equity portfolio is indexed.
 
 
Fair Value of Pension and Other Postretirement Benefit Plan Assets
 
We classify the investments in Sempra Energy’s pension master trust and the trusts for the Sempra Utilities’ other postretirement benefit plans into:
 
§  
Level 1, for securities valued using quoted prices from active markets for identical assets;
 
§  
Level 2, for securities not traded on an active market but for which observable market inputs are readily available; and
 
§  
Level 3, for securities and investments valued based on significant inputs that are generally less observable from objective sources.
 
We provide more discussion of fair value measurements in Notes 1, 2 and 11. The following tables set forth by level within the fair value hierarchy a summary of the investments in our pension and other postretirement benefit plan trusts measured at fair value on a recurring basis.
 

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

FAIR VALUE MEASUREMENTS — SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
 
 
At fair value as of December 31, 2011
PENSION PLANS - INVESTMENT ASSETS
 
Level 1
 
Level 2
 
Level 3
 
Total
SDG&E (see table below)
$
 466 
$
 244 
$
 7 
$
 717 
SoCalGas (see table below)
 
 919 
 
 484 
 
 15 
 
 1,418 
Other Sempra Energy
 
 
 
 
 
 
 
 
Equity securities:
 
 
 
 
 
 
 
 
   Domestic large-cap(1)
 
 50 
 
 ― 
 
 ― 
 
 50 
   Domestic mid-cap(1)
 
 10 
 
 ― 
 
 ― 
 
 10 
   Domestic small-cap(1)
 
 12 
 
 ― 
 
 ― 
 
 12 
   Foreign large-cap
 
 32 
 
 ― 
 
 ― 
 
 32 
   Foreign mid-cap
 
 7 
 
 ― 
 
 ― 
 
 7 
   Foreign small-cap
 
 6 
 
 ― 
 
 ― 
 
 6 
   Foreign preferred small-cap
 
 1 
 
 ― 
 
 ― 
 
 1 
   Registered investment companies
 
 1 
 
 ― 
 
 ― 
 
 1 
Fixed income securities:
 
 
 
 
 
 
 
 
   Domestic municipal bonds
 
 ― 
 
 2 
 
 ― 
 
 2 
   Foreign government bonds
 
 ― 
 
 5 
 
 ― 
 
 5 
   Domestic corporate bonds(2)
 
 ― 
 
 36 
 
 ― 
 
 36 
   Foreign corporate bonds
 
 ― 
 
 12 
 
 ― 
 
 12 
   Common/collective trusts(3)
 
 ― 
 
 6 
 
 ― 
 
 6 
Other types of investments:
 
 
 
 
 
 
 
 
   Private equity funds(4) (stated at net asset value)
 
 1 
 
 ― 
 
 2 
 
 3 
Total other Sempra Energy(5)
 
 120 
 
 61 
 
 2 
 
 183 
Total Sempra Energy Consolidated(6)
$
 1,505 
$
 789 
$
 24 
$
 2,318 
 
 
 
 
 
 
 
 
 
 
 
 
At fair value as of December 31, 2010
PENSION PLANS - INVESTMENT ASSETS
 
Level 1
 
Level 2
 
Level 3
 
Total
SDG&E (see table below)
$
 450 
$
 245 
$
 8 
$
 703 
SoCalGas (see table below)
 
 924 
 
 501 
 
 17 
 
 1,442 
Other Sempra Energy
 
 
 
 
 
 
 
 
Equity securities:
 
 
 
 
 
 
 
 
   Domestic large-cap(1)
 
 54 
 
 ― 
 
 ― 
 
 54 
   Domestic mid-cap(1)
 
 11 
 
 ― 
 
 ― 
 
 11 
   Domestic small-cap(1)
 
 12 
 
 ― 
 
 ― 
 
 12 
   Foreign emerging market funds
 
 ― 
 
 13 
 
 ― 
 
 13 
   Foreign large-cap
 
 31 
 
 ― 
 
 ― 
 
 31 
   Foreign mid-cap
 
 8 
 
 ― 
 
 ― 
 
 8 
   Foreign small-cap
 
 5 
 
 ― 
 
 ― 
 
 5 
Fixed income securities:
 
 
 
 
 
 
 
 
   U.S. Treasury securities
 
 5 
 
 ― 
 
 ― 
 
 5 
   Other U.S. government securities
 
 ― 
 
 9 
 
 ― 
 
 9 
   Domestic municipal bonds
 
 ― 
 
 2 
 
 ― 
 
 2 
   Foreign government bonds
 
 ― 
 
 2 
 
 ― 
 
 2 
   Domestic corporate bonds(2)
 
 ― 
 
 31 
 
 ― 
 
 31 
   Foreign corporate bonds
 
 ― 
 
 9 
 
 ― 
 
 9 
   Common/collective trusts(3)
 
 ― 
 
 3 
 
 ― 
 
 3 
Other types of investments:
 
 
 
 
 
 
 
 
   Private equity funds(4) (stated at net asset value)
 
 ― 
 
 ― 
 
 2 
 
 2 
Total other Sempra Energy(7)
 
 126 
 
 69 
 
 2 
 
 197 
Total Sempra Energy Consolidated(6)
$
 1,500 
$
 815 
$
 27 
$
 2,342 
(1)
Investments in common stock of domestic corporations stratified according to the MSCI 2500 index.
(2)
Investment-grade bonds of U.S. issuers from diverse industries.
(3)
Investments in common/collective trusts held in Sempra Energy’s Pension Master Trust.
(4)
Investments in venture capital and real estate funds.
(5)
Excludes cash and cash equivalents of $1 million and transfers payable to other plans of $7 million.
(6)
Excludes cash and cash equivalents of $14 million and $12 million at December 31, 2011 and 2010, respectively.
(7)
Excludes transfers payable to other plans of $12 million.
 
 

FAIR VALUE MEASUREMENTS — SDG&E
(Dollars in millions)
 
 
At fair value as of December 31, 2011
PENSION PLANS - INVESTMENT ASSETS
 
Level 1
 
Level 2
 
Level 3
 
Total
Equity securities:
 
 
 
 
 
 
 
 
   Domestic large-cap(1)
$
 199 
$
 ― 
$
 ― 
$
 199 
   Domestic mid-cap(1)
 
 39 
 
 ― 
 
 ― 
 
 39 
   Domestic small-cap(1)
 
 45 
 
 ― 
 
 ― 
 
 45 
   Foreign large-cap
 
 125 
 
 ― 
 
 ― 
 
 125 
   Foreign mid-cap
 
 31 
 
 ― 
 
 ― 
 
 31 
   Foreign small-cap
 
 22 
 
 ― 
 
 ― 
 
 22 
   Foreign preferred large-cap
 
 1 
 
 ― 
 
 ― 
 
 1 
   Registered investment companies
 
 4 
 
 ― 
 
 ― 
 
 4 
Fixed income securities:
 
 
 
 
 
 
 
 
   Domestic municipal bonds
 
 ― 
 
 9 
 
 ― 
 
 9 
   Foreign government bonds
 
 ― 
 
 25 
 
 ― 
 
 25 
   Domestic corporate bonds(2)
 
 ― 
 
 139 
 
 ― 
 
 139 
   Foreign corporate bonds
 
 ― 
 
 48 
 
 ― 
 
 48 
   Common/collective trusts(3)
 
 ― 
 
 23 
 
 ― 
 
 23 
Other types of investments:
 
 
 
 
 
 
 
 
   Private equity funds(4) (stated at net asset value)
 
 ― 
 
 ― 
 
 7 
 
 7 
Total investment assets(5)
$
 466 
$
 244 
$
 7 
$
 717 
 
 
 
 
At fair value as of December 31, 2010
PENSION PLANS - INVESTMENT ASSETS
 
Level 1
 
Level 2
 
Level 3
 
Total
Equity securities:
 
 
 
 
 
 
 
 
   Domestic large-cap(1)
$
 198 
$
 ― 
$
 ― 
$
 198 
   Domestic mid-cap(1)
 
 39 
 
 ― 
 
 ― 
 
 39 
   Domestic small-cap(1)
 
 42 
 
 ― 
 
 ― 
 
 42 
   Foreign emerging market funds
 
 ― 
 
 46 
 
 ― 
 
 46 
   Foreign large-cap
 
 108 
 
 ― 
 
 ― 
 
 108 
   Foreign mid-cap
 
 25 
 
 ― 
 
 ― 
 
 25 
   Foreign small-cap
 
 19 
 
 ― 
 
 ― 
 
 19 
   Foreign preferred large-cap
 
 1 
 
 ― 
 
 ― 
 
 1 
Fixed income securities:
 
 
 
 
 
 
 
 
   U.S. Treasury securities
 
 18 
 
 ― 
 
 ― 
 
 18 
   Other U.S. government securities
 
 ― 
 
 32 
 
 ― 
 
 32 
   Domestic municipal bonds
 
 ― 
 
 8 
 
 ― 
 
 8 
   Foreign government bonds
 
 ― 
 
 9 
 
 ― 
 
 9 
   Domestic corporate bonds(2)
 
 ― 
 
 111 
 
 ― 
 
 111 
   Foreign corporate bonds
 
 ― 
 
 33 
 
 ― 
 
 33 
   Common/collective trusts(3)
 
 ― 
 
 6 
 
 ― 
 
 6 
Other types of investments:
 
 
 
 
 
 
 
 
   Private equity funds(4) (stated at net asset value)
 
 ― 
 
 ― 
 
 8 
 
 8 
Total investment assets(6)
$
 450 
$
 245 
$
 8 
$
 703 
(1)
Investments in common stock of domestic corporations stratified according to the MSCI 2500 index.
(2)
Investment-grade bonds of U.S. issuers from diverse industries.
(3)
Investments in common/collective trusts held in Sempra Energy’s Pension Master Trust.
(4)
Investments in venture capital and real estate funds.
(5)
Excludes cash and cash equivalents of $4 million and $9 million of transfers payable to other plans.
(6)
Excludes cash and cash equivalents of $4 million and transfers receivable from other plans of $6 million.

 
FAIR VALUE MEASUREMENTS — SOCALGAS
(Dollars in millions)
 
 
At fair value as of December 31, 2011
PENSION PLANS - INVESTMENT ASSETS
 
Level 1
 
Level 2
 
Level 3
 
Total
Equity securities:
 
 
 
 
 
 
 
 
   Domestic large-cap(1)
$
 393 
$
 ― 
$
 ― 
$
 393 
   Domestic mid-cap(1)
 
 76 
 
 ― 
 
 ― 
 
 76 
   Domestic small-cap(1)
 
 89 
 
 ― 
 
 ― 
 
 89 
   Foreign large-cap
 
 247 
 
 ― 
 
 ― 
 
 247 
   Foreign mid-cap
 
 61 
 
 ― 
 
 ― 
 
 61 
   Foreign small-cap
 
 43 
 
 ― 
 
 ― 
 
 43 
   Foreign preferred large-cap
 
 1 
 
 ― 
 
 ― 
 
 1 
   Registered investment companies
 
 8 
 
 ― 
 
 ― 
 
 8 
Fixed income securities:
 
 
 
 
 
 
 
 
   Domestic municipal bonds
 
 ― 
 
 18 
 
 ― 
 
 18 
   Foreign government bonds
 
 ― 
 
 49 
 
 ― 
 
 49 
   Domestic corporate bonds(2)
 
 ― 
 
 275 
 
 ― 
 
 275 
   Foreign corporate bonds
 
 ― 
 
 96 
 
 ― 
 
 96 
   Common/collective trusts(3)
 
 ― 
 
 46 
 
 ― 
 
 46 
Other types of investments:
 
 
 
 
 
 
 
 
   Private equity funds(4) (stated at net asset value)
 
 1 
 
 ― 
 
 15 
 
 16 
Total investment assets(5)
$
 919 
$
 484 
$
 15 
$
 1,418 
 
 
 
 
At fair value as of December 31, 2010
PENSION PLANS - INVESTMENT ASSETS
 
Level 1
 
Level 2
 
Level 3
 
Total
Equity securities:
 
 
 
 
 
 
 
 
   Domestic large-cap(1)
$
 409 
$
 ― 
$
 ― 
$
 409 
   Domestic mid-cap(1)
 
 80 
 
 ― 
 
 ― 
 
 80 
   Domestic small-cap(1)
 
 86 
 
 ― 
 
 ― 
 
 86 
   Foreign emerging market funds
 
 ― 
 
 95 
 
 ― 
 
 95 
   Foreign large-cap
 
 221 
 
 ― 
 
 ― 
 
 221 
   Foreign mid-cap
 
 52 
 
 ― 
 
 ― 
 
 52 
   Foreign small-cap
 
 39 
 
 ― 
 
 ― 
 
 39 
   Foreign preferred large-cap
 
 1 
 
 ― 
 
 ― 
 
 1 
Fixed income securities:
 
 
 
 
 
 
 
 
   U.S. Treasury securities
 
 36 
 
 ― 
 
 ― 
 
 36 
   Other U.S. government securities
 
 ― 
 
 65 
 
 ― 
 
 65 
   Domestic municipal bonds
 
 ― 
 
 16 
 
 ― 
 
 16 
   Foreign government bonds
 
 ― 
 
 18 
 
 ― 
 
 18 
   Domestic corporate bonds(2)
 
 ― 
 
 227 
 
 ― 
 
 227 
   Foreign corporate bonds
 
 ― 
 
 67 
 
 ― 
 
 67 
   Common/collective trusts(3)
 
 ― 
 
 13 
 
 ― 
 
 13 
Other types of investments:
 
 
 
 
 
 
 
 
   Private equity funds(4) (stated at net asset value)
 
 ― 
 
 ― 
 
 17 
 
 17 
Total investment assets(6)
$
 924 
$
 501 
$
 17 
$
 1,442 
(1)
Investments in common stock of domestic corporations stratified according to the MSCI 2500 index.
(2)
Investment-grade bonds of U.S. issuers from diverse industries.
(3)
Investments in common/collective trusts held in Sempra Energy’s Pension Master Trust.
(4)
Investments in venture capital and real estate funds.
(5)
Excludes cash and cash equivalents of $9 million and transfers receivable from other plans of $16 million.
(6)
Excludes cash and cash equivalents of $8 million and transfers receivable from other plans of $6 million.


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

FAIR VALUE MEASUREMENTS — SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
 
 
At fair value as of December 31, 2011
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS
 
Level 1
 
Level 2
 
Level 3
 
Total
SDG&E (see table below)
$
 47 
$
 24 
$
 1 
$
 72 
SoCalGas (see table below)
 
 176 
 
 390 
 
 3 
 
 569 
Other Sempra Energy
 
 
 
 
 
 
 
 
Equity securities:
 
 
 
 
 
 
 
 
   Domestic large-cap(1)
 
 4 
 
 ― 
 
 ― 
 
 4 
   Domestic mid-cap(1)
 
 1 
 
 ― 
 
 ― 
 
 1 
   Domestic small-cap(1)
 
 1 
 
 ― 
 
 ― 
 
 1 
   Foreign large-cap
 
 2 
 
 ― 
 
 ― 
 
 2 
   Foreign small-cap
 
 1 
 
 ― 
 
 ― 
 
 1 
Fixed income securities:
 
 
 
 
 
 
 
 
   Domestic corporate bonds(2)
 
 ― 
 
 4 
 
 ― 
 
 4 
   Foreign government bonds
 
 ― 
 
 1 
 
 ― 
 
 1 
   Foreign corporate bonds
 
 ― 
 
 1 
 
 ― 
 
 1 
Total other Sempra Energy(3)
 
 9 
 
 6 
 
 ― 
 
 15 
Total Sempra Energy Consolidated(4)
$
 232 
$
 420 
$
 4 
$
 656 
 
 
 
 
 
 
 
 
 
 
 
 
At fair value as of December 31, 2010
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS
 
Level 1
 
Level 2
 
Level 3
 
Total
SDG&E (see table below)
$
 45 
$
 24 
$
 1 
$
 70 
SoCalGas (see table below)
 
 184 
 
 395 
 
 3 
 
 582 
Other Sempra Energy
 
 
 
 
 
 
 
 
Equity securities:
 
 
 
 
 
 
 
 
   Domestic large-cap(1)
 
 3 
 
 ― 
 
 ― 
 
 3 
   Domestic mid-cap(1)
 
 1 
 
 ― 
 
 ― 
 
 1 
   Domestic small-cap(1)
 
 1 
 
 ― 
 
 ― 
 
 1 
   Foreign large-cap
 
 2 
 
 ― 
 
 ― 
 
 2 
   Foreign mid-cap
 
 1 
 
 ― 
 
 ― 
 
 1 
   Foreign small-cap
 
 1 
 
 ― 
 
 ― 
 
 1 
Fixed income securities:
 
 
 
 
 
 
 
 
   U.S. Treasury securities
 
 1 
 
 ― 
 
 ― 
 
 1 
   Domestic corporate bonds(2)
 
 ― 
 
 3 
 
 ― 
 
 3 
Total other Sempra Energy(5)
 
 10 
 
 3 
 
 ― 
 
 13 
Total Sempra Energy Consolidated(6)
$
 239 
$
 422 
$
 4 
$
 665 
(1)
Investments in common stock of domestic corporations stratified according to the MSCI 2500 index.
(2)
Investment-grade bonds of U.S. issuers from diverse industries.
(3)
Excludes transfers payable to other plans of $1 million.
(4)
Excludes cash and cash equivalents of $122 million, $86 million and $36 million of which is held in SoCalGas and SDG&E
 
PBOP plan trusts, respectively.
(5)
Excludes cash and cash equivalents of $2 million.
(6)
Excludes cash and cash equivalents of $81 million, $50 million and $29 million of which is held in SoCalGas and SDG&E
 
PBOP plan trusts, respectively.
 
 
 
 
 
 
 
 
 
 
 



FAIR VALUE MEASUREMENTS — SDG&E
(Dollars in millions)
 
 
At fair value as of December 31, 2011
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS
 
Level 1
 
Level 2
 
Level 3
 
Total
Equity securities:
 
 
 
 
 
 
 
 
   Domestic large-cap(1)
$
 17 
$
 ― 
$
 ― 
$
 17 
   Domestic mid-cap(1)
 
 3 
 
 ― 
 
 ― 
 
 3 
   Domestic small-cap(1)
 
 4 
 
 ― 
 
 ― 
 
 4 
   Foreign large-cap
 
 11 
 
 ― 
 
 ― 
 
 11 
   Foreign mid-cap
 
 3 
 
 ― 
 
 ― 
 
 3 
   Foreign small-cap
 
 2 
 
 ― 
 
 ― 
 
 2 
   Registered investment company
 
 7 
 
 ― 
 
 ― 
 
 7 
Fixed income securities:
 
 
 
 
 
 
 
 
   Domestic municipal bonds(2)
 
 ― 
 
 4 
 
 ― 
 
 4 
   Domestic corporate bonds(3)
 
 ― 
 
 12 
 
 ― 
 
 12 
   Foreign government bonds
 
 ― 
 
 2 
 
 ― 
 
 2 
   Foreign corporate bonds
 
 ― 
 
 4 
 
 ― 
 
 4 
   Common/collective trusts(4)
 
 ― 
 
 2 
 
 ― 
 
 2 
Other types of investments:
 
 
 
 
 
 
 
 
   Private equity funds(5) (stated at net asset value)
 
 ― 
 
 ― 
 
 1 
 
 1 
Total investment assets(6)
$
 47 
$
 24 
$
 1 
$
 72 
 
 
 
 
 
 
 
 
 
 
 
 
At fair value as of December 31, 2010
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS
 
Level 1
 
Level 2
 
Level 3
 
Total
Equity securities:
 
 
 
 
 
 
 
 
   Domestic large-cap(1)
$
 16 
$
 ― 
$
 ― 
$
 16 
   Domestic mid-cap(1)
 
 3 
 
 ― 
 
 ― 
 
 3 
   Domestic small-cap(1)
 
 3 
 
 ― 
 
 ― 
 
 3 
   Foreign emerging market funds
 
 ― 
 
 4 
 
 ― 
 
 4 
   Foreign large-cap
 
 8 
 
 ― 
 
 ― 
 
 8 
   Foreign mid-cap
 
 2 
 
 ― 
 
 ― 
 
 2 
   Foreign small-cap
 
 1 
 
 ― 
 
 ― 
 
 1 
   Registered investment company
 
 11 
 
 ― 
 
 ― 
 
 11 
Fixed income securities:
 
 
 
 
 
 
 
 
   U.S. Treasury securities
 
 1 
 
 ― 
 
 ― 
 
 1 
   Other U.S. government securities
 
 ― 
 
 2 
 
 ― 
 
 2 
   Foreign government  bonds
 
 ― 
 
 1 
 
 ― 
 
 1 
   Domestic municipal bonds(2)
 
 ― 
 
 6 
 
 ― 
 
 6 
   Domestic corporate bonds(3)
 
 ― 
 
 9 
 
 ― 
 
 9 
   Foreign corporate bonds
 
 ― 
 
 2 
 
 ― 
 
 2 
Other types of investments:
 
 
 
 
 
 
 
 
   Private equity funds(5) (stated at net asset value)
 
 ― 
 
 ― 
 
 1 
 
 1 
Total investment assets(7)
$
 45 
$
 24 
$
 1 
$
 70 
(1)
Investments in common stock of domestic corporations stratified according to the MSCI 2500 index.
(2)
Bonds of California municipalities held in SDG&E PBOP plan trusts.
(3)
Investment-grade bonds of U.S. issuers from diverse industries.
(4)
Investment in common/collective trusts held in PBOP plan VEBA trusts.
 
 
 
 
 
 
 
(5)
Investments in venture capital and real estate funds.
(6)
Excludes cash and cash equivalents of $36 million, all of which is held in SDG&E PBOP plan trusts, and transfers payable to other plans of $2 million.
(7)
Excludes cash and cash equivalents of $29 million, all of which is held in SDG&E PBOP plan trusts.



FAIR VALUE MEASUREMENTS — SOCALGAS
(Dollars in millions)
 
 
At fair value as of December 31, 2011
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS
 
Level 1
 
Level 2
 
Level 3
 
Total
Equity securities:
 
 
 
 
 
 
 
 
   Domestic large-cap(1)
$
 75 
$
 ― 
$
 ― 
$
 75 
   Domestic mid-cap(1)
 
 15 
 
 ― 
 
 ― 
 
 15 
   Domestic small-cap(1)
 
 17 
 
 ― 
 
 ― 
 
 17 
   Foreign large-cap
 
 47 
 
 ― 
 
 ― 
 
 47 
   Foreign mid-cap
 
 12 
 
 ― 
 
 ― 
 
 12 
   Foreign small-cap
 
 8 
 
 ― 
 
 ― 
 
 8 
   Registered investment company
 
 2 
 
 ― 
 
 ― 
 
 2 
Fixed income securities:
 
 
 
 
 
 
 
 
   Domestic municipal bonds
 
 ― 
 
 3 
 
 ― 
 
 3 
   Foreign government bonds
 
 ― 
 
 9 
 
 ― 
 
 9 
   Domestic corporate bonds(2)
 
 ― 
 
 52 
 
 ― 
 
 52 
   Foreign corporate bonds
 
 ― 
 
 18 
 
 ― 
 
 18 
   Common/collective trusts(3)
 
 ― 
 
 308 
 
 ― 
 
 308 
Other types of investments:
 
 
 
 
 
 
 
 
   Private equity funds(4) (stated at net asset value)
 
 ― 
 
 ― 
 
 3 
 
 3 
Total investment assets(5)
$
 176 
$
 390 
$
 3 
$
 569 
 
 
 
 
 
 
 
 
 
 
 
 
At fair value as of December 31, 2010
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS
 
Level 1
 
Level 2
 
Level 3
 
Total
Equity securities:
 
 
 
 
 
 
 
 
   Domestic large-cap(1)
$
 82 
$
 ― 
$
 ― 
$
 82 
   Domestic mid-cap(1)
 
 16 
 
 ― 
 
 ― 
 
 16 
   Domestic small-cap(1)
 
 17 
 
 ― 
 
 ― 
 
 17 
   Foreign emerging market funds
 
 ― 
 
 19 
 
 ― 
 
 19 
   Broad market fund(6)
 
 ― 
 
 220 
 
 ― 
 
 220 
   Foreign large-cap
 
 44 
 
 ― 
 
 ― 
 
 44 
   Foreign mid-cap
 
 10 
 
 ― 
 
 ― 
 
 10 
   Foreign small-cap
 
 8 
 
 ― 
 
 ― 
 
 8 
Fixed income securities:
 
 
 
 
 
 
 
 
   U.S. Treasury securities
 
 7 
 
 ― 
 
 ― 
 
 7 
   Other U.S. government securities
 
 ― 
 
 14 
 
 ― 
 
 14 
   Domestic municipal bonds
 
 ― 
 
 3 
 
 ― 
 
 3 
   Foreign government bonds
 
 ― 
 
 3 
 
 ― 
 
 3 
   Domestic corporate bonds(2)
 
 ― 
 
 45 
 
 ― 
 
 45 
   Foreign corporate bonds
 
 ― 
 
 14 
 
 ― 
 
 14 
   Common/collective trusts(3)
 
 ― 
 
 77 
 
 ― 
 
 77 
Other types of investments:
 
 
 
 
 
 
 
 
   Private equity funds(4) (stated at net asset value)
 
 ― 
 
 ― 
 
 3 
 
 3 
Total investment assets(7)
$
 184 
$
 395 
$
 3 
$
 582 
(1)
Investments in common stock of domestic corporations stratified according to the MSCI 2500 index.
(2)
Investment-grade bonds of U.S. issuers from diverse industries.
(3)
Investments in common/collective trusts held in PBOP plan VEBA trusts.
(4)
Investments in venture capital and real estate funds.
(5)
Excludes cash and cash equivalents of $86 million, all of which is held in SoCalGas PBOP plan trusts, and transfers receivable from other plans of $3 million.
(6)
A passively managed broad market fund held in SoCalGas PBOP plan trusts.
(7)
Excludes cash and cash equivalents of $50 million, all of which is held in SoCalGas PBOP plan trusts.


The investments of the pension master trust allocated to the pension and postretirement benefit plans classified as Level 3 are private equity funds and represent a percentage of each plan’s total allocated assets as follows at December 31:
 
 
Private Equity Funds
 
2011 
 
2010 
(Dollars in millions)
SDG&E
SoCalGas
All Other
Sempra Energy Consolidated
 
SDG&E
SoCalGas
All Other
Sempra Energy Consolidated
PENSION PLANS
 
 
 
 
 
 
 
 
 
Total Level 3 investment
    assets
$7
$15
$2
$24
 
$8
$17
$2
$27
Percentage of total
    investment assets
1%
1%
-%
1%
 
1%
1%
-%
1%
OTHER POSTRETIREMENT
 BENEFIT PLANS
 
 
 
 
 
Total Level 3 investment
    assets
$1
$3
$-
$4
 
$1
$3
$-
$4
Percentage of total
    investment assets
1%
-%
-%
1%
 
1%
-%
-%
1%

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

 
Valuation Techniques Used to Determine Fair Value
 
The following descriptions of the valuation methods and assumptions used to estimate the fair values of investments apply to investments held directly by the plans and those held as underlying investments of the master trust:
 
Equity Securities — Equity securities are valued using quoted prices listed on nationally recognized securities exchanges.
 
Fixed Income Securities — Certain fixed income securities are valued at the closing price reported in the active market in which the security is traded. Other fixed income securities are valued based on yields currently available on comparable securities of issuers with similar credit ratings. When quoted prices are not available for identical or similar securities, the security is valued under a discounted cash flows approach that maximizes observable inputs, such as current yields of similar instruments, but includes adjustments for certain risks that may not be observable, such as credit and liquidity risks.
 
Common/Collective Trusts — Investments in common/collective trust funds are valued based on the redemption price of units owned, which is based on the current fair value of the fund’s underlying assets.
 
Private Equity Funds — Investments in private equity funds do not trade in active markets. Fair value is determined by the fund managers, based upon their review of the underlying investments as well as their utilization of discounted cash flows and other valuation models.
 
Real Estate — Real estate investments are valued on the basis of a discounted cash flow approach, which includes the future rental receipts, expenses, and residual values for the highest and best use of the real estate from a market participant view as rental property.
 
The methods described are intended to produce a fair value calculation that is indicative of net realizable value or reflective of future fair values. However, while management believes the valuation methods are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date.
 
Derivative Financial Instruments
 
In accordance with the Sempra Energy pension investment guidelines, derivative financial instruments are used by the pension master trust’s equity and fixed income portfolio investment managers. Futures and foreign currency exchange contracts are used primarily to rebalance the fixed income/equity allocation of the pension master trust’s portfolio and to hedge all or a portion of the currency risk component of the foreign equity investments. Currency hedge positions are not permitted to exceed the level of underlying foreign security exposure in the pension master trust’s related assets. Some of the fixed income investment managers are permitted to use certain specified types of derivative instruments as part of their respective strategies. These strategies include the use of futures and options as substitutes for certain types of fixed income securities. During 2011 and 2010, the pension master trust owned shares in funds that held futures contracts and foreign currency forward contracts. In 2011 and 2010, such funds in which the pension master trust owned shares were the S&P 1500 Index and the Foreign Equity Index managed by Barclay’s Global Investors. As these futures contracts are not held directly by the pension master trust, they are not included in the following discussion.
 
At December 31, 2011 and 2010, the pension master trust did not directly hold any futures or currency forward contracts. As we discuss above, interest rate swaps are used indirectly through an index fund in the pension master trust.
 
 
Future Payments
 
We expect to contribute the following amounts to our pension and other postretirement benefit plans in 2012:
 
 
Sempra Energy
 
 
(Dollars in millions)
Consolidated
SDG&E
SoCalGas
Pension plans
$
 215 
$
 67 
$
 113 
Other postretirement benefit plans
 
 59 
 
 14 
 
 40 

The following table shows the total benefits we expect to pay for the next 10 years to current employees and retirees from the plans or from company assets.
 
 
Sempra Energy Consolidated
 
SDG&E
 
SoCalGas
 
 
Other
 
 
Other
 
 
Other
 
Pension
Postretirement
 
Pension
Postretirement
 
Pension
Postretirement
(Dollars in millions)
Benefits
Benefits
 
Benefits
Benefits
 
Benefits
Benefits
2012 
$
 302 
$
 49 
 
$
 89 
$
 7 
 
$
 173 
$
 37 
2013 
 
 309 
 
 52 
 
 
 91 
 
 8 
 
 
 183 
 
 40 
2014 
 
 313 
 
 56 
 
 
 91 
 
 9 
 
 
 185 
 
 43 
2015 
 
 304 
 
 60 
 
 
 89 
 
 10 
 
 
 179 
 
 46 
2016 
 
 302 
 
 64 
 
 
 82 
 
 11 
 
 
 182 
 
 49 
2017-2021
 
 1,344 
 
 373 
 
 
 377 
 
 67 
 
 
 806 
 
 283 


 
PROFIT SHARING PLANS
 
Under Chilean law, Chilquinta Energía is required to pay all employees either (1) 30 percent of Chilquinta Energía’s taxable income after deducting a 10 percent return on equity, allocated in proportion to the annual salary of each employee or (2) 25 percent of each employee’s annual salary, with a maximum mandatory profit sharing of 4.75 months of Chile’s legal minimum salary. Chilquinta Energía has elected the second option but calculates the profit sharing amounts with actual employee salaries instead of the legal minimum salary, resulting in a higher cost. The amounts are paid out each pay period. Chilquinta Energía recorded annual profit sharing expense of $5 million for 2011 related to this plan.
 
Under Peruvian law, Luz del Sur is required to pay their employees 5 percent of Luz del Sur’s taxable income, paid once a year and allocated as follows: 50 percent based on each employee’s annual hours worked and 50 percent based on each employee’s annual salary. Luz del Sur recorded annual profit sharing expense of $9 million for 2011 related to this plan.
 
SAVINGS PLANS
 
Sempra Energy offers trusteed savings plans to all domestic employees. Participation in the plans is immediate for salary deferrals for all employees except for the represented employees at SoCalGas, who are eligible upon completion of one year of service. Subject to plan provisions, employees may contribute from one percent to 25 percent of their regular earnings when they begin employment. After one year of the employee’s completed service, Sempra Energy makes matching contributions. Employer contribution amounts and methodology vary by plan, but generally the contributions are equal to 50 percent of the first 6 percent of eligible base salary contributed by employees and, if certain company goals are met, an additional amount related to incentive compensation payments.
 
Employer contributions are initially invested in Sempra Energy common stock, but the employee may transfer the contribution to other investments. Employee contributions are invested in Sempra Energy common stock, mutual funds or institutional trusts (the same investments to which employees may direct the employer contributions), which the employee selects. In Sempra Energy plans, employee contributions may also be invested in guaranteed investment contracts. Employer contributions for substantially all plans are partially funded by the ESOP referred to below.
 
Contributions to the savings plans were as follows:
 

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

The market value of Sempra Energy common stock held by the savings plans was $883 million and $847 million at December 31, 2011 and 2010, respectively.
 
 
EMPLOYEE STOCK OWNERSHIP PLAN
 
All contributions to the ESOP Trust (described in Note 5) are made by Sempra Energy; there are no contributions made by the participants. As Sempra Energy makes contributions, the ESOP debt service is paid and shares are released in proportion to the total expected debt service. We charge compensation expense and credit equity for the market value of the released shares. Dividends on unallocated shares are used to pay debt service and are applied against the liability. The shares held by the Trust are unallocated and consist of 0.2 million shares of Sempra Energy common stock with a fair value of $8 million at December 31, 2011, and 0.5 million shares of Sempra Energy common stock with a fair value of $27 million at December 31, 2010.
 


 

NOTE 9. SHARE-BASED COMPENSATION
 

 
SEMPRA ENERGY EQUITY COMPENSATION PLANS
 
Sempra Energy has share-based compensation plans intended to align employee and shareholder objectives related to the long-term growth of Sempra Energy. The plans permit a wide variety of share-based awards, including:
 
§  
non-qualified stock options
 
§  
incentive stock options
 
§  
restricted stock
 
§  
restricted stock units
 
§  
stock appreciation rights
 
§  
performance awards
 
§  
stock payments
 
§  
dividend equivalents
 
Eligible Sempra Utilities employees participate in Sempra Energy’s share-based compensation plans as a component of their compensation package.
 
At December 31, 2011, Sempra Energy had the following types of equity awards outstanding:
 
§  
Non-Qualified Stock Options: Options have an exercise price equal to the market price of the common stock at the date of grant, are service-based, become exercisable over a four-year period, and expire 10 years from the date of grant. Vesting and/or the ability to exercise may be accelerated upon a change in control, in accordance with severance pay agreements or upon eligibility for retirement. Options are subject to forfeiture or earlier expiration when an employee terminates employment.
§  
Restricted Stock: Substantially all restricted stock awards vest at the end of four-year performance periods based on Sempra Energy’s total return to shareholders relative to that of market indices. Vesting is subject to earlier forfeiture upon termination of employment and accelerated vesting upon a change in control, in accordance with severance pay agreements or upon eligibility for retirement. Holders of restricted stock have full voting rights. They also have full dividend rights; however, dividends paid on restricted stock held by officers are reinvested to purchase additional shares that become subject to the same vesting conditions as the restricted stock to which the dividends relate.
§  
Restricted Stock Units: Restricted stock unit awards vest at the end of four-year performance periods based on Sempra Energy’s total return to shareholders relative to that of market indices. If Sempra Energy’s total return to shareholders exceeds the target levels established under the 2008 Long Term Incentive Plan for awards granted beginning in 2008 and each year since, up to an additional 50 percent of the number of granted restricted stock units may be issued. If Sempra Energy’s total return to shareholders is below the target levels, shares are subject to partial vesting on a pro rata basis. Vesting is subject to earlier forfeiture upon termination of employment and accelerated vesting upon a change in control, in accordance with severance pay agreements or upon eligibility for retirement. Dividend equivalents on shares subject to restricted stock units are reinvested to purchase additional shares that become subject to the same vesting conditions as the restricted stock units to which the dividends relate.
 
The Sempra Energy 2008 Long Term Incentive Plan for EnergySouth, Inc. Employees and Other Eligible Individuals (the Plan) authorizes the issuance of up to 302,478 shares of Sempra Energy common stock. In connection with the acquisition of EnergySouth, Inc. in October 2008, we adopted the Plan to utilize the shares remaining available for future awards under the 2008 Incentive Plan of EnergySouth, Inc. (the Prior Plan). All awards outstanding under the Prior Plan at the time of the acquisition were canceled, and the holders were paid the merger consideration in accordance with the terms of the merger agreement. The Plan provides for the grant of substantially the same types of share-based awards (other than incentive stock options) that are available under the Sempra Energy 2008 Long Term Incentive Plan.
 
 
SHARE-BASED AWARDS AND COMPENSATION EXPENSE
 
We measure and recognize compensation expense for all share-based payment awards made to our employees and directors based on estimated fair values on the date of grant. We recognize compensation costs net of an estimated forfeiture rate (based on historical experience) and recognize the compensation costs for non-qualified stock options and restricted stock and stock units on a straight-line basis over the requisite service period of the award, which is generally four years. However, in the year that an employee becomes eligible for retirement, the remaining expense related to the employee’s awards is recognized immediately. Substantially all awards outstanding are classified as equity instruments, therefore we recognize additional paid in capital as we recognize the compensation expense associated with the awards.
 
As of December 31, 2011, 2,555,427 shares were authorized and available for future grants of share-based awards. Our practice is to satisfy share-based awards by issuing new shares rather than by open-market purchases.
 
Total share-based compensation expense for all of Sempra Energy’s share-based awards was comprised as follows:
 
SHARE-BASED COMPENSATION EXPENSE ― SEMPRA ENERGY CONSOLIDATED
(Dollars in millions, except per share amounts)
 
Years ended December 31,
 
2011 
2010 
2009 
Share-based compensation expense, before income taxes
$
 44 
$
 34 
$
 34 
Income tax benefit
 
 (18)
 
 (13)
 
 (13)
Share-based compensation expense, net of income taxes
$
 26 
$
 21 
$
 21 
 
 
 
 
 
 
 
Net share-based compensation expense, per common share
 
 
 
 
 
 
    Basic
$
 0.11 
$
 0.09 
$
 0.09 
    Diluted
$
 0.11 
$
 0.08 
$
 0.08 

Sempra Energy Consolidated’s capitalized compensation cost was $4 million in 2011, $3 million in 2010 and $5 million in 2009.
 
We classify the tax benefits resulting from tax deductions in excess of the tax benefit related to compensation cost recognized for stock option exercises as financing cash flows.
 
Sempra Energy subsidiaries record an expense for the plans to the extent that subsidiary employees participate in the plans and/or the subsidiaries are allocated a portion of the Sempra Energy plans’ corporate staff costs. Expenses and capitalized compensation costs recorded by SDG&E and SoCalGas were as follows:
 
SHARE-BASED COMPENSATION EXPENSE ― SDG&E AND SOCALGAS
(Dollars in millions)
 
Years ended December 31,
 
2011 
2010 
2009 
SDG&E:
 
 
 
 
 
 
    Compensation expense
$
 8 
$
 9 
$
 6 
    Capitalized compensation cost
 
 3 
 
 2 
 
 3 
SoCalGas:
 
 
 
 
 
 
    Compensation expense
$
 9 
$
 8 
$
 7 
    Capitalized compensation cost
 
 1 
 
 1 
 
 2 
 
SEMPRA ENERGY NON-QUALIFIED STOCK OPTIONS
 
We use a Black-Scholes option-pricing model (Black-Scholes model) to estimate the fair value of each non-qualified stock option grant. The use of a valuation model requires us to make certain assumptions about selected model inputs. Expected volatility is calculated based on the historical volatility of Sempra Energy’s stock price. We base the average expected life for options on the contractual term of the option and expected employee exercise and post-termination behavior.
 

The risk-free interest rate is based on U.S. Treasury zero-coupon issues with a remaining term equal to the expected life assumed at the date of the grant.  No new options were granted in 2011, and the weighted-average per-share fair values for options granted in 2010 and 2009 were $7.92 and $5.29, respectively. To calculate these fair values, we used the Black-Scholes model with the following weighted-average assumptions:
 
 
2010 
2009 
Stock price volatility
19%
 
18%
 
Risk-free rate of return
2.6%
 
1.9%
 
Annual dividend yield
2.8%
 
3.2%
 
Expected life
5.5 years
 
5.6 years
 

The following table shows a summary of the non-qualified stock options as of December 31, 2011 and activity for the year then ended:
 
NON-QUALIFIED STOCK OPTIONS
 
 
 
 
Weighted-
 
 
 
Weighted-
Average
 
 
Shares
Average
Remaining
Aggregate
 
Under
Exercise
Contractual Term
Intrinsic Value
 
Option
Price
(in years)
(in millions)
Outstanding at December 31, 2010
 
 5,630,472 
$
 44.79 
 
 
 
 
    Exercised
 
 (958,126)
$
 29.41 
 
 
 
 
    Forfeited/canceled
 
 (41,375)
$
 57.75 
 
 
 
 
Outstanding at December 31, 2011
 
 4,630,971 
$
 47.85 
 
 4.9 
$
 40 
 
 
 
 
 
 
 
 
 
Vested or expected to vest, at December 31, 2011
 
 4,615,468 
$
 47.83 
 
 4.8 
$
 40 
Exercisable at December 31, 2011
 
 3,542,346 
$
 46.56 
 
 4.2 
$
 35 

The aggregate intrinsic value at December 31, 2011 is the total of the difference between Sempra Energy’s closing stock price and the exercise price for all in-the-money options. The aggregate intrinsic value for non-qualified stock options exercised in the last three years was
 
§  
$23 million in 2011
§  
$22 million in 2010
§  
$45 million in 2009
 
The total fair value of shares vested in the last three years was
 
§  
$7 million in 2011
§  
$8 million in 2010
§  
$9 million in 2009
 
The $1 million of total compensation cost related to nonvested stock options not yet recognized as of December 31, 2011 is expected to be recognized over a weighted-average period of 1.7 years.
 
We received cash from option exercises during 2011 totaling $28 million. There were no realized tax benefits for the share-based payment award deductions in 2011 over and above the $18 million income tax benefit shown above.
 

SEMPRA ENERGY RESTRICTED STOCK AWARDS AND UNITS
 
We use a Monte-Carlo simulation model to estimate the fair value of the restricted stock awards and units. Our determination of fair value is affected by the volatility of the stock price and the dividend yields for Sempra Energy and its peer group companies. The valuation also is affected by the risk-free rates of return, and a number of other variables. Below are key assumptions for Sempra Energy:
 
 
2011 
2010 
2009 
Risk-free rate of return
1.5%
 
2.1%
 
1.4%
 
Annual dividend yield
3.0%
 
2.8%
 
3.2%
 
Stock price volatility
27%
 
26%
 
25%
 
 
Restricted Stock Awards
 
We provide a summary of Sempra Energy’s restricted stock awards as of December 31, 2011 and the activity during the year below.
 
RESTRICTED STOCK AWARDS
 
 
 
Weighted-
 
 
Average
 
 
Grant-Date
 
Shares
Fair Value
Nonvested at December 31, 2010
 
 787,973 
$
 36.73 
    Granted
 
 11,876 
$
 52.96 
    Vested
 
 (775,573)
$
 36.67 
Nonvested at December 31, 2011
 
 24,276 
$
 46.51 
Vested or expected to vest, at December 31, 2011
 
 24,276 
$
 46.51 

The $1 million of total compensation cost related to nonvested restricted stock awards not yet recognized as of December 31, 2011 is expected to be recognized in 2012. The weighted-average per-share fair value for restricted stock awards granted in 2009 was $40.34.
 
The total fair value of shares vested in the last three years was
 
§  
$28 million in 2011
 
§  
$4 million in 2010
 
§  
$27 million in 2009
 
 
Restricted Stock Units
 
We provide a summary of Sempra Energy’s restricted stock units as of December 31, 2011 and the activity during the year below.
 
RESTRICTED STOCK UNITS
 
 
 
 
Weighted-
 
 
 
Average
 
 
 
Grant-Date
 
 
Units
Fair Value
Nonvested at December 31, 2010
 
 2,231,325 
$
 43.46 
    Granted
 
 1,089,223 
$
 42.35 
    Vested
 
 (10,336)
$
 50.40 
    Forfeited
 
 (17,700)
$
 42.34 
Nonvested at December 31, 2011(1)
 
 3,292,512 
$
 43.08 
Vested or expected to vest, at December 31, 2011
 
 3,231,843 
$
 43.10 
(1)
Each unit represents the right to receive one share of our common stock if applicable performance conditions are satisfied. Up to an additional 50% of the shares represented by the units may be issued if Sempra Energy exceeds target performance conditions.

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

 

NOTE 10. DERIVATIVE FINANCIAL INSTRUMENTS
 

We use derivative instruments primarily to manage exposures arising in the normal course of business. Our principal exposures are commodity market risk and benchmark interest rate risk. We may also manage foreign exchange rate exposures using derivatives. Our use of derivatives for these risks is integrated into the economic management of our anticipated revenues, anticipated expenses, assets and liabilities. Derivatives may be effective in mitigating these risks (1) that could lead to declines in anticipated revenues or increases in anticipated expenses, or (2) that our asset values may fall or our liabilities increase. Accordingly, our derivative activity summarized below generally represents an impact that is intended to offset associated revenues, expenses, assets or liabilities that are not presented below.
 
We record all derivatives at fair value on the Consolidated Balance Sheets. We designate each derivative as (1) a cash flow hedge, (2) a fair value hedge, or (3) undesignated. Depending on the applicability of hedge accounting and, for the Sempra Utilities and other operations subject to regulatory accounting, the requirement to pass impacts through to customers, the impact of derivative instruments may be offset in other comprehensive income (cash flow hedge), on the balance sheet (fair value hedges and regulatory offsets), or recognized in earnings. We classify cash flows from the settlements of derivative instruments as operating activities on the Consolidated Statements of Cash Flows.
 
In certain cases, we apply the normal purchase or sale exception to derivative accounting and have other commodity contracts that are not derivatives. These contracts are not recorded at fair value and are therefore excluded from the disclosures below.
 
 
HEDGE ACCOUNTING
 
We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accounting for derivative commodity instruments and interest rate instruments. Designating cash flow hedges is dependent on the business context in which the instrument is being used, the effectiveness of the instrument in offsetting the risk that a given future revenue or expense item may vary, and other criteria.
 
We may designate an interest rate derivative as a fair value hedging instrument if it effectively converts our own debt from a fixed interest rate to a variable rate. The combination of the derivative and debt instruments results in fixing that portion of the fair value of the debt that is related to benchmark interest rates. Designating fair value hedges is dependent on the instrument being used, the effectiveness of the instrument in offsetting changes in the fair value of our debt instruments, and other criteria.
 
 
ENERGY DERIVATIVES
 
Our market risk is primarily related to natural gas and electricity price volatility and the specific physical locations where we transact. We use energy derivatives to manage these risks. The use of energy derivatives in our various businesses depends on the particular energy market, and the operating and regulatory environments applicable to the business.
 
§  
The Sempra Utilities use natural gas energy derivatives, on their customers’ behalf, with the objective of managing price risk and basis risks, and lowering natural gas costs. These derivatives include fixed price natural gas positions, options, and basis risk instruments, which are either exchange-traded or over-the-counter financial instruments. This activity is governed by risk management and transacting activity plans that have been filed with and approved by the CPUC. Natural gas derivative activities are recorded as commodity costs that are offset by regulatory account balances and are recovered in rates. Net commodity cost impacts on the Consolidated Statements of Operations are reflected in Cost of Electric Fuel and Purchased Power or in Cost of Natural Gas.
 
§  
SDG&E is allocated and may purchase congestion revenue rights (CRRs), which serve to reduce the regional electricity price volatility risk that may result from local transmission capacity constraints. Unrealized gains and losses do not impact earnings, as they are offset by regulatory account balances. Realized gains and losses associated with CRRs are recorded in Cost of Electric Fuel and Purchased Power, which is recoverable in rates, on the Consolidated Statements of Operations.
 
§  
Sempra Generation uses natural gas and electricity instruments to market energy products and optimize the earnings of its natural gas power plants. Gains and losses associated with these undesignated derivatives are recognized in Energy-Related Businesses Revenues or in Cost of Natural Gas, Electric Fuel and Purchased Power on the Consolidated Statements of Operations.
 
§  
Sempra LNG and Sempra Pipelines & Storage use natural gas derivatives to market energy products and optimize the earnings of our liquefied natural gas business and Sempra Pipelines & Storage’s natural gas storage and transportation assets. Sempra Pipelines & Storage also uses natural gas energy derivatives with the objective of managing price risk and lowering natural gas prices at its Mexican distribution operations. These derivatives, which are recorded as commodity costs that are offset by regulatory account balances and recovered in rates, are recognized in Cost of Natural Gas on the Consolidated Statements of Operations. At Sempra Pipelines & Storage’s non-utility businesses, derivatives are undesignated, and their impact on earnings is recorded in Energy-Related Businesses Revenues or in Cost of Natural Gas, Electric Fuel and Purchased Power on the Consolidated Statements of Operations. Sempra LNG’s derivatives are undesignated, and their impact on earnings is recorded in Energy-Related Businesses Revenues on the Consolidated Statements of Operations.
 
§  
From time to time, our various businesses, including the Sempra Utilities, may use other energy derivatives to hedge exposures such as the price of vehicle fuel.
 
We summarize net energy derivative volumes as of December 31, 2011 and 2010 as follows:
 
 
 
 
December 31,
Business Unit and Commodity
2011 
2010 
Sempra Utilities:
 
 
 
    SDG&E:
 
 
 
 
Natural gas
35 million MMBtu
51 million MMBtu
(1)
 
Congestion revenue rights
19 million MWh
21 million MWh
(2)
 
 
 
 
 
 
Energy-Related Businesses:
 
 
 
    Sempra Generation - electric power
5 million MWh
1 million MWh
 
    Sempra Pipelines & Storage - natural gas
16 million MMBtu
8 million MMBtu
 
    Sempra LNG - natural gas
5 million MMBtu
7 million MMBtu
 
(1)
Million British thermal units
 
(2)
Megawatt hours
 
 
In addition to the amounts noted above, we frequently use commodity derivatives to manage risks associated with the physical locations of our customers, assets and other contractual obligations, such as natural gas purchases and sales.
 
 
INTEREST RATE DERIVATIVES
 
We are exposed to interest rates primarily as a result of our current and expected use of financing. We periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. We utilize interest rate swaps typically designated as fair value hedges, as a means to achieve our targeted level of variable rate debt as a percent of total debt. In addition, we may utilize interest rate swaps, which are typically designated as cash flow hedges, to lock in interest rates on outstanding debt or in anticipation of future financings.
 
Interest rate derivatives are utilized by the Sempra Utilities as well as by other Sempra Energy subsidiaries. Although the Sempra Utilities generally recover borrowing costs in rates over time, the use of interest rate derivatives is subject to certain regulatory constraints, and the impact of interest rate derivatives may not be recovered from customers as timely as described above with regard to natural gas derivatives. Accordingly, interest rate derivatives are generally accounted for as hedges at the Sempra Utilities, as well as at the rest of Sempra Energy’s subsidiaries. Separately, Otay Mesa VIE has entered into interest rate swap agreements to moderate its exposure to interest rate changes. This activity was designated as a cash flow hedge as of April 1, 2011.
 
The net notional amounts of our interest rate derivatives as of December 31, 2011 and 2010 were:
 
 
 
December 31, 2011
December 31, 2010
(Dollars in millions)
Notional Debt
Maturities
Notional Debt
Maturities
Sempra Energy Consolidated(1)
$
15-305
2013-2019
$
215-355
2011-2019
SDG&E(1)
 
285-355
2019
 
285-365
2019
SoCalGas
 
 - 
 - 
 
150
2011
(1)
Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE.
 
FOREIGN CURRENCY DERIVATIVES
 
We are exposed to exchange rate movements primarily as a result of our Mexican subsidiaries, which have U.S. dollar denominated receivables and payables (monetary assets and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. These subsidiaries also have deferred income tax assets and liabilities that are denominated in the Mexican peso, which must be translated into U.S. dollars for financial reporting purposes. From time to time, we may utilize short-term foreign currency derivatives at our subsidiaries and at the consolidated level as a means to manage the risk of exposure to significant fluctuations in our income tax expense from these impacts.
 
 
FINANCIAL STATEMENT PRESENTATION
 
The following tables provide the fair values of derivative instruments, without consideration of margin deposits held or posted, on the Consolidated Balance Sheets as of December 31, 2011 and 2010:
 

DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
 
 
December 31, 2011
 
 
 
 
 
 
 
 
 
Deferred
 
 
 
 
 
 
 
 
 
credits
 
 
 
Current
 
 
 
Current
 
and other
 
 
 
assets:
 
 
 
liabilities:
 
liabilities:
 
 
 
Fixed-price
 
Investments
 
Fixed-price
 
Fixed-price
 
 
 
contracts
 
and other
 
contracts
 
contracts
 
 
 
and other
 
assets:
 
and other
 
and other
Derivatives designated as hedging instruments
 
derivatives(1)
 
Sundry
 
derivatives(2)
 
derivatives
Sempra Energy Consolidated:
 
 
 
 
 
 
 
 
 
Interest rate instruments(3)
$
 5 
$
 11 
$
 (17)
$
 (65)
SDG&E:
 
 
 
 
 
 
 
 
 
Interest rate instruments(3)
$
 ― 
$
 ― 
$
 (16)
$
 (65)
 
 
 
 
 
 
 
 
 
 
Derivatives not designated as hedging instruments
 
 
 
 
 
 
 
 
Sempra Energy Consolidated:
 
 
 
 
 
 
 
 
 
Interest rate instruments
$
 8 
$
 41 
$
 (7)
$
 (36)
 
Commodity contracts not subject to rate recovery
 
 156 
 
 72 
 
 (148)
 
 (94)
 
    Associated offsetting commodity contracts
 
 (120)
 
 (68)
 
 120 
 
 68 
 
Commodity contracts subject to rate recovery
 
 28 
 
 8 
 
 (62)
 
 (24)
 
    Associated offsetting commodity contracts
 
 (10)
 
 (2)
 
 10 
 
 2 
 
Total
$
 62 
$
 51 
$
 (87)
$
 (84)
SDG&E:
 
 
 
 
 
 
 
 
 
Commodity contracts subject to rate recovery
$
 22 
$
 8 
$
 (55)
$
 (24)
 
    Associated offsetting commodity contracts
 
 (5)
 
 (2)
 
 5 
 
 2 
 
Total
$
 17 
$
 6 
$
 (50)
$
 (22)
SoCalGas:
 
 
 
 
 
 
 
 
 
Commodity contracts subject to rate recovery
$
 6 
$
 ― 
$
 (7)
$
 ― 
 
    Associated offsetting commodity contracts
 
 (5)
 
 ― 
 
 5 
 
 ― 
 
Total
$
 1 
$
 ― 
$
 (2)
$
 ― 
(1)
Included in Current Assets: Other for SoCalGas.
(2)
Included in Current Liabilities: Other for SoCalGas.
(3)
Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE.



DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Continued)
(Dollars in millions)
 
 
December 31, 2010
 
 
 
 
 
 
 
 
 
Deferred
 
 
 
 
 
 
 
 
 
credits
 
 
 
Current
 
 
 
Current
 
and other
 
 
 
assets:
 
 
 
liabilities:
 
liabilities:
 
 
 
Fixed-price
 
Investments
 
Fixed-price
 
Fixed-price
 
 
 
contracts
 
and other
 
contracts
 
contracts
 
 
 
and other
 
assets:
 
and other
 
and other
Derivatives designated as hedging instruments
 
derivatives(1)
 
Sundry
 
derivatives(2)
 
derivatives
Sempra Energy Consolidated:
 
 
 
 
 
 
 
 
 
Interest rate instrument
$
 3 
$
 ― 
$
 ― 
$
 ― 
SoCalGas:
 
 
 
 
 
 
 
 
 
Interest rate instrument
$
 3 
$
 ― 
$
 ― 
$
 ― 
 
 
 
 
 
 
 
 
 
 
Derivatives not designated as hedging instruments
 
 
 
 
 
 
 
 
Sempra Energy Consolidated:
 
 
 
 
 
 
 
 
 
Interest rate instruments(3)
$
 9 
$
 22 
$
 (25)
$
 (57)
 
Commodity contracts not subject to rate recovery
 
 59 
 
 20 
 
 (44)
 
 (34)
 
    Associated offsetting commodity contracts
 
 (2)
 
 (8)
 
 2 
 
 8 
 
Commodity contracts subject to rate recovery
 
 5 
 
 ― 
 
 (43)
 
 (27)
 
    Associated offsetting commodity contracts
 
 (37)
 
 (26)
 
 37 
 
 26 
 
Total
$
 34 
$
 8 
$
 (73)
$
 (84)
SDG&E:
 
 
 
 
 
 
 
 
 
Interest rate instruments(3)
$
 ― 
$
 ― 
$
 (17)
$
 (41)
 
Commodity contracts not subject to rate recovery
 
 1 
 
 ― 
 
 ― 
 
 ― 
 
Commodity contracts subject to rate recovery
 
 2 
 
 ― 
 
 (35)
 
 (27)
 
    Associated offsetting commodity contracts
 
 (34)
 
 (26)
 
 34 
 
 26 
 
Total
$
 (31)
$
 (26)
$
 (18)
$
 (42)
SoCalGas:
 
 
 
 
 
 
 
 
 
Commodity contracts not subject to rate recovery
$
 1 
$
 ― 
$
 ― 
$
 ― 
 
Commodity contracts subject to rate recovery
 
 3 
 
 ― 
 
 (3)
 
 ― 
 
    Associated offsetting commodity contracts
 
 (3)
 
 ― 
 
 3 
 
 ― 
 
Total
$
 1 
$
 ― 
$
 ― 
$
 ― 
(1)
Included in Current Assets: Other for SoCalGas.
(2)
Included in Current Liabilities: Other for SoCalGas.
(3)
Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE.


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

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

Sempra Energy expects that losses of $8 million, which are net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next twelve months as the hedged items affect earnings. Actual amounts ultimately reclassified into earnings depend on the interest rates in effect when derivative contracts that are currently outstanding mature.
 
SDG&E and SoCalGas expect that losses of $3 million and $1 million, respectively, which are net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next twelve months as the hedged items affect earnings.
 
For all forecasted transactions, the maximum term over which we are hedging exposure to the variability of cash flows at December 31, 2011 is 88 months for Sempra Energy and SDG&E. The maximum term of exposure related to contracts at Sempra Generation’s equity method investees is 18 years.
 
We recorded negligible hedge ineffectiveness in 2011, 2010 and 2009.
 
The effects of derivative instruments not designated as hedging instruments on the Consolidated Statements of Operations for the years ended December 31 were:
 
UNDESIGNATED DERIVATIVE IMPACT ON THE CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
 
 
 
Gain (loss) on derivatives recognized in earnings
 
 
 
Years ended December 31,
 
 
Location
2011 
2010 
2009 
Sempra Energy Consolidated:
 
 
 
 
 
 
 
 
Interest rate and foreign
 
 
 
 
 
 
 
 
    exchange instruments(1)
Other Income, Net
$
 (14)
$
 (34)
$
 30 
 
Commodity contracts not subject
Revenues: Energy-Related
 
 
 
 
 
 
 
    to rate recovery
    Businesses
 
 30 
 
 47 
 
 47 
 
Commodity contracts not subject
Cost of Natural Gas, Electric
 
 
 
 
 
 
 
    to rate recovery
    Fuel and Purchased Power
 
 1 
 
 (29)
 
 (39)
 
Commodity contracts not subject
 
 
 
 
 
 
 
 
    to rate recovery
Other Operation and Maintenance
 
 1 
 
 2 
 
 ― 
 
Commodity contracts subject
Cost of Electric Fuel
 
 
 
 
 
 
 
    to rate recovery
    and Purchased Power
 
 (14)
 
 (102)
 
 (54)
 
Commodity contracts subject
 
 
 
 
 
 
 
 
    to rate recovery
Cost of Natural Gas
 
 (2)
 
 (9)
 
 (10)
 
Total
 
$
 2 
$
 (125)
$
 (26)
SDG&E:
 
 
 
 
 
 
 
 
Interest rate instruments(1)
Other Income, Net
$
 (1)
$
 (34)
$
 27 
 
Commodity contracts not subject
 
 
 
 
 
 
 
 
    to rate recovery
Operation and Maintenance
 
 ― 
 
 1 
 
 ― 
 
Commodity contracts subject
Cost of Electric Fuel
 
 
 
 
 
 
 
    to rate recovery
    and Purchased Power
 
 (14)
 
 (102)
 
 (54)
 
Total
 
$
 (15)
$
 (135)
$
 (27)
SoCalGas:
 
 
 
 
 
 
 
 
Commodity contracts not subject
 
 
 
 
 
 
 
 
    to rate recovery
Operation and Maintenance
$
 1 
$
 1 
$
 ― 
 
Commodity contracts subject
 
 
 
 
 
 
 
 
    to rate recovery
Cost of Natural Gas
 
 (2)
 
 (5)
 
 (5)
 
Total
 
$
 (1)
$
 (4)
$
 (5)
(1)
Amounts are related to Otay Mesa VIE. Sempra Energy Consolidated also includes additional instruments.
 
 
 

 

CONTINGENT FEATURES
 
For Sempra Energy and SDG&E, certain of our derivative instruments contain credit limits which vary depending upon our credit ratings. Generally, these provisions, if applicable, may reduce our credit limit if a specified credit rating agency reduces our ratings. In certain cases, if our credit ratings were to fall below investment grade, the counterparty to these derivative liability instruments could request immediate payment or demand immediate and ongoing full collateralization. 
 
For Sempra Energy, the total fair value of this group of derivative instruments in a net liability position at December 31, 2011 is $24 million. As of December 31, 2011, if the credit ratings of Sempra Energy were reduced below investment grade, $24 million of additional assets could be required to be posted as collateral for these derivative contracts.
 
For SDG&E, the total fair value of this group of derivative instruments in a net liability position at December 31, 2011 is $11 million. As of December 31, 2011, if the credit ratings of SDG&E were reduced below investment grade, $11 million of additional assets could be required to be posted as collateral for these derivative contracts.
 
For Sempra Energy, SDG&E and SoCalGas, some of our derivative contracts contain a provision that would permit the counterparty, in certain circumstances, to request adequate assurance of our performance under the contracts. Such additional assurance, if needed, is not material and is not included in the amounts above.
 

 

NOTE 11. FAIR VALUE MEASUREMENTS
 

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


Sempra Energy based the fair values of investments in affordable housing partnerships on the present value of estimated future cash flows, discounted at rates available for similar investments. All entities based the fair values of long-term debt and preferred stock on their quoted market prices or quoted market prices for similar securities.
 
 
Derivative Positions Net of Cash Collateral
 
Each Consolidated Balance Sheet reflects the offsetting of net derivative positions with fair value amounts for cash collateral with the same counterparty when management believes a legal right of offset exists.
 
The following table provides the amount of fair value of cash collateral receivables that were not offset in the Consolidated Balance Sheets as of December 31, 2011 and 2010:
 
 
December 31,
(Dollars in millions)
2011 
2010 
Sempra Energy Consolidated
$
 20 
$
 32 
SDG&E
 
 10 
 
 25 
SoCalGas
 
 2 
 
 3 
 
Fair Value Hierarchy
 
We discuss the valuation techniques and inputs we use to measure fair value and the definition of the three levels of the fair value hierarchy in Note 1 under “Fair Value Measurements.”
 
The three tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis as of December 31, 2011 and 2010. We also discuss our financial assets and liabilities recorded at fair value on a non-recurring basis. We classify financial assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities, and their placement within the fair value hierarchy levels.
 
The fair value of commodity derivative assets and liabilities is determined in accordance with our netting policy, as discussed above under “Derivative Positions Net of Cash Collateral.”
 
The determination of fair values, shown in the tables below, incorporates various factors, including but not limited to, the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits, letters of credit and priority interests).
 
Our financial assets and liabilities that were accounted for at fair value on a recurring basis as of December 31, 2011 and 2010 in the tables below include the following:
 
§  
Nuclear decommissioning trusts reflect the assets of SDG&E’s nuclear decommissioning trusts, excluding cash balances, as we discuss in Note 6. The trust assets are valued by a third party trustee. The trustee obtains prices from pricing services that are derived from observable data. We monitor the prices supplied by pricing services by validating pricing with other sources of data.
§  
Investments include marketable securities and are primarily priced based on observable interest rates for similar instruments actively trading in the marketplace.
§  
Commodity and other derivative positions, which include other interest rate management instruments, are entered into primarily as a means to manage price exposures. We use market participant assumptions to price these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable.
 


RECURRING FAIR VALUE MEASURES ― SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
 
 
At fair value as of December 31, 2011
 
 
 
 
 
 
 
 
 
Collateral
 
 
 
 
 
Level 1
 
Level 2
 
Level 3
 
Netted
 
Total
Assets:
 
 
 
 
 
 
 
 
 
 
    Nuclear decommissioning trusts
 
 
 
 
 
 
 
 
 
 
          Equity securities
$
 468 
$
 ― 
$
 ― 
$
 ― 
$
 468 
          Debt securities:
 
 
 
 
 
 
 
 
 
 
              Debt securities issued by the U.S. Treasury and other
 
 
 
 
 
 
 
 
 
 
                   U.S. government corporations and agencies
 
 92 
 
 78 
 
 ― 
 
 ― 
 
 170 
              Municipal bonds
 
 ― 
 
 77 
 
 ― 
 
 ― 
 
 77 
              Other securities
 
 ― 
 
 78 
 
 ― 
 
 ― 
 
 78 
          Total debt securities
 
 92 
 
 233 
 
 ― 
 
 ― 
 
 325 
    Total nuclear decommissioning trusts(1)
 
 560 
 
 233 
 
 ― 
 
 ― 
 
 793 
    Interest rate instruments
 
 ― 
 
 66 
 
 ― 
 
 ― 
 
 66 
    Commodity contracts subject to rate recovery
 
 10 
 
 1 
 
 23 
 
 ― 
 
 34 
    Commodity contracts not subject to rate recovery
 
 15 
 
 35 
 
 ― 
 
 (2)
 
 48 
    Investments
 
 5 
 
 ― 
 
 ― 
 
 ― 
 
 5 
Total
$
 590 
$
 335 
$
 23 
$
 (2)
$
 946 
Liabilities:
 
 
 
 
 
 
 
 
 
 
    Interest rate instruments
$
 1 
$
 124 
$
 ― 
$
 ― 
$
 125 
    Commodity contracts subject to rate recovery
 
 61 
 
 13 
 
 ― 
 
 (61)
 
 13 
    Commodity contracts not subject to rate recovery
 
 1 
 
 52 
 
 ― 
 
 (4)
 
 49 
Total
$
 63 
$
 189 
$
 ― 
$
 (65)
$
 187 
 
 
 
 
 
 
 
 
 
 
 
 
 
At fair value as of December 31, 2010
 
 
 
 
 
 
 
 
Collateral
 
 
 
 
Level 1
 
Level 2
 
Level 3
 
netted
 
Total
Assets:
 
 
 
 
 
 
 
 
 
 
    Nuclear decommissioning trusts
 
 
 
 
 
 
 
 
 
 
          Equity securities
$
 460 
$
 ― 
$
 ― 
$
 ― 
$
 460 
          Debt securities:
 
 
 
 
 
 
 
 
 
 
              Debt securities issued by the U.S. Treasury and other
 
 
 
 
 
 
 
 
 
 
                   U.S. government corporations and agencies
 
 144 
 
 30 
 
 ― 
 
 ― 
 
 174 
              Municipal bonds
 
 ― 
 
 100 
 
 ― 
 
 ― 
 
 100 
              Other securities
 
 ― 
 
 25 
 
 ― 
 
 ― 
 
 25 
          Total debt securities
 
 144 
 
 155 
 
 ― 
 
 ― 
 
 299 
    Total nuclear decommissioning trusts(1)
 
 604 
 
 155 
 
 ― 
 
 ― 
 
 759 
    Interest rate instruments
 
 ― 
 
 34 
 
 ― 
 
 ― 
 
 34 
    Commodity contracts subject to rate recovery
 
 25 
 
 1 
 
 2 
 
 ― 
 
 28 
    Commodity contracts not subject to rate recovery
 
 9 
 
 66 
 
 ― 
 
 (22)
 
 53 
    Investments
 
 1 
 
 ― 
 
 ― 
 
 ― 
 
 1 
Total
$
 639 
$
 256 
$
 2 
$
 (22)
$
 875 
Liabilities:
 
 
 
 
 
 
 
 
 
 
    Interest rate instruments
$
 ― 
$
 82 
$
 ― 
$
 ― 
$
 82 
    Commodity contracts subject to rate recovery
 
 60 
 
 8 
 
 ― 
 
 (60)
 
 8 
    Commodity contracts not subject to rate recovery
 
 ― 
 
 67 
 
 ― 
 
 ― 
 
 67 
Total
$
 60 
$
 157 
$
 ― 
$
 (60)
$
 157 
(1)
Excludes cash balances and cash equivalents.
 
 
 
 
 
 
 
 
 
 

 
RECURRING FAIR VALUE MEASURES ― SDG&E
(Dollars in millions)
 
At fair value as of December 31, 2011
 
 
 
 
 
 
 
 
Collateral
 
 
 
 
Level 1
 
Level 2
 
Level 3
 
netted
 
Total
Assets:
 
 
 
 
 
 
 
 
 
 
    Nuclear decommissioning trusts
 
 
 
 
 
 
 
 
 
 
          Equity securities
$
 468 
$
 ― 
$
 ― 
$
 ― 
$
 468 
          Debt securities:
 
 
 
 
 
 
 
 
 
 
              Debt securities issued by the U.S. Treasury and other
 
 
 
 
 
 
 
 
 
 
                   U.S. government corporations and agencies
 
 92 
 
 78 
 
 ― 
 
 ― 
 
 170 
              Municipal bonds
 
 ― 
 
 77 
 
 ― 
 
 ― 
 
 77 
              Other securities
 
 ― 
 
 78 
 
 ― 
 
 ― 
 
 78 
          Total debt securities
 
 92 
 
 233 
 
 ― 
 
 ― 
 
 325 
    Total nuclear decommissioning trusts(1)
 
 560 
 
 233 
 
 ― 
 
 ― 
 
 793 
    Commodity contracts subject to rate recovery
 
 9 
 
 ― 
 
 23 
 
 ― 
 
 32 
    Commodity contracts not subject to rate recovery
 
 1 
 
 ― 
 
 ― 
 
 ― 
 
 1 
Total
$
 570 
$
 233 
$
 23 
$
 ― 
$
 826 
 
 
 
 
 
 
 
 
 
 
 
Liabilities:
 
 
 
 
 
 
 
 
 
 
    Interest rate instruments
$
 ― 
$
 81 
$
 ― 
$
 ― 
$
 81 
    Commodity contracts subject to rate recovery
 
 61 
 
 12 
 
 ― 
 
 (61)
 
 12 
Total
$
 61 
$
 93 
$
 ― 
$
 (61)
$
 93 
 
 
 
 
 
 
 
 
 
 
 
 
At fair value as of December 31, 2010
 
 
 
 
 
 
 
 
Collateral
 
 
 
 
Level 1
 
Level 2
 
Level 3
 
netted
 
Total
Assets:
 
 
 
 
 
 
 
 
 
 
    Nuclear decommissioning trusts
 
 
 
 
 
 
 
 
 
 
          Equity securities
$
 460 
$
 ― 
$
 ― 
$
 ― 
$
 460 
          Debt securities:
 
 
 
 
 
 
 
 
 
 
              Debt securities issued by the U.S. Treasury and other
 
 
 
 
 
 
 
 
 
 
                   U.S. government corporations and agencies
 
 144 
 
 30 
 
 ― 
 
 ― 
 
 174 
              Municipal bonds
 
 ― 
 
 100 
 
 ― 
 
 ― 
 
 100 
              Other securities
 
 ― 
 
 25 
 
 ― 
 
 ― 
 
 25 
          Total debt securities
 
 144 
 
 155 
 
 ― 
 
 ― 
 
 299 
    Total nuclear decommissioning trusts(1)
 
 604 
 
 155 
 
 ― 
 
 ― 
 
 759 
    Commodity contracts subject to rate recovery
 
 24 
 
 ― 
 
 2 
 
 ― 
 
 26 
    Commodity contracts not subject to rate recovery
 
 2 
 
 ― 
 
 ― 
 
 ― 
 
 2 
Total
$
 630 
$
 155 
$
 2 
$
 ― 
$
 787 
 
 
 
 
 
 
 
 
 
 
 
Liabilities:
 
 
 
 
 
 
 
 
 
 
    Interest rate instruments
$
 ― 
$
 58 
$
 ― 
$
 ― 
$
 58 
    Commodity contracts subject to rate recovery
 
 60 
 
 2 
 
 ― 
 
 (60)
 
 2 
Total
$
 60 
$
 60 
$
 ― 
$
 (60)
$
 60 
(1)
Excludes cash balances and cash equivalents.
 
 
 
 
 
 
 
 
 
 
 

RECURRING FAIR VALUE MEASURES ― SOCALGAS
(Dollars in millions)
 
At fair value as of December 31, 2011
 
 
 
 
 
 
 
 
Collateral
 
 
 
 
Level 1
 
Level 2
 
Level 3
 
netted
 
Total
Assets:
 
 
 
 
 
 
 
 
 
 
    Commodity contracts subject to rate recovery
$
 1 
$
 1 
$
 ― 
$
 ― 
$
 2 
    Commodity contracts not subject to rate recovery
 
 2 
 
 ― 
 
 ― 
 
 ― 
 
 2 
Total
$
 3 
$
 1 
$
 ― 
$
 ― 
$
 4 
 
 
 
 
 
 
 
 
 
 
 
Liabilities:
 
 
 
 
 
 
 
 
 
 
    Commodity contracts subject to rate recovery
$
 ― 
$
 1 
$
 ― 
$
 ― 
$
 1 
Total
$
 ― 
$
 1 
$
 ― 
$
 ― 
$
 1 
 
 
 
 
 
 
 
 
 
 
 
 
At fair value as of December 31, 2010
 
 
 
 
 
 
 
 
Collateral
 
 
 
 
Level 1
 
Level 2
 
Level 3
 
netted
 
Total
Assets:
 
 
 
 
 
 
 
 
 
 
    Interest rate instruments
$
 ― 
$
 3 
$
 ― 
$
 ― 
$
 3 
    Commodity contracts subject to rate recovery
 
 1 
 
 1 
 
 ― 
 
 ― 
 
 2 
    Commodity contracts not subject to rate recovery
 
 3 
 
 ― 
 
 ― 
 
 ― 
 
 3 
Total
$
 4 
$
 4 
$
 ― 
$
 ― 
$
 8 

There were no transfers into or out of Level 1 or Level 2 for Sempra Energy Consolidated, SDG&E or SoCalGas during the periods presented.
 
 
Level 3 Information
 
The following table sets forth reconciliations of changes in the fair value of net trading and other derivatives classified as Level 3 in the fair value hierarchy for Sempra Energy Consolidated and SDG&E:
 

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

There were no transfers into or out of Level 3 during the periods presented.
 
Level 3 recurring items are related to CRRs at SDG&E. These instruments are recorded at fair value based on the most current auction prices published by the California Independent System Operator (ISO). The earnings impacts of CRRs are deferred and recorded in regulatory accounts to the extent they are recoverable or refundable through rates. Upon settlement, CRRs are included in Cost of Electric Fuel and Purchased Power on the Consolidated Statements of Operations for each of the three years in the period ended December 31, 2011.
 
 
Non-Recurring Fair Value Measures – Sempra Energy Consolidated
 
We discuss non-recurring fair value measures and the associated accounting impact on our investments in RBS Sempra Commodities and Argentina in Note 4.
 


 

NOTE 12. PREFERRED STOCK
 

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

PREFERRED STOCK
 
 
 
 
 
 
 
 
 
 
 
Call/
 
 
 
 
 
 
 
Redemption
December 31,
 
 
 
Price
2011 
2010 
 
 
 
 
(in millions)
Contingently redeemable:
 
 
 
 
 
 
 
SDG&E:
 
 
 
 
 
 
 
    $20 par value, authorized 1,375,000 shares:
 
 
 
 
 
 
 
        5% Series, 375,000 shares outstanding
$
 24.00 
$
 8 
$
 8 
 
        4.5% Series, 300,000 shares outstanding
$
 21.20 
 
 6 
 
 6 
 
        4.4% Series, 325,000 shares outstanding
$
 21.00 
 
 7 
 
 7 
 
        4.6% Series, 373,770 shares outstanding
$
 20.25 
 
 7 
 
 7 
 
    Without par value:
 
 
 
 
 
 
 
        $1.70 Series, 1,400,000 shares outstanding
$
 25.17 
 
 35 
 
 35 
 
        $1.82 Series, 640,000 shares outstanding
$
 26.00 
 
 16 
 
 16 
 
    SDG&E - Total contingently redeemable preferred stock
 
 
 
 79 
 
 79 
 
    Sempra Energy - Total preferred stock of subsidiary,
 
 
 
 
 
 
 
        contingently redeemable
 
 
$
 79 
$
 79 
 
 
 
 
 
 
 
SoCalGas:
 
 
 
 
 
 
    $25 par value, authorized 1,000,000 shares:
 
 
 
 
 
 
        6% Series, 79,011 shares outstanding
 
 
$
 3 
$
 3 
        6% Series A, 783,032 shares outstanding
 
 
 
 19 
 
 19 
    Total preferred stock of SoCalGas
 
 
 
 22 
 
 22 
    Less: 50,970 shares of the 6% Series outstanding owned by PE
 
 
 
 (2)
 
 (2)
 
 
 
 
 20 
 
 20 
Pacific Enterprises:
 
 
 
 
 
 
    Without par value, authorized 15,000,000 shares; outstanding
 
   as of December 31, 2010:
 
 
 
 
 
 
              $4.75 Dividend, 200,000 shares
$
 100.00 
 
 ― 
 
 20 
              $4.50 Dividend, 300,000 shares
$
 100.00 
 
 ― 
 
 30 
              $4.40 Dividend, 100,000 shares
$
 101.50 
 
 ― 
 
 10 
              $4.36 Dividend, 200,000 shares
$
 101.00 
 
 ― 
 
 20 
              $4.75 Dividend, 253 shares
$
 101.00 
 
 ― 
 
 ― 
    Total preferred stock of Pacific Enterprises
 
 
 
 ― 
 
 80 
 
 
 
 
 
 
 
 
 
    Sempra Energy - Total preferred stock of subsidiaries
 
 
$
 20 
$
 100 

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

SDG&E
 
§  
All outstanding series are callable.
 
§  
The $20 par value preferred stock has two votes per share on matters being voted upon by shareholders of SDG&E and a liquidation preference at par plus any unpaid dividends.
 
§  
All outstanding series of SDG&E’s preferred stock have cumulative preferences as to dividends.
 
§  
The no-par-value preferred stock is nonvoting and has a liquidation preference of $25 per share plus any unpaid dividends.
 
§  
SDG&E is authorized to issue 10 million shares of no-par-value preferred stock (both subject to and not subject to mandatory redemption).
 
SDG&E is currently authorized to issue up to 25 million shares of an additional class of preference shares designated as “Series Preference Stock.” The Series Preference Stock is in addition to the Cumulative Preferred Stock, Preference Stock (Cumulative) and Common Stock that SDG&E was otherwise authorized to issue, and when issued would rank junior to the Cumulative Preferred Stock and Preference Stock (Cumulative). The stock’s rights, preferences and privileges would be established by the board of directors at the time of issuance.
 
SDG&E’s outstanding preferred securities are classified as contingently redeemable because they contain a contingent redemption feature that allows the holder to elect a majority of SDG&E’s board of directors if dividends are not paid for eight consecutive quarters, and such a redemption triggering event is not solely within the control of SDG&E. They are therefore presented separate from and outside of equity in a manner consistent with temporary equity.
 
 
SOCALGAS
 
§  
None of SoCalGas’ outstanding preferred stock is callable.
 
§  
All outstanding series have one vote per share, cumulative preferences as to dividends and liquidation preferences of $25 per share plus any unpaid dividends.
 
SoCalGas currently is authorized to issue 5 million shares of series preferred stock and 5 million shares of preference stock, both without par value and with cumulative preferences as to dividends and liquidation value. The preference stock would rank junior to all series of preferred stock. Other rights and privileges of the stock would be established by the board of directors at the time of issuance.
 
 
PACIFIC ENTERPRISES
 
On June 30, 2011, PE redeemed all five series of its outstanding preferred stock for $81 million. Each series was redeemed for cash at redemption prices ranging from $100 to $101.50 per share, plus accrued dividends up to the redemption date of an aggregate of $1 million. The redeemed shares are no longer outstanding and represent only the right to receive the applicable redemption price, to the extent that shares have not yet been presented for payment.
 
PE currently is authorized to issue 10 million shares of series preferred stock and 5 million shares of Class A series preferred stock, both without par value and with cumulative preferences as to dividends and liquidation value.  No shares of preferred stock or Class A series preferred stock are outstanding. Class A series preferred stock, when issued, would rank junior to all other series of preferred stock with respect to dividends and liquidation value. Other rights and privileges of each series of the preferred stock and Class A series preferred stock would be established by the board of directors at the time of issuance.
 

 

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

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

EARNINGS PER SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
 
Years ended December 31,
 
2011 
2010 
2009 
Numerator:
 
 
 
 
 
 
    Earnings/Income attributable to common shareholders
$
 1,357 
$
 739 
$
 1,119 
 
 
 
 
 
 
 
Denominator:
 
 
 
 
 
 
    Weighted-average common shares outstanding for basic EPS
 
 239,720 
 
 244,736 
 
 243,339 
    Dilutive effect of stock options, restricted stock awards and
 
 
 
 
 
 
        restricted stock units
 
 1,803 
 
 3,206 
 
 4,045 
    Weighted-average common shares outstanding for diluted EPS
 
 241,523 
 
 247,942 
 
 247,384 
 
 
 
 
 
 
 
Earnings per share:
 
 
 
 
 
 
    Basic
$
 5.66 
$
 3.02 
$
 4.60 
    Diluted
$
 5.62 
$
 2.98 
$
 4.52 

The dilution from common stock options is based on the treasury stock method. Under this method, proceeds based on the exercise price plus unearned compensation and windfall tax benefits and minus tax shortfalls are assumed to be used to repurchase shares on the open market at the average market price for the period. The windfall tax benefits are tax deductions we would receive upon the assumed exercise of stock options in excess of the deferred income taxes we recorded related to the compensation expense on the stock options. Tax shortfalls occur when the assumed tax deductions are less than recorded deferred income taxes. The calculation excludes options for which the exercise price on common stock was greater than the average market price during the period (out-of-the-money options).  We had 2,083,275; 2,138,800 and 1,504,250 of such antidilutive stock options outstanding during 2011, 2010 and 2009, respectively.
 
During 2011 and 2010, respectively, we had 900 and 9,900 stock options outstanding that were antidilutive because of the unearned compensation and windfall tax benefits included in the assumed proceeds under the treasury stock method. There were no such antidilutive stock options outstanding during 2009.
 
The dilution from unvested restricted stock awards (RSAs) and restricted stock units (RSUs) is also based on the treasury stock method. Assumed proceeds equal to the unearned compensation and windfall tax benefits and minus tax shortfalls related to the awards and units are assumed to be used to repurchase shares on the open market at the average market price for the period. The windfall tax benefits or tax shortfalls are the difference between tax deductions we would receive upon the assumed vesting of RSAs or RSUs and the deferred income taxes we recorded related to the compensation expense on such awards and units. There were no antidilutive restricted stock awards or units from the application of unearned compensation in the treasury stock method in 2011, 2010 or 2009.
 
Each performance based RSU represents the right to receive between zero and 1.5 shares of Sempra Energy common stock based on Sempra Energy’s four-year cumulative total shareholder return compared to the S&P 500 Utilities Index, as follows:
 
Four-Year Cumulative Total Shareholder Return Ranking versus S&P 500 Utilities Index(1)
Number of Sempra Energy Common Shares Received for Each Restricted Stock Unit(2)
75th Percentile or Above
1.5 
50th Percentile
35th Percentile or Below
 (1)
If Sempra Energy ranks at or above the 50th percentile compared to the S&P 500 Index, participants will receive a minimum of 1.0 share for each restricted stock unit.
 (2)
Participants may also receive additional shares for dividend equivalents on shares subject to restricted stock units, which are reinvested to purchase additional shares that become subject to the same vesting conditions as the restricted stock units to which the dividends relate.


 
RSAs have a maximum potential of 100 percent vesting. We include our performance based RSAs and RSUs in potential dilutive shares at zero to 100 percent and zero to 150 percent, respectively, to the extent that they currently meet the performance requirements for vesting, subject to the application of the treasury stock method. Due to market fluctuations of both Sempra Energy stock and the comparative index, dilutive RSA and RSU shares may vary widely from period-to-period. We include our service-based RSAs in potential dilutive shares at 100 percent.
 
RSUs and RSAs may be excluded from potential dilutive shares by the application of unearned compensation in the treasury stock method or because performance goals are currently not met.  The maximum excluded RSUs and RSAs, assuming performance goals were met at maximum levels, were 4,109,717; 2,008,413, and 1,058,521 for the years ended December 31 2011, 2010 and 2009, respectively.
 
We are authorized to issue 750,000,000 shares of no-par-value common stock. In addition, we are authorized to issue 50,000,000 shares of preferred stock having rights, preferences and privileges that would be established by the Sempra Energy board of directors at the time of issuance.
 
Shares of common stock held by the ESOP were 153,625; 504,440 and 868,173 at December 31, 2011, 2010 and 2009, respectively. These shares are unallocated and therefore excluded from the computation of EPS.
 
Excluding shares held by the ESOP, common stock activity consisted of the following:
 

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

Our board of directors has the discretion to determine the payment and amount of future dividends.
 
 
COMMON STOCK REPURCHASE PROGRAMS
 
On September 11, 2007, our board of directors authorized the repurchase of additional shares of our common stock provided that the amounts expended for such purposes did not exceed the greater of $2 billion or amounts expended to purchase no more than 40 million shares. Purchases may include open-market and negotiated transactions, structured purchase arrangements, and tender offers.
 
In April 2008, we entered into a share repurchase program under which we prepaid $1 billion to repurchase shares of our common stock to be delivered later in 2008 in a share forward transaction. The $1 billion purchase price was recorded as a reduction in shareholders’ equity, and we received 18,416,241 shares under the program during 2008 based on a final weighted average price of $54.30 per share.
 
In September 2010, we entered into a share repurchase program under which we prepaid $500 million to repurchase shares of our common stock in a share forward transaction. The program was completed in March 2011 with a total of 9,574,435 shares repurchased at an average price of $52.22 per share. Our outstanding shares used to calculate earnings per share were reduced by the number of shares repurchased when they were delivered to us, and the $500 million purchase price was recorded as a reduction in shareholdersequity upon its prepayment. We received 5,670,006 shares during the quarter ended September 30, 2010; 2,407,994 shares on October 4, 2010 and 1,496,435 shares on March 22, 2011.
 
These share repurchase programs are unrelated to share based compensation as described in Note 9.
 

 

NOTE 14. SEMPRA UTILITIES’ REGULATORY MATTERS
 

 
SDG&E POWER PROCUREMENT AND RESOURCE PLANNING
 
 
Background—Electric Industry Regulation
 
California’s legislative response to the 2000 – 2001 energy crisis resulted in the DWR purchasing a substantial portion of power for California’s electricity users. In 2001, the DWR entered into long-term contracts with suppliers, including Sempra Generation, to provide power for the utility procurement customers of each of the California investor-owned utilities (IOUs), including SDG&E. The CPUC allocates the power and its administrative responsibility, including collection of power contract costs from utility customers, among the IOUs.
 
Effective in 2003, the IOUs resumed responsibility for electric commodity procurement above their allocated share of the DWR’s long-term contracts, and the CPUC:
 
§  
directed the IOUs, including SDG&E, to resume electric commodity procurement to cover their net short energy requirements, which are the total customer energy requirements minus supply from resources owned, operated or contracted;
 
§  
implemented legislation regarding procurement and renewable energy portfolio standards; and
 
§  
established a process for review and approval of the utilities’ long-term resource and procurement plans.
 
This process is intended to identify anticipated needs for generation and transmission resources in order to support transmission grid reliability and to better serve customers.
 
 
Renewable Energy
 
In 2010, the State of California required certain California electric retail sellers, including SDG&E, to deliver 20 percent of their retail energy sales from renewable energy sources. The rules governing this requirement, administered by both the CPUC and the California Energy Commission (CEC), are known as the Renewables Portfolio Standard (RPS) Program. In December 2011, California Senate Bill 2(1X) (33% RPS Program) went into effect, superseding the previous RPS Program. It requires each California utility to procure 33 percent of its annual electric energy requirements from renewable energy sources by 2020, with an average of 20 percent required from January 1, 2011 to December 31, 2013; 25 percent by December 31, 2016; and 33 percent by December 31, 2020. The CPUC began a rulemaking in May 2011 to address the implementation of the 33% RPS Program.
 
The 33% RPS Program contains new flexible compliance mechanisms, more restrictive than the prior mechanisms, that can be used to comply with or meet the 33% RPS Program mandates in 2011 and beyond. The new mechanisms provide for a CPUC waiver under certain conditions, including: 1) a finding of inadequate transmission, 2) delays in the start-up of commercial operations of renewable energy projects due to permitting or interconnection or 3) unexpected curtailment by an electric system balancing authority, such as the California Independent System Operator (ISO).
 
SDG&E continues to procure renewable energy supplies to achieve the 33% RPS Program requirements. A substantial number of these supply contracts, however, are contingent upon many factors, including:
 
§  
access to electric transmission infrastructure;
 
§  
timely regulatory approval of contracted renewable energy projects;
 
§  
the renewable energy project developers’ ability to obtain project financing and permitting; and
 
§  
successful development and implementation of the renewable energy technologies.
 
For 2010, SDG&E satisfied its RPS procurement requirements through a combination of contracted deliveries and application of the flexible compliance mechanism, including the application of certain mechanisms that are no longer available under the 33% RPS Program. For 2011 and beyond, SDG&E believes it will be able to comply with the 33% RPS Program requirements based on its contracting activity and, if necessary, application of the new flexible compliance mechanisms. SDG&E’s failure to comply with the RPS Program requirements could subject it to a CPUC-imposed penalty of 5 cents per kilowatt hour of renewable energy under-delivery.
 

SDG&E Purchase of El Dorado
 
SDG&E purchased Sempra Generation’s El Dorado natural gas generation plant on October 1, 2011, pursuant to an option to acquire the plant that was exercised in 2007. In accordance with the CPUC’s approval, SDG&E acquired El Dorado (now named Desert Star Energy Center) at a price equal to the closing book value of the plant upon transfer. SDG&E made a compliance filing with the CPUC in September 2011 stating the book value purchase price as $215 million. The final purchase price was $214 million based on the completion of an independent audit of Sempra Generation’s net book value of the plant as of the close of business on September 30, 2011.
 
 
East County Substation
 
In response to a CPUC application filed by SDG&E for authorization to proceed with the East County Substation project, the CPUC and Bureau of Land Management jointly issued a favorable final environmental impact report and environmental impact statement in October 2011. The project, which will include construction of a new 500/230/138- kilovolt (kV) substation, rebuilding of the existing Boulevard Substation and construction of a new 138-kV transmission line connecting the two substations, is estimated to cost approximately $435 million. It would allow interconnections from new renewable-generation sources and enhance the reliability of electric service to a number of communities. We expect a CPUC decision on this project in the first half of 2012.
 
 
San Onofre Nuclear Generating Station (SONGS)
 
Edison (78.21%), SDG&E (20%) and the city of Riverside (1.79%) jointly own SONGS. Edison completed the replacement of the steam generators at San Onofre Units 2 and 3 in April 2010 and February 2011, respectively. The final phase of the project, disposal of the old steam generators, is planned to be completed in 2012. SDG&E’s share of the capital investment in this project is $180 million, including $160 million incurred through December 31, 2011. The CPUC approved SDG&E’s participation in the replacement project. SDG&E has requested continuation of full recovery of current operating and maintenance costs via balancing account treatment in its 2012 General Rate Case application, discussed below.
 
 
GENERAL RATE CASE (GRC)
 
The CPUC uses a general rate case proceeding to prospectively set rates sufficient to allow the Sempra Utilities to recover their reasonable cost of operations and maintenance and to provide the opportunity to realize their authorized rates of return on their investment. In December 2010, the Sempra Utilities filed their 2012 General Rate Case (GRC) applications to establish their authorized 2012 revenue requirements and the ratemaking mechanisms by which those requirements will change on an annual basis over the subsequent three-year (2013-2015) period. Both SDG&E and SoCalGas filed revised applications with the CPUC in July 2011. Evidentiary hearings were completed in January 2012 and final briefs reflecting the results from these hearings are scheduled to be filed with the CPUC by May 1, 2012. The final decision for the 2012 GRC will be made effective retroactive to January 1, 2012.
 
In February 2012, the Sempra Utilities filed amendments to update their July 2011 revised applications. With these amendments, SDG&E is requesting a revenue requirement in 2012 of $1.849 billion, an increase of $235 million (or 14.6%) over 2011. SoCalGas is requesting a revenue requirement in 2012 of $2.112 billion, an increase of $268 million (14.5%) over 2011. The Division of Ratepayer Advocates and other intervening parties are recommending that the CPUC reduce the utilities’ revenue requirements in 2012 by approximately 5 percent compared to 2011.
 
 
UTILITY INCENTIVE MECHANISMS
 
The CPUC applies performance-based measures and incentive mechanisms to all California IOUs. Under these, the Sempra Utilities have earnings potential above authorized base margins if they achieve or exceed specific performance and operating goals. Generally, for performance-based awards, if performance is above or below specific benchmarks, the utility is eligible for financial awards or subject to financial penalties. Both SDG&E and SoCalGas have incentive mechanisms associated with:
 
§  
operational incentives
 
§  
energy efficiency/demand side management
 
SoCalGas has additional incentive mechanisms associated with:
 
§  
natural gas procurement
 
§  
unbundled natural gas storage and system operator hub services
 
Incentive awards are included in our earnings when we receive any required CPUC approval of the award. We would record penalties for results below the specified benchmarks in earnings when we believe it is more likely than not that the CPUC would assess a penalty.
 
We provide a summary of the incentive awards recognized below.
 
UTILITY INCENTIVE AWARDS 2009-2011
 
 
 
 
 
 
 
 
 
(Dollars in millions)
 
 
 
 
 
 
 
 
 
 
Years ended December 31,
 
2011 
2010 
2009 
Sempra Energy Consolidated
 
 
 
 
 
 
 
 
 
Energy efficiency and demand side management
$
 16 
 
$
 15 
 
$
 2 
 
Unbundled natural gas storage and hub services
 
 4 
 
 
 15 
 
 
 19 
 
Natural gas procurement
 
 6 
 
 
 12 
 
 
 7 
 
Operational incentives
 
 3 
 
 
 1 
 
 
 1 
 
Total awards
$
 29 
 
$
 43 
 
$
 29 
 
SDG&E
 
 
 
 
 
 
 
 
 
Energy efficiency and demand side management
$
 14 
 
$
 5 
 
$
 ― 
 
Operational incentives
 
 1 
 
 
 1 
 
 
 1 
 
Total awards
$
 15 
 
$
 6 
 
$
 1 
 
SoCalGas
 
 
 
 
 
 
 
 
 
Energy efficiency and demand side management
$
 2 
 
$
 10 
 
$
 2 
 
Unbundled natural gas storage and hub services
 
 4 
 
 
 15 
 
 
 19 
 
Natural gas procurement
 
 6 
 
 
 12 
 
 
 7 
 
Operational incentives
 
 2 
 
 
 ― 
 
 
 ― 
 
Total awards
$
 14 
 
$
 37 
 
$
 28 
 
 
Energy Efficiency and Demand Side Management
 
The CPUC established incentive mechanisms that are based on the effectiveness of energy efficiency and demand side management programs. In December 2009, the CPUC awarded $0.3 million and $2.1 million to SDG&E and SoCalGas, respectively, for their performance during the 2006 – 2008 program period. In February 2010, the Sempra Utilities filed a petition with the CPUC to correct errors in the computation of these awards. In December 2010, the CPUC additionally awarded $5.1 million and $9.9 million to SDG&E and SoCalGas, respectively, as the final true-up incentive awards for the 2006 – 2008 program period, which amounts incorporate the Sempra Utilities’ petition to correct computational errors.
 
In December 2011, the CPUC awarded $13.7 million to SDG&E and $2.0 million to SoCalGas for their 2009 program year results.
 
The CPUC has not yet established a schedule for reviewing and approving incentive awards for the 2010 – 2012 program period. The CPUC is also considering modifications to the incentive mechanism that would apply to future program periods (2013 and beyond), but has not established a schedule for a decision.
 
 
Natural Gas Procurement
 
The Sempra Utilities procure natural gas on behalf of their core natural gas customers. The CPUC has established incentive mechanisms to allow the Sempra Utilities the opportunity to share in the savings and/or costs from buying natural gas for their core customers at prices below or above monthly market-based benchmarks. In 2008, the SDG&E and SoCalGas core natural gas supply portfolios were combined, and SoCalGas now procures natural gas for SDG&E’s core natural gas customers’ requirements. All SDG&E assets associated with its core natural gas supply portfolio were transferred or assigned to SoCalGas. Accordingly, SDG&E’s incentive mechanism for natural gas procurement awards or penalties ended as of the effective date of the combination of the core natural gas supply portfolios, and SoCalGas’ gas cost incentive mechanism (GCIM) is applied on the combined portfolio basis going forward.
 
In September 2011, the CPUC approved SoCalGas’ application for its GCIM award of $6 million for natural gas procured for its core customers during the 12-month period ending March 31, 2010.
 
In June 2011, SoCalGas applied to the CPUC for approval of a GCIM award of $6.2 million for natural gas procured for its core customers during the 12-month period ending March 31, 2011. SoCalGas expects a CPUC decision in the first half of 2012.
 
In January 2010, the CPUC approved a GCIM award of $12 million for SoCalGas’ procurement activities during the 12-month period ending March 31, 2009.
 
 
Unbundled Natural Gas Storage and System Operator Hub Services
 
The CPUC has established a revenue sharing mechanism which provides for the sharing between ratepayers and SoCalGas (shareholders) of the net revenues generated by SoCalGas’ unbundled natural gas storage and system operator hub services. Annual net revenues (revenues less allocated service costs) are shared on a graduated basis, as follows:
 
§  
the first $15 million of net revenue to be shared 90 percent ratepayers/10 percent shareholders;
 
§  
the next $15 million of net revenue to be shared 75 percent ratepayers/25 percent shareholders;
 
§  
all additional net revenues to be shared evenly between ratepayers and shareholders; and
 
§  
the maximum total annual shareholder-allocated portion of the net revenues cannot exceed $20 million.
 
 
Operational Incentives
 
The CPUC may establish operational incentives and associated performance benchmarks as part of a general rate case or cost of service proceeding. Through the end of 2011, the Sempra Utilities had operational incentives that applied to their performance in the area of employee safety.
 
 
COST OF CAPITAL
 
A cost of capital proceeding determines a utility’s authorized capital structure and authorized rate of return on rate base (ROR), which is a weighted average of the authorized returns on debt, preferred stock, and common equity (return on equity or ROE). The authorized rate of return is the rate that the Sempra Utilities may earn on their electric and natural gas distribution, natural gas transmission and electric generation assets. In addition, a cost of capital proceeding also addresses market-based benchmarks to be monitored to determine whether an adjustment to the established authorized rate of return is required during the interim years between proceedings through the approved adjustment mechanism.
 
SDG&E’s authorized ROE is 11.10 percent and its authorized ROR is 8.40 percent. SDG&E’s current authorized capital structure is
 
§  
49.0 percent common equity
 
§  
5.75 percent preferred equity
 
§  
45.25 percent long-term debt
 
Unless the benchmark interest rates, as described below, change from current levels, the authorized ROE and ROR will remain in effect until SDG&E’s next cost of capital proceeding is completed. SDG&E’s next cost of capital application is scheduled to be filed in April 2012 for a 2013 test year, consistent with the schedule for cost of capital applications for each of Edison and Pacific Gas and Electric Company (PG&E).
 
SoCalGas’ authorized ROE is 10.82 percent and its authorized ROR is 8.68 percent. These rates continue to be effective until market interest rate changes are large enough to trigger an automatic adjustment or until either the CPUC orders a periodic review or SoCalGas files a cost of capital application. In its 2012 GRC application, SoCalGas advised the CPUC that it plans to file a cost of capital application in April 2012 for a 2013 test year, at the same time as the other California IOUs. SoCalGas’ current authorized capital structure is
 
§  
48.0 percent common equity
 
§  
6.39 percent preferred equity
 
§  
45.61 percent long-term debt
 
In addition to establishing the authorized ROR, a cost of capital proceeding also addresses market-based benchmarks to be monitored to determine whether an adjustment to the established authorized rate of return is required during the interim years between cost of capital proceedings. SDG&E’s cost of capital benchmark is based on the 12-month average monthly A-rated utility bond yield as published by Moody’s for the 12-month period October through September of each fiscal year. If this 12-month average falls outside of the range of 5.02 percent to 7.02 percent, SDG&E’s authorized rate of return would be adjusted, upward or downward, by one-half of the difference between the 12-month average and 6.02 percent (SDG&E’s benchmark interest rate), effective January 1 following the year in which the benchmark range was exceeded. In the event of such an event occurring, the benchmark interest rate would be reset to the interest rate in effect at the time it was determined that the benchmark range had been exceeded.
 
SoCalGas’ cost of capital trigger mechanism (the Market Indexed Capital Adjustment Mechanism or MICAM) identifies two conditions for determining whether a change in the authorized rate of return is required. Both conditions are based on the 30-year Treasury bond yields – one being the most recent trailing 12-month rolling average yield and the second being the corresponding 12-month forward forecast yield as published by Global Insight. If both conditions fall outside a range of 3.88 percent (MICAM floor) to 6.88 percent (MICAM ceiling) in a given month, SoCalGas’ authorized ROE would be adjusted, upward or downward, by one-half of the difference between the trailing 12-month rolling average yield and 5.38 percent (SoCalGas’ MICAM benchmark interest rate), effective January 1 following the year in which both conditions were exceeded. Also, SoCalGas’ authorized recovery rate for the cost of debt and preferred stock would be adjusted to their actual weighted average cost. Therefore, SoCalGas’ authorized ROR would adjust, upward or downward, as a result of all three cost adjustments. In the event of such an event occurring, the benchmark interest rate would be reset to the interest rate in effect at the time it was determined that the benchmark range had been exceeded.
 
At December 31, 2011, neither SDG&E’s nor SoCalGas’ benchmark range has been exceeded. As of January 31, 2012, the historical rolling average yield for the 30-year Treasury bonds of 3.79 percent fell below the MICAM floor of 3.88 percent. In addition, the Global Insight 12-month forward forecasted yield of 3.48 percent published in early February 2012 is also below the MICAM floor. Therefore, SoCalGas’ MICAM mechanism calls for an adjustment of its ROE and authorized recovery for the cost of debt and preferred stock to their actual weighted average cost to be effective on January 1, 2013. However, as SoCalGas has advised the CPUC of its plan to file a cost of capital application in April 2012 along with the other California IOUs, SoCalGas expects that the decision from this cost of capital application will supersede the rates that would result from the MICAM trigger. As there haven’t been any objections raised to SoCalGas’ proposal to file a cost of capital application, management believes that the CPUC will accept SoCalGas’ application. Absent a SoCalGas cost of capital application and proceeding, SoCalGas’ ROE would be reduced to 10.02 percent effective January 1, 2013, a reduction of 80 basis points from its current authorized ROE, and its authorized ROR would be reduced to 8.05 percent, a reduction of 63 basis points from its current authorized ROR.
 
 
ADVANCED METERING INFRASTRUCTURE
 
 
SDG&E
 
SDG&E’s project to install advanced meters with integrated two-way communications functionality, including electric remote disconnect and home area network capability, was substantially completed by the end of 2011.
 
 
SoCalGas
 
In April 2010, the CPUC issued a decision approving SoCalGas’ application to upgrade approximately six million natural gas meters with an advanced metering infrastructure (AMI), subject to certain safeguards to better ensure its cost effectiveness for ratepayers. The approved cost of the project is $1.05 billion (including approximately $900 million in capital investment), with SoCalGas being subject to risk/reward sharing for costs above or below this amount. Installation of the meters is expected to begin in early 2013 and continue through mid 2017.
 
In November 2011, the Division of Ratepayer Advocates (DRA) and The Utility Reform Network (TURN) filed a joint petition requesting that the CPUC reconsider its prior approval of SoCalGas’ AMI project and stay AMI deployment while the CPUC considers the request. The CPUC has taken no action in response to the DRA/TURN request, and SoCalGas is continuing its deployment of AMI pursuant to the April 2010 CPUC decision.
 
 
SDG&E REQUEST FOR AUTHORITY TO INVEST IN WIND FARM
 
In July 2011, the CPUC approved a settlement agreement regarding SDG&E’s request to make a tax equity investment in the holding company of a wind farm project. In December 2011, the Federal Energy Regulatory Commission (FERC) approved SDG&E’s involvement in the project and the associated power purchase agreement. These approvals allow SDG&E to make an investment after the wind farm project has met all of the conditions precedent set forth in the definitive documents and upon the initiation of commercial operation of the project. The approved investment, which would be included in the utility’s rate base, is the lesser of $250 million or 64.99 percent of the project’s costs. SDG&E would also make an incremental investment, to be excluded from the utility’s rate base, of no less than 10 percent of the project’s costs. SDG&E expects the project to be in commercial operation in late 2012.
 
 
2007 WILDFIRES COST RECOVERY FOR RESTORATION OF COMPANY FACILITIES
 
In October 2010, the CPUC issued a decision approving a settlement agreement between SDG&E and the DRA, authorizing SDG&E to recover $43 million of capital costs incurred to replace and repair company facilities under CPUC jurisdiction damaged by the October 2007 wildfires. This decision was in response to an application that SDG&E filed with the CPUC in March 2009 seeking to recover $49.8 million of incremental costs ($43 million of capital costs and $6.8 million of operation and maintenance costs).
 
SDG&E also incurred $30.1 million of incremental costs for the replacement and repair of company facilities under FERC jurisdiction, which are currently being recovered in SDG&E’s electric transmission rates.
 
We discuss recovery of 2007 wildfire litigation costs in Note 15.
 
 
INCREMENTAL INSURANCE PREMIUM COST RECOVERY
 
In December 2010, the CPUC approved SDG&E’s request for a $29 million revenue requirement for the recovery of the incremental increase in its general liability and wildfire liability insurance premium costs for the 2009/2010 policy period. In its decision approving this cost recovery, the CPUC also authorized SDG&E to request recovery of any incremental insurance premiums for future policy periods through December 31, 2011, with a $5 million deductible applied to each policy renewal period. This approval was in response to a request filed by SDG&E with the CPUC in August 2009 seeking authorization to recover higher liability insurance premiums (amounts in excess of those authorized to be recovered in the 2008 GRC), which SDG&E began incurring commencing July 1, 2009, and any losses realized due to higher deductibles associated with the new policies. SDG&E made the filing under the CPUC’s rules allowing utilities to seek recovery of significant cost increases incurred between GRC filings resulting from unforeseen circumstances. The CPUC’s rules allow a utility to seek recovery of incurred costs that meet certain criteria, subject to a $5 million deductible per event.
 
In December 2011, the CPUC approved SDG&E’s request for an incremental revenue requirement of $63 million for the 2010/2011 policy period. SDG&E recorded the revenue resulting from this decision in the fourth quarter of 2011. In addition, SDG&E’s fourth quarter 2011 earnings include revenue to recover $28 million of incremental insurance premiums incurred in the six month period of July through December 2011 for which a final decision from the CPUC is pending. We expect a CPUC decision on this request in the second quarter of 2012.
 
 
EXCESS WILDFIRE CLAIMS COST RECOVERY
 
SDG&E and SoCalGas filed an application, along with other related filings, with the CPUC in August 2009 proposing a new mechanism for the future recovery of all wildfire-related expenses for claims, litigation expenses and insurance premiums that are in excess of amounts authorized by the CPUC for recovery in rates. This application was made jointly with Edison and PG&E. In July 2010, the CPUC approved SDG&E’s and SoCalGas’ requests for separate regulatory memorandum accounts to record the subject expenses while the application is pending before the CPUC. Several parties protested the original application and, in response, the four utilities jointly submitted an amended application in August 2010. A February 2011 ruling directing the utilities to show cause why the application should not be dismissed was stayed to permit continued settlement discussions between the four utilities and the CPUC and with the other parties to the proceeding. In June 2011, the CPUC issued a ruling scheduling evidentiary hearings in October with a decision in 2012. In September 2011, the CPUC delayed hearings to January 2012. In November 2011, Edison and PG&E requested to withdraw from the joint utility application due, in part, to the delays in the proceeding. In January 2012, the CPUC granted their requests to withdraw and held evidentiary hearings for SDG&E and SoCalGas, both of which are still moving forward with the application. We expect a CPUC decision in the second half of 2012.
 
SDG&E intends to request recovery for costs incurred associated with the 2007 wildfires that are in excess of amounts recovered from its insurance coverage and other responsible third parties in a future application.  If a cost recovery mechanism covering the 2007 wildfire costs is approved by the CPUC as a result of these proceedings, SDG&E intends to utilize the methodology authorized. Otherwise, SDG&E will file an application for cost recovery utilizing other cost recovery application processes available through the CPUC.
 
We provide additional information about 2007 wildfire litigation costs and their recovery in Note 15.
 
 
NATURAL GAS PIPELINE OPERATIONS SAFETY ASSESSMENTS
 
As a result of recent natural gas pipeline explosions in the U.S., including the September 2010 rupture in San Bruno, California of a natural gas pipeline owned and operated by PG&E (the San Bruno incident), various regulatory agencies, including the CPUC, are evaluating natural gas pipeline safety regulations, practices and procedures.
 
In February 2011, the CPUC opened a forward-looking rulemaking proceeding to examine what changes should be made to existing pipeline safety regulations for California natural gas pipelines. The Sempra Utilities are parties to this proceeding. The CPUC also appointed an independent review panel to make recommendations for possible actions by the CPUC in light of the San Bruno incident. The panel issued its report in June 2011 providing a number of conclusions regarding the San Bruno incident specifically, as well as general recommendations for pipeline operations and their oversight by regulatory agencies going forward.
 
In June 2011, the CPUC directed SoCalGas, SDG&E, PG&E and Southwest Gas to file comprehensive implementation plans to test or replace all natural gas transmission pipelines that have not been pressure tested. The Sempra Utilities filed their Pipeline Safety Enhancement Plan (PSEP) with the CPUC in August 2011. The proposed safety measures, investments and estimated costs are not included in the Sempra Utilities’ 2012 GRC requests discussed above. The comprehensive plan covers all of the utilities’ approximately 4,000 miles of transmission lines (3,750 miles for SoCalGas and 250 miles for SDG&E) and would be implemented in two phases:
 
§  
Phase 1 focuses on populated areas of SoCalGas’ and SDG&E’s service territories and would be implemented over a 10-year period, from 2012 to 2022.
 
§  
Phase 2 covers unpopulated areas of SoCalGas’ and SDG&E’s service territories and will be filed with the CPUC at a later date.
 
The total cost estimate for Phase 1, over the 10-year period of 2012 to 2022, is $3.1 billion ($2.5 billion for SoCalGas and $600 million for SDG&E). In their August 2011 filing, the utilities requested the CPUC to authorize funding for the recovery of costs through 2015 of approximately $1.5 billion for SoCalGas, of which $1.2 billion would be capital investment, and $240 million for SDG&E, of which $230 million would be capital investment. After 2015, the utilities proposed to include the costs of the PSEP in their next General Rate Case (for their authorized revenue requirements in 2016). The utilities also proposed that the cost of the program be recovered through a surcharge, rather than by incorporating it into rates. The surcharge would increase over time, as more project work is completed.
 
In December 2011, the assigned Commissioner to the rulemaking proceeding for the pipeline safety regulations ruled that SDG&E’s and SoCalGas’ Triennial Cost Allocation Proceeding (TCAP) would be the most logical proceeding to conduct the reasonableness and ratemaking review of the companies’ PSEP. In the TCAP, SDG&E and SoCalGas will, among other things, seek to: (1) establish and revise gas rates to reflect updated customer class allocations of each company’s respective base margin costs authorized in the most recent GRC; (2) update demand forecasts; and (3) support continuation of balancing account treatment for noncore transportation revenue requirements.  In February 2012, the assigned Commissioner to the TCAP issued a scoping memo for the companies’ TCAP, including their PSEP. This scoping memo sets evidentiary hearings for the first phase of the TCAP, which addresses the scope and reasonableness of the PSEP, in the third quarter of 2012, with briefs scheduled to be filed early in the fourth quarter of 2012.
 
On January 17, 2012, the CPUC Consumer Protection and Safety Division (CPSD) issued a Technical Report of the Sempra Utilities’ PSEP.  The report, along with testimony and evidentiary hearings, will be used to evaluate the PSEP in the regulatory process (once a schedule is established).  Generally, the report found that the PSEP approach to pipeline replacement and pressure testing and other proposed enhancements is reasonable. 
 
In January 2011, the National Transportation Safety Board (NTSB) issued seven safety recommendations in connection with its investigation into the cause of the San Bruno incident. According to the NTSB, these safety recommendations “were issued to address record-keeping problems that could create conditions in which a pipeline is operated at a higher pressure than the pipe was built to withstand.” In response to a request from the CPUC, each of the Sempra Utilities reviewed its pipeline facilities located or operating in populated or high consequence areas, as defined by the NTSB, to identify those segments that have not had the maximum allowable operating pressure (MAOP) established through prior hydrostatic testing. Federal and state regulations allow natural gas pipelines installed prior to July 1, 1970 to establish MAOPs through prior operating history rather than through a strength test, but strength tests are required on natural gas pipelines installed subsequent to June 30, 1970 as an element in establishing MAOPs.
 
In response to the CPUC’s request, the Sempra Utilities conducted a detailed review of 1,622 miles of pipelines (1,416 miles for SoCalGas and 206 miles for SDG&E) installed in the subject class locations, and on April 15, 2011, the Sempra Utilities submitted a report to the CPUC on the results of their review and the actions they are taking in response to the NTSB recommendations.
 
The Sempra Utilities’ records review process did not reveal any significant concerns with the currently established MAOP for their pipelines, and the Sempra Utilities intend to continue to operate their pipelines in a safe and prudent manner.
 
 
NATURAL GAS PIPELINE SAFETY LEGISLATION
 
In October 2011, the California legislature enacted five separate legislative bills (SB44, SB216, SB705, SB879 and AB56) that address natural gas pipeline safety. Each bill addresses a different aspect of natural gas pipeline safety and imposes requirements on the CPUC and the natural gas pipeline operator. These include such things as the development of a safety plan; installation of automatic shut-off and remote controlled gas valves; emergency response; reporting; ratemaking; and increasing the maximum penalty for gas pipeline safety violations. Much of the legislation is addressed by the utility safety plans being reviewed by the CPUC, and the Sempra Utilities do not expect that the legislation will have a material impact on their results of operations, financial condition or cash flows.
 
 
AIR QUALITY AND GREENHOUSE GAS REGULATION
 
The California Legislature enacted Assembly Bill 32 (AB 32) and California Senate Bill 1368 in 2006. These laws mandate, among other things, reductions in greenhouse gas (GHG) emissions and the payment of GHG administration fees annually. The California Air Resources Board (CARB), the agency responsible for establishing the compliance rules and regulations for the regulation of GHG under AB 32, has adopted a number of regulations pursuant to AB 32, including CARB’s GHG administration fees regulation and its GHG emissions trading regulation.
 
On October 20, 2011, the CARB finalized details of the cap and trade regulation authorized by AB 32. CARB intends to implement its cap and trade program in 2013. Certain legal challenges have been raised regarding the implementation of cap and trade (Associations of Irritated Residents, et al. v. California Air Resources Board). In September 2011, the California Supreme Court declined to immediately halt implementation of the CARB’s cap and trade program. The Supreme Court’s decision was limited only to a stay application before the California Court of Appeals, and was not a ruling on the merits of the legal challenges against cap and trade, which is still subject to appeal. No injunction has been issued by any court delaying adoption of the cap and trade program and it is currently proceeding.
 
These legislative and regulatory mandates could affect costs and growth at the Sempra Utilities and at Sempra Generation’s power plants. Any cost impact at the Sempra Utilities is expected to be recoverable through rates. As discussed in Note 15 under “Environmental Issues,” compliance with this and similar legislation could adversely affect Sempra Generation. However, such legislation could also have a positive impact on Sempra Generation because of an increasing preference for natural gas and renewables for electric generation, as opposed to other sources.
 

 

NOTE 15. COMMITMENTS AND CONTINGENCIES
 

 
LEGAL PROCEEDINGS
 
We accrue losses for legal proceedings when it is probable that a loss has been incurred and the amounts of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to estimate with reasonable certainty the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed applicable insurance coverages and could materially adversely affect our business, cash flows, results of operations, and financial condition. Unless otherwise indicated, we are unable to estimate reasonably possible losses in excess of any amounts accrued.
 
At December 31, 2011, Sempra Energy’s accrued liabilities for material legal proceedings, on a consolidated basis, were $625 million. At December 31, 2011, accrued liabilities for material legal proceedings for SDG&E and SoCalGas were $596 million and $18 million, respectively. At December 31, 2011, liabilities of $596 million at Sempra Energy and SDG&E were related to wildfire litigation discussed below.
 
 
SDG&E
 
 
2007 Wildfire Litigation
 
In October 2007, San Diego County experienced several catastrophic wildfires. Reports issued by the California Department of Forestry and Fire Protection (Cal Fire) concluded that two of these fires (the Witch and Rice fires) were SDG&E “power line caused” and that a third fire (the Guejito fire) occurred when a wire securing a Cox Communications’ (Cox) fiber optic cable came into contact with an SDG&E power line “causing an arc and starting the fire.” Cal Fire reported that the Rice fire burned approximately 9,500 acres and damaged 206 homes and two commercial properties, and the Witch and Guejito fires merged and eventually burned approximately 198,000 acres, resulting in two fatalities, approximately 40 firefighters injured and approximately 1,141 homes destroyed.
 
A September 2008 staff report issued by the CPUC’s CPSD reached substantially the same conclusions as the Cal Fire reports, but also contended that the power lines involved in the Witch and Rice fires and the lashing wire involved in the Guejito fire were not properly designed, constructed and maintained. In April 2010, proceedings initiated by the CPUC to determine if any of its rules were violated were settled with SDG&E’s payment of $14.75 million.
 
Numerous parties have sued SDG&E and Sempra Energy in San Diego County Superior Court seeking recovery of unspecified amounts of damages, including punitive damages, from the three fires. These include owners and insurers of properties that were destroyed or damaged in the fires and public entities seeking recovery of firefighting, emergency response, and environmental costs. They assert various bases for recovery, including inverse condemnation based upon a California Court of Appeal decision finding that another California investor-owned utility was subject to strict liability, without regard to foreseeability or negligence, for property damages resulting from a wildfire ignited by power lines.
 
In October 2010, the Court of Appeal affirmed the trial court’s ruling that these claims must be pursued in individual lawsuits, rather than as class actions on behalf of all persons who incurred wildfire damages. In February 2011, the California Supreme Court denied a petition for review of the affirmance. The trial court has scheduled a Witch fire and Guejito fire trial to begin in March 2013.
 
SDG&E filed cross-complaints against Cox seeking indemnification for any liability that SDG&E might incur in connection with the Guejito fire, two SDG&E contractors seeking indemnification in connection with the Witch fire, and one SDG&E contractor seeking indemnification in connection with the Rice fire.
 
In December 2010, SDG&E and Cox reached an agreement settling SDG&E’s claims against Cox and Cox’s insurers in the wildfire litigation (Cox Settlement). Among other things, the settlement agreement provided that SDG&E receive approximately $444 million for wildfire related expenditures, and SDG&E will defend and indemnify Cox against all compensatory damage claims and related costs arising out of the wildfires.
 
At December 31, 2010, the $300 million Settlement Receivable Related to Wildfire Litigation on the Consolidated Balance Sheets of Sempra Energy and SDG&E represented cash to be received in accordance with the terms of the Cox Settlement in several payments through March 2011 and which was received. As of December 31, 2011, there was no wildfire-related restricted cash on the Consolidated Balance Sheets of Sempra Energy and SDG&E as all amounts received from Cox had been applied to wildfire related expenditures.
 
SDG&E has settled all of the approximately 19,000 claims brought by homeowner insurers for damage to insured property relating to the three fires. Under the settlement agreements, SDG&E has paid or will pay 57.5 percent of the approximately $1.6 billion paid or reserved for payment by the insurers to their policyholders and received an assignment of the insurers’ claims against other parties potentially responsible for the fires.
 
The wildfire litigation also includes claims of non-insurer plaintiffs for damage to uninsured and underinsured structures, business interruption, evacuation expenses, agricultural damage, emotional harm, personal injuries and other losses. SDG&E has settled the claims of approximately 2,750 of these plaintiffs. Approximately 650 of the approximately 1,650 remaining individual and business plaintiffs have submitted settlement demands and damage estimates totaling approximately $750 million and government entity claims totaling approximately $80 million. SDG&E expects to receive additional settlement demands and damage estimates as settlement negotiations continue. SDG&E has established reserves for the wildfire litigation as we discuss below.
 
SDG&E’s settled claims and defense costs have exceeded its $1.1 billion of liability insurance coverage and the $444 million it received from Cox. It expects that its wildfire reserves and amounts paid to resolve wildfire claims will continue to increase as it obtains additional information; it is presently unable to reasonably estimate the amount or timing of recoveries from other potentially responsible parties.
 
SDG&E has concluded, however, that it is probable that it will be permitted to recover from its utility customers substantially all reasonably incurred costs of resolving wildfire claims in excess of its liability insurance coverage and any amounts recovered from other potentially responsible parties. Accordingly, although such recovery will require future regulatory actions, at December 31, 2011 and December 31, 2010, SDG&E recorded a regulatory asset of $594 million and $364 million, respectively, which represents the amount substantially equal to the aggregate amount it has paid or reserved for payment for the resolution of wildfire claims and related costs in excess of its liability insurance coverage and amounts received from Cox. SDG&E will increase the regulatory asset as additional amounts are paid or reserves are recorded and reduce it by any amounts recovered from other potentially responsible parties.
 
As a consequence of the expected recovery of wildfire costs from utility customers, Sempra Energy and SDG&E expect no significant earnings impact from the resolution of the remaining wildfire claims. However, SDG&E’s cash flow may be materially adversely affected due to the timing differences between the resolution of claims and the recoveries from other potentially responsible parties and utility customers, which may extend over a number of years. Also, recovery from customers will require future regulatory actions, and a failure to obtain substantial or full recovery, or any negative assessment of the likelihood of recovery, would likely have a material adverse effect on Sempra Energy’s and SDG&E’s financial position, cash flows and results of operations.
 
SDG&E will continue to gather information to evaluate and assess the remaining wildfire claims and the likelihood, amount and timing of related recoveries from other potentially responsible parties and utility customers and will make appropriate adjustments to wildfire reserves and the related regulatory asset as additional information becomes available.
 
In 2010 and 2011, as liabilities for wildfire litigation have become reasonably estimable in the form of settlement demands, damage estimates, and other damage information, SDG&E has recorded related reserves as a liability. The impact of this liability at December 31, 2011 is offset by the recognition of a regulatory asset, as discussed above, for reserves in excess of the insurance coverage and the Cox Settlement. The impact of the reserves on SDG&E’s and Sempra Energy’s after-tax earnings was $13 million and $20 million for the years ended December 31, 2011 and 2010, respectively. There was no effect on SDG&E’s or Sempra Energy’s 2009 earnings from the recording of the reserves. At December 31, 2011, wildfire litigation reserves were $596 million ($586 million in current and $10 million in long-term).
 
Sunrise Powerlink Electric Transmission Line
 
SDG&E commenced construction on the Sunrise Powerlink in the fall of 2010. The Sunrise Powerlink is a new 117-mile, 500-kV electric transmission line that is being built between the Imperial Valley and the San Diego region, along a route that generally runs south of the Anza-Borrego Desert State Park. The current project plan provides for the transmission line to be completed and in-service in the second half of 2012.
 
The Sunrise Powerlink project was originally approved by the CPUC in December 2008, including approval of the environmental impact review conducted jointly with the Bureau of Land Management (BLM). The CPUC has subsequently denied or dismissed all requests for rehearing of its approval of the project.
 
In February 2011, the California Supreme Court denied a petition filed jointly by the Utility Consumers’ Action Network (UCAN) and the Center for Biological Diversity/Sierra Club (CBD). The petition challenged the CPUC’s decision with regard to implementation of the California Environmental Quality Act (CEQA). In addition, in August 2010, the California Court of Appeal denied a petition previously filed by UCAN with the Court of Appeal challenging the CPUC decision on other legal grounds.
 
In January 2009, the BLM issued its decision approving the portions of the project, route and environmental review within its jurisdiction. The Interior Board of Land Appeals (IBLA) subsequently denied or dismissed all administrative appeals that were filed challenging the BLM’s approval of the project.
 
The CPUC and BLM jointly approved the final Project Modification Report for Sunrise Powerlink in September 2010, accepting all of the proposed modifications to the approved route and finding that no additional environmental review was required. In December 2010, the IBLA dismissed an appeal challenging the BLM’s approval of the Project Modification Report. In March 2011, opponents of the Sunrise Powerlink filed a petition for writ of review or mandamus with the California Supreme Court challenging the CPUC’s acceptance of the Project Modification Report. The California Supreme Court denied the petition in April 2011.
 
In February 2010, parties opposed to the project filed a lawsuit in Federal District Court in San Diego seeking declaratory and injunctive relief and alleging that the BLM failed to properly address the environmental impacts of the approved Sunrise Powerlink route and the related potential development of renewable resources in east San Diego County and Imperial County. In June 2011, the court granted the defendants’ motion for summary judgment on the grounds that the plaintiffs were not challenging final government agency actions. The plaintiffs have appealed to the U.S. Court of Appeals for the Ninth Circuit.
 
In July 2010, the United States Forest Service (USFS) issued its decision approving the portions of the project, route and environmental review within its jurisdiction. The USFS has subsequently denied all administrative appeals challenging its approval of the project.
 
In January 2011, project opponents filed a lawsuit in Federal District Court in San Diego alleging that the federal approvals for construction of the project on USFS land and BLM land violated the National Environmental Policy Act and other federal environmental laws. The lawsuit asks the court for injunctive relief preventing the USFS and the BLM from approving any ongoing or future construction activities. In October 2011, the opponents appealed the court’s denial of their motion for a preliminary injunction.
 
In February 2011, opponents of the Sunrise Powerlink filed a lawsuit in Sacramento County Superior Court against the State Water Resources Control Board and SDG&E alleging that the water quality certification issued by the Board under the Federal Clean Water Act violated CEQA. The complaint seeks to have the certification set aside and requests an injunction be issued.
 
September 2011 Power Outage
 
In September 2011, a power outage lasting approximately 12 hours affected millions of people from Mexico to southern Orange County, California. Several agencies, including the FERC and North American Electric Reliability Corp., are participating in a joint investigation to determine the cause of the power failure. Within several days of the outage, several SDG&E customers filed a class action lawsuit in Federal District Court against Arizona Public Service Company, Pinnacle West, and SDG&E alleging that the companies failed to prevent the outage. The lawsuit seeks recovery of unspecified amounts of damages, including punitive damages. In addition, more than 6,500 customers’ claims, primarily related to food spoilage, have been submitted directly to SDG&E.
 
Smart Meters Patent Infringement Lawsuit
 
In October 2011, SDG&E was sued by a Texas design and manufacturing company in Federal District Court alleging that SDG&E’s recently installed smart meters infringed certain patents. The meters were purchased from a third party vendor that has agreed to defend and indemnify SDG&E. The lawsuit seeks injunctive relief and recovery of unspecified amounts of damages.
 

SoCalGas
 
SoCalGas, along with Monsanto Co., Solutia, Inc., Pharmacia Corp., and Pfizer, Inc., are defendants in two Los Angeles County Superior Court lawsuits served in May 2011 seeking recovery of unspecified amounts of damages, including punitive damages, as a result of plaintiffs’ exposure to PCBs (polychlorinated biphenyls). The lawsuits allege plaintiffs were exposed to PCBs not only through the food chain and other various sources but from PCB-contaminated natural gas pipelines owned and operated by SoCalGas. This contamination allegedly caused plaintiffs to develop cancer and other serious illnesses. Plaintiffs assert various bases for recovery, including negligence and products liability.
 
 
Sempra Pipelines & Storage
 
Liberty Gas Storage, LLC (Liberty) received a demand for arbitration from Williams Midstream Natural Gas Liquids, Inc. (Williams) in February 2011 related to a sublease agreement. Williams alleges that Liberty was negligent in its attempt to convert certain salt caverns to natural gas storage and seeks damages of $56.7 million. Liberty filed a counterclaim alleging breach of contract in the inducement and seeks damages of more than $215 million.
 
 
Sempra LNG
 
Sempra LNG has been engaged in a long-running land dispute relating to property adjacent to its Energía Costa Azul liquefied natural gas (LNG) terminal near Ensenada, Mexico. The adjacent property is not required by environmental or other regulatory permits for the operation of the terminal. A claimant to the adjacent property has nonetheless asserted that his health and safety are endangered by the operation of the facility. In June 2010, a Mexican federal appeals court revoked a district court order, issued at the behest of the claimant, directing Mexican regulatory authorities to provisionally suspend authorizations for the operation of the LNG terminal. In February 2011, based on a complaint by the claimant, the new Ensenada Mayor attempted to temporarily close the terminal based on claims of irregularities in municipal permits issued six years earlier. This attempt was promptly countermanded by Mexican federal and Baja California state authorities. No terminal permits or operations were affected as a result of these proceedings or events and the terminal has continued to operate normally.
 
Sempra LNG expects additional Mexican court proceedings and governmental actions regarding the claimant’s assertions as to whether the terminal’s permits should be modified or revoked in any manner.
 
The property claimant also filed a lawsuit in July 2010 against Sempra Energy in Federal District Court in San Diego seeking compensatory and punitive damages as well as the earnings from the Energía Costa Azul LNG terminal based on his allegations that he was wrongfully evicted from the adjacent property and that he has been harmed by other allegedly improper actions.
 
 
Other Litigation
 
In August 2007, the U.S. Court of Appeals for the Ninth Circuit issued a decision reversing and remanding certain FERC orders declining to provide refunds regarding short-term bilateral sales up to one month in the Pacific Northwest for the December 2000 to June 2001 time period. In December 2010, the FERC approved a comprehensive settlement previously reached by Sempra Energy and RBS Sempra Commodities with the State of California. The settlement resolves all issues with regard to sales between the California Department of Water Resources (DWR) and Sempra Commodities in the Pacific Northwest, but potential claims may exist regarding sales between Sempra Commodities and other buyers in the Pacific Northwest. The FERC is in the process of addressing these potential claims on remand. Pursuant to the agreements related to the formation of RBS Sempra Commodities, we have indemnified RBS should the liability from the final resolution of these matters be greater than the reserves related to Sempra Commodities. Pursuant to our agreement with the Noble Group, we have also indemnified Noble Americas Gas & Power Corp. and its affiliates for all losses incurred by such parties resulting from these proceedings as related to Sempra Commodities.
 
Sempra Energy and several subsidiaries, along with three oil and natural gas companies, the City of Beverly Hills, and the Beverly Hills Unified School District, are defendants in toxic tort lawsuits filed beginning in 2003 in Los Angeles County Superior Court by approximately 1,000 plaintiffs. These lawsuits claim that various emissions resulted in cancer or fear of cancer. In November 2006, the court granted the defendants’ summary judgment motions based on lack of medical causation for the 12 initial plaintiffs scheduled to go to trial first. The court also granted summary judgment excluding punitive damages. The court has stayed the lawsuits as to the remaining plaintiffs pending the appeal of the rulings. A mediation occurred in June 2010, after which the plaintiffs’ counsel agreed to recommend a settlement of the lawsuits as to Sempra Energy and its subsidiaries for an amount that is not significant and has been recorded. Any such settlement will require approval by each of the plaintiffs. If approval is obtained, finalization of the settlement is expected to occur within six months.
 
We are also defendants in ordinary routine litigation incidental to our businesses, including personal injury, product liability, property damage and other claims. California juries have demonstrated an increasing willingness to grant large awards, including punitive damages, in these types of cases.
 
 
Resolved Matters
 
We discuss certain commitments remaining from an energy crisis matter resolved prior to 2010 below under “Other Commitments.”
 
The following is a description of the 2010 litigation settlements relating to California energy crisis matters.
 
Energy Crisis Litigation Settlement
 
In 2010, Sempra Energy, RBS Sempra Commodities and Sempra Generation reached a comprehensive settlement with the State of California to resolve substantially all of their remaining litigation arising out of the 2000 – 2001 California energy crisis for a total payment of $410 million. The matters resolved include the settlement of multiple actions brought by the DWR and other parties with respect to the validity, pricing and operation of Sempra Generation’s contract with the DWR and the settlement of the FERC refund and manipulation proceedings against RBS Sempra Commodities. The FERC approved both settlements in December 2010.
 
The payment of $410 million was funded largely from previously recorded reserves and receivables at RBS Sempra Commodities. Sempra Energy also recorded an additional pretax charge of $159 million in the first quarter of 2010 to provide for the remainder of the settlement, including $139 million at Sempra Generation and $20 million at Sempra Commodities. The amount at Sempra Commodities was reduced by $11 million pretax in the fourth quarter of 2010 to reflect a receipt in January 2011 from an unrelated party that had a joint liability for the claim. In January 2011, Sempra Generation paid $130 million to the DWR under the terms of the settlement agreement.
 
 
CONTRACTUAL COMMITMENTS
 
 
Natural Gas Contracts
 
Natural Gas
 
SoCalGas has the responsibility for procuring natural gas for both SDG&E’s and SoCalGas’ core customers in a combined portfolio. SoCalGas buys natural gas under short-term and long-term contracts for this portfolio. Purchases are from various producing regions in the southwestern U.S., U.S. Rockies, and Canada and are primarily based on published monthly bid-week indices.
 
SoCalGas transports natural gas primarily under long-term firm interstate pipeline capacity agreements that provide for annual reservation charges, which are recovered in rates. SoCalGas has commitments with interstate pipeline companies for firm pipeline capacity under contracts that expire at various dates through 2027.
 
Sempra Global’s businesses have various natural gas purchase agreements to fuel natural gas-fired power plants and capacity agreements for natural gas storage and transportation.
 
At December 31, 2011, the future minimum payments under existing natural gas contracts and natural gas storage and transportation contracts were:
 
Sempra Energy Consolidated
 
 
Storage and
 
 
 
 
(Dollars in millions)
Transportation
Natural Gas(1)
Total(1)
2012 
 
$
 143 
$
 415 
$
 558 
2013 
 
 
 106 
 
 148 
 
 254 
2014 
 
 
 74 
 
 103 
 
 177 
2015 
 
 
 60 
 
 3 
 
 63 
2016 
 
 
 55 
 
 3 
 
 58 
Thereafter
 
 252 
 
 5 
 
 257 
Total minimum payments
$
 690 
$
 677 
$
 1,367 
(1)
Excludes amounts related to LNG purchase agreements at Sempra LNG discussed below.

 
SoCalGas
(Dollars in millions)
Transportation
Natural Gas
Total
2012 
$
 110 
$
 290 
$
 400 
2013 
 
 81 
 
 19 
 
 100 
2014 
 
 55 
 
 2 
 
 57 
2015 
 
 41 
 
 2 
 
 43 
2016 
 
 36 
 
 2 
 
 38 
Thereafter
 
 145 
 
 ― 
 
 145 
Total minimum payments
$
 468 
$
 315 
$
 783 

Total payments under natural gas contracts were:
 
 
Years ended December 31,
(Dollars in millions)
2011 
2010 
2009 
Sempra Energy Consolidated
$
 1,991 
$
 2,097 
$
 1,754 
SoCalGas
 
 1,810 
 
 1,936 
 
 1,452 
 
LNG
 
Sempra LNG has various purchase agreements with major international companies for the supply of LNG to its Energía Costa Azul and Cameron terminals. The agreements range from short-term to multi-year periods and are priced using a predetermined formula based on natural gas market indices.
 
Although these contracts specify a number of cargoes to be delivered, under their terms, customers may divert certain cargoes, which would reduce amounts paid under the contracts by Sempra LNG. As of December 31, 2011, if all cargoes under the contracts were to be delivered, future payments under these contracts would be
 
§  
$517 million in 2012
 
§  
$625 million in 2013
 
§  
$689 million in 2014
 
§  
$733 million in 2015
 
§  
$774 million in 2016
 
§  
$12.1 billion in 2017 – 2029
 
The amounts above are based on forward prices of the index applicable to each contract from 2012 to 2021 and an estimated one percent escalation per year beyond 2021. The LNG commitment amounts above are based on Sempra LNG’s commitment to accept the maximum possible delivery of cargoes under the agreements. Actual LNG purchases in 2011 have been significantly lower than the maximum amount possible.
 
 
Purchased-Power Contracts
 
For 2012, SDG&E expects to receive 9 percent of its customer power requirements from DWR allocations. The remaining requirements are expected to be met as follows:
 
§  
SONGS: 18 percent
 
§  
Long-term contracts: 20 percent (of which 9 percent is provided by renewable energy contracts expiring on various dates through 2037)
 
§  
Other SDG&E-owned generation (including Palomar, Miramar I and II, Desert Star Energy Center and Cuyamaca Peak Energy Plant) and tolling contracts (including OMEC): 40 percent
 
§  
Spot market purchases: 13 percent
 
The long-term contracts expire on various dates through 2037.
 
Chilquinta Energía and Luz del Sur also have purchased-power contracts, with various dates extending through 2025, which cover most of the consumption needs of the companies’ customers. These commitments are included under Sempra Energy Consolidated in the table below.
 
At December 31, 2011, the estimated future minimum payments under long-term purchased-power contracts (not including the DWR allocations for SDG&E) were:
 
 
Sempra
 
 
 
 
Energy
 
 
(Dollars in millions)
Consolidated
SDG&E
2012 
$
 1,049 
$
 319 
2013 
 
 1,120 
 
 321 
2014 
 
 1,110 
 
 260 
2015 
 
 1,164 
 
 229 
2016 
 
 1,199 
 
 231 
Thereafter
 
 9,555 
 
 1,948 
Total minimum payments(1)
$
 15,197 
$
 3,308 
(1)
Excludes purchase agreements accounted for as capital leases and amounts related to Otay Mesa VIE, as it is consolidated by Sempra Energy and SDG&E.

Payments on these contracts represent capacity charges and minimum energy purchases. SDG&E is required to pay additional amounts for actual purchases of energy that exceed the minimum energy commitments. Excluding DWR-allocated contracts, total payments under purchased-power contracts were:
 
 
Years ended December 31,
(Dollars in millions)
2011 
2010 
2009 
Sempra Energy Consolidated
$
918 
$
314 
$
 413 
Sempra Pipelines & Storage
 
572 
 
 - 
 
 - 
SDG&E
 
346 
 
314 
 
 413 
 
Operating Leases
 
Sempra Energy, SDG&E and SoCalGas have operating leases on real and personal property expiring at various dates from 2012 through 2054. Certain leases on office facilities contain escalation clauses requiring annual increases in rent ranging from two percent to six percent at both Sempra Energy and SDG&E and three percent to five percent at SoCalGas. The rentals payable under these leases may increase by a fixed amount each year or by a percentage of a base year, and most leases contain extension options that we could exercise.
 
The Sempra Utilities have an operating lease agreement for future acquisitions of fleet vehicles with RBS Asset Finance, Inc. with an aggregate maximum lease limit of $125 million, $66 million of which has been utilized.
 
Rent expense for all operating leases totaled:
 
 
Years ended December 31,
(Dollars in millions)
2011 
2010 
2009 
Sempra Energy Consolidated
$
 77 
$
 85 
$
 101 
SDG&E
 
 18 
 
 20 
 
 24 
SoCalGas
 
 35 
 
 40 
 
 52 

At December 31, 2011, the minimum rental commitments payable in future years under all noncancelable operating leases were as follows:
 
 
Sempra
 
 
 
Energy
 
 
(Dollars in millions)
Consolidated
SDG&E
SoCalGas
2012 
$
 73 
$
 19 
$
 28 
2013 
 
 72 
 
 18 
 
 28 
2014 
 
 68 
 
 18 
 
 28 
2015 
 
 65 
 
 17 
 
 28 
2016 
 
 60 
 
 17 
 
 26 
Thereafter
 
 538 
 
 46 
 
 240 
Total future rental commitments
$
 876 
$
 135 
$
 378 
 
Capital Leases
 
 
Utility Fleet Vehicles
 
The Sempra Utilities entered into agreements with U.S. Bancorp Equipment Finance in 2009 and with RBS Asset Finance, Inc. in 2010 to refinance existing fleet vehicles. These are capital leases, and as of December 31, 2011, the related capital lease obligations were $24 million at Sempra Energy, including $13 million at SDG&E and $11 million at SoCalGas. As of December 31, 2010, the related capital lease obligations were $39 million at Sempra Energy, including $20 million at SDG&E and $19 million at SoCalGas.
 
At December 31, 2011, the future minimum lease payments and present value of the net minimum lease payments under these capital leases are as follows:
 
 
Sempra
 
 
 
Energy
 
 
(Dollars in millions)
Consolidated
SDG&E
SoCalGas
2012 
$
 13 
$
 7 
$
 6 
2013 
 
 7 
 
 4 
 
 3 
2014 
 
 4 
 
 2 
 
 2 
Total minimum lease payments
 
 24 
 
 13 
 
 11 
Less:  interest
 
 ― 
 
 ― 
 
 ― 
Present value of net minimum lease payments
$
 24 
$
 13 
$
 11 
 
 
 
 
 
 
 
 
The 2011 annual amortization charge for the utility fleet vehicles was $15 million at Sempra Energy, including $7 million at SDG&E and $8 million at SoCalGas. The 2010 annual amortization charge for the utility fleet vehicles was $17 million at Sempra Energy, including $6 million at SDG&E and $11 million at SoCalGas. The 2009 annual amortization charge for the utility fleet vehicles was $3 million at Sempra Energy, including $1 million at SDG&E and $2 million at SoCalGas.
 
 
Power Purchase Agreements
 
SDG&E has two power purchase agreements with peaker plant facilities that went into commercial operation in June 2010 and are accounted for as capital leases. As of December 31, 2011, capital lease obligations for these leases, each with a 25-year term, were valued at $180 million.
 
At December 31, 2011, the future minimum lease payments and present value of the net minimum lease payments under these capital leases for both Sempra Energy Consolidated and SDG&E were as follows:
 

(Dollars in millions)
 
 
2012 
$
 24 
 
2013 
 
 24 
 
2014 
 
 24 
 
2015 
 
 24 
 
2016 
 
 24 
 
Thereafter
 
 442 
 
Total minimum lease payments(1)
 
 562 
 
Less:  estimated executory costs
 
 (93)
 
Less:  interest(2)
 
 (289)
 
Present value of net minimum lease payments(3)
$
 180 
(1)
This amount will be recorded over the lives of the leases as Cost of Electric Fuel and Purchased Power on Sempra Energy’s and SDG&E’s Consolidated Statements of Operations. This expense will receive ratemaking treatment consistent with purchased-power costs.
(2)
Amount necessary to reduce net minimum lease payments to present value at the inception of the leases.
(3)
Includes $2 million in Current Portion of Long-Term Debt and $178 million in Long-Term Debt on Sempra Energy’s and SDG&E’s Consolidated Balance Sheets at December 31, 2011.


The annual amortization charge for the power purchase agreements was $2 million for 2011 and $1 million for 2010.
 
Construction and Development Projects
 
Sempra Energy has various capital projects in progress in the United States, Mexico and South America. The following is a summary of contractual commitments and contingencies related to the construction projects.
 
 
SDG&E
 
At December 31, 2011, SDG&E has commitments to make future payments of $408 million for construction projects that include
 
§  
$147 million for the engineering, material procurement and construction costs associated with the Sunrise Powerlink project; and
 
§  
$205 million related to nuclear fuel fabrication and other construction projects at SONGS.
 
SDG&E expects future payments under these contractual commitments to be $229 million in 2012, $39 million in 2013, $16 million in 2014, $14 million in 2015, $27 million in 2016 and $83 million thereafter.
 
 
SoCalGas
 
At December 31, 2011, SoCalGas has commitments to make future payments of $378 million for construction and infrastructure improvements for natural gas transmission and distribution operations, pipeline integrity and the Advanced Metering Infrastructure Program. The future payments under these contractual commitments are expected to be $60 million in 2012, $72 million in 2013, $65 million in 2014, $65 million in 2015, $6 million in 2016 and $110 million thereafter.
 
 
Sempra Generation
 
At December 31, 2011, Sempra Generation has commitments to make future payments of $836 million for the construction of Mesquite Solar 1 and Copper Mountain 2 Solar facilities. The future payments under these contractual commitments are expected to be $610 million in 2012 and $226 million in 2013.
 
 
Sempra Pipelines & Storage
 
At December 31, 2011, Sempra Pipelines & Storage has commitments to make future payments of $177 million for construction projects that include
 
§  
$129 million for the construction of the Santa Teresa hydroelectric power plant at Luz del Sur; and
 
§  
$34 million for the construction of natural gas storage facilities at Bay Gas and Mississippi Hub.
 
Sempra Pipelines & Storage expects future payments under these contractual commitments to be $96 million in 2012, $73 million in 2013 and $8 million in 2014.
 
 
GUARANTEES
 
Sempra Energy’s guarantees related to RBS Sempra Commodities, Fowler Ridge 2 and Cedar Creek 2 are discussed in Note 5.
 
As of December 31, 2011, SDG&E and SoCalGas did not have any outstanding guarantees.
 
 
DEPARTMENT OF ENERGY NUCLEAR FUEL DISPOSAL
 
The Nuclear Waste Policy Act of 1982 made the DOE responsible for the disposal of spent nuclear fuel. However, it is uncertain when the DOE will begin accepting spent nuclear fuel from SONGS. This delay will lead to increased costs for spent fuel storage.  This cost will be recovered through SONGS revenue unless SDG&E is able to recover the increased cost from the federal government.
 
 
OTHER COMMITMENTS
 
Additional consideration for the settlement discussed above in “Legal Proceedings – Resolved Matters – Energy Crisis Litigation Settlement” included an agreement that, for a period of 18 years beginning in 2011, Sempra LNG would sell to the Sempra Utilities, subject to annual CPUC approval, up to 500 million cubic feet (MMcf) per day of regasified LNG from Sempra LNG’s Energía Costa Azul facility that is not delivered or sold in Mexico at the California border index minus $0.02 per MMBtu.
 
We discuss reserves at Sempra Energy and SDG&E for wildfire litigation above in “Legal Proceedings – SDG&E – 2007 Wildfire Litigation.”
 
 
ENVIRONMENTAL ISSUES
 
Our operations are subject to federal, state and local environmental laws. We also are subject to regulations related to hazardous wastes, air and water quality, land use, solid waste disposal and the protection of wildlife. These laws and regulations require that we investigate and correct the effects of the release or disposal of materials at sites associated with our past and our present operations. These sites include those at which we have been identified as a Potentially Responsible Party (PRP) under the federal Superfund laws and similar state laws.
 
In addition, we are required to obtain numerous governmental permits, licenses and other approvals to construct facilities and operate our businesses. The related costs of environmental monitoring, pollution control equipment, cleanup costs, and emissions fees are significant. Increasing national and international concerns regarding global warming and mercury, carbon dioxide, nitrogen oxide and sulfur dioxide emissions could result in requirements for additional pollution control equipment or significant emissions fees or taxes that could adversely affect Sempra Generation. The Sempra Utilities’ costs to operate their facilities in compliance with these laws and regulations generally have been recovered in customer rates.
 
We generally capitalize the significant costs we incur to mitigate or prevent future environmental contamination or extend the life, increase the capacity, or improve the safety or efficiency of property used in current operations. The following table shows (in millions) our capital expenditures in order to comply with environmental laws and regulations:
 
 
 
Years ended December 31,
 
 
2011 
2010 
2009 
Sempra Energy Consolidated(1)
$
 21 
$
 21 
$
 43 
SDG&E
 
 7 
 
 10 
 
 24 
SoCalGas
 
 13 
 
 10 
 
 17 
(1)
In cases of non-wholly owned affiliates, includes only our share.

Decreases in 2010 compared to 2009 were primarily due to a decrease in environmental-related spending on SoCalGas’ natural gas transmission projects, completion of SDG&E’s Miramar II facility and the deconsolidation of a VIE at SDG&E. We have not identified any significant environmental issues outside the United States. From 2009 through 2013, SDG&E expects to incur costs of approximately $286 million for environmental mitigation measures associated with the Sunrise Powerlink construction project.
 
At the Sempra Utilities, costs that relate to current operations or an existing condition caused by past operations are generally recorded as a regulatory asset due to the probability that these costs will be recovered in rates.
 
The environmental issues currently facing us or resolved during the last three years include (1) investigation and remediation of the Sempra Utilities’ manufactured-gas sites, (2) cleanup of third-party waste-disposal sites used by the Sempra Utilities at sites for which we have been identified as a PRP and (3) mitigation of damage to the marine environment caused by the cooling-water discharge from SONGS. The requirements for enhanced fish protection and restoration of 150 acres of coastal wetlands for the SONGS mitigation are in process and a 150-acre artificial reef was completed in 2008. The table below shows the status at December 31, 2011, of the Sempra Utilities’ manufactured-gas sites and the third-party waste-disposal sites for which we have been identified as a PRP:
 
 
# Sites
# Sites
 
Completed
In Process
SDG&E
 
 
 
 
Manufactured-gas sites
 
 3 
 
 ― 
Third-party waste-disposal sites
 
 1 
 
 1 
SoCalGas
 
 
 
 
Manufactured-gas sites
 
 38 
 
 4 
Third-party waste-disposal sites
 
 1 
 
 2 

We record environmental liabilities at undiscounted amounts when our liability is probable and the costs can be reasonably estimated. In many cases, however, investigations are not yet at a stage where we can determine whether we are liable or, if the liability is probable, to reasonably estimate the amount or range of amounts of the costs. Estimates of our liability are further subject to uncertainties such as the nature and extent of site contamination, evolving cleanup standards and imprecise engineering evaluations. We review our accruals periodically and, as investigations and cleanup proceed, we make adjustments as necessary. The following table shows (in millions) our accrued liabilities for environmental matters at December 31, 2011:
 
 
 
 
Waste
Former Fossil-
Other
 
 
 
Manufactured-
Disposal
Fueled Power
Hazardous
 
 
 
Gas Sites
Sites (PRP)(1)
Plants
Waste Sites
Total
SDG&E(2)
$
 0.1 
$
 ― 
$
 1.0 
$
 0.5 
$
 1.6 
SoCalGas
 
 21.3 
 
 0.5 
 
 ― 
 
 1.6 
 
 23.4 
Other
 
 2.7 
 
 1.2 
 
 ― 
 
 0.1 
 
 4.0 
    Total Sempra Energy
$
 24.1 
$
 1.7 
$
 1.0 
$
 2.2 
$
 29.0 
(1)
Sites for which we have been identified as a Potentially Responsible Party.
(2)
Does not include SDG&E’s liability for SONGS marine mitigation.

We expect to pay the majority of these accruals over the next three years. In connection with the issuance of operating permits, SDG&E and the other owners of SONGS previously reached an agreement with the California Coastal Commission to mitigate the damage to the marine environment caused by the cooling-water discharge from SONGS. At December 31, 2011, SDG&E’s share of the estimated mitigation costs remaining to be spent through 2050 is $17 million, which is recoverable in rates.
 
We discuss renewable energy requirements and greenhouse gas regulation in Note 14.
 
 
NUCLEAR INSURANCE
 
SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. This insurance provides $375 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides for up to $12.2 billion of secondary financial protection (SFP). If a nuclear liability loss occurring at any U.S. licensed/commercial reactor exceeds the $375 million insurance limit, all nuclear reactor owners could be required to contribute to the SFP. SDG&E’s contribution would be up to $47 million. This amount is subject to an annual maximum of $7 million, unless a default occurs by any other SONGS owner. If the SFP is insufficient to cover the liability loss, SDG&E could be subject to an additional assessment.
 
The SONGS owners, including SDG&E, also have $2.75 billion of nuclear property, decontamination, and debris removal insurance. In addition, the SONGS owners have up to $490 million insurance coverage for outage expenses and replacement power costs due to accidental property damage. This coverage is limited to $3.5 million per week for the first 52 weeks, then $2.8 million per week for up to 110 additional weeks. There is a 12-week waiting period deductible. These insurance coverages are provided through a mutual insurance company. Insured members are subject to retrospective premium assessments. SDG&E could be assessed up to $9.6 million.
 
The nuclear property insurance program includes an industry aggregate loss limit for non-certified acts of terrorism (as defined by the Terrorism Risk Insurance Act). The industry aggregate loss limit for property claims arising from non-certified acts of terrorism is $3.24 billion. This is the maximum amount that will be paid to insured members who suffer losses or damages from these non-certified terrorist acts.
 
 
CONCENTRATION OF CREDIT RISK
 
We maintain credit policies and systems to manage our overall credit risk. These policies include an evaluation of potential counterparties’ financial condition and an assignment of credit limits. These credit limits are established based on risk and return considerations under terms customarily available in the industry. We grant credit to utility customers and counterparties, substantially all of whom are located in our service territory, which covers most of Southern California and a portion of central California for SoCalGas, and all of San Diego County and an adjacent portion of Orange County for SDG&E. We also grant credit to utility customers and counterparties of Sempra Pipelines & Storage’s companies providing natural gas or electric services in Mexico, Chile, Peru and southwest Alabama.
 
When they become operational, projects owned or partially owned by Sempra LNG, Sempra Pipelines & Storage and Sempra Generation place significant reliance on the ability of their suppliers and customers to perform on long-term agreements and on our ability to enforce contract terms in the event of nonperformance. We consider many factors, including the negotiation of supplier and customer agreements, when we evaluate and approve development projects.
 
At December 31, 2011, RBS Sempra Commodities no longer requires significant working capital support, although RBS is obligated to provide RBS Sempra Commodities with all credit support. However, we have provided back-up guarantees for a portion of RBS Sempra Commodities’ remaining trading obligations. A few of these back-up guarantees may continue for a prolonged period of time. We provide additional information regarding these back-up guarantees and other guarantees in Note 5.
 

 

NOTE 16. SEGMENT INFORMATION
 

We have five separately managed reportable segments, as follows:
 
1.  
SDG&E provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County.

2.  
SoCalGas is a natural gas distribution utility, serving customers throughout most of Southern California and part of central California.

3.  
Sempra Generation develops, owns and operates, or holds interests in, electric power plants and energy projects in Arizona, California, Colorado, Hawaii, Indiana, Kansas, Nevada, Pennsylvania and Mexico to serve wholesale electricity markets in the United States and Mexico. Sempra Generation also includes the operating results of Sempra Rockies Marketing, which holds firm service capacity on the Rockies Express Pipeline.
 
4.  
Sempra Pipelines & Storage develops, owns and operates, or holds interests in, natural gas and propane pipelines and natural gas storage facilities in the United States and Mexico, and companies that provide natural gas or electricity services in Argentina, Chile, Mexico and Peru. We are currently pursuing the sale of our interests in the Argentine utilities, which we discuss further in Note 4 above. Sempra Pipelines & Storage also operates a natural gas distribution utility in Alabama.

In April 2011, Sempra Pipelines & Storage increased its interests in Chile and Peru, as we discuss in Note 3.

5.  
Sempra LNG develops, owns and operates terminals in the U.S. and Mexico for the import and export of LNG, and has supply and marketing agreements to purchase and sell LNG and natural gas.

We evaluate each segment’s performance based on its contribution to Sempra Energy’s reported earnings. The Sempra Utilities operate in essentially separate service territories, under separate regulatory frameworks and rate structures set by the CPUC. The Sempra Utilities’ operations are based on rates set by the CPUC and the FERC. We describe the accounting policies of all of our segments in Note 1.
 
Sempra Generation’s sales to the DWR, under a 10-year contract that expired September 30, 2011, comprised 6 percent of our revenues in 2011, 8 percent in 2010 and 9 percent in 2009.
 
Prior to 2011, our Sempra Commodities segment contained our investment in RBS Sempra Commodities LLP (RBS Sempra Commodities), which held commodities-marketing businesses previously owned by us.  Our investment in the partnership is reported on the equity method. We and RBS, our partner in the joint venture, sold substantially all of the partnership’s businesses and assets in four separate transactions completed in July, November and December of 2010 and February of 2011. We discuss these transactions and other matters concerning the partnership in Note 4.
 
The activity in the partnership no longer meets the quantitative thresholds that require Sempra Commodities to be reported as a reportable segment under applicable GAAP, and we do not consider the remaining wind-down activities of the partnership to be of continuing significance. As a result, effective January 1, 2011, we are reporting the former Sempra Commodities segment in “All other” in the following tables and have restated prior year information to be consistent with this treatment.
 
The following tables show selected information by segment from our Consolidated Statements of Operations and Consolidated Balance Sheets. We provide information about our equity method investments by segment in Note 4. Amounts labeled as “All other” in the following tables consist primarily of parent organizations and the former commodities-marketing businesses.
 


SEGMENT INFORMATION
(Dollars in millions)
 
Years ended December 31,
 
2011 
2010 
2009 
REVENUES
 
 
 
 
 
 
 
 
 
 
 
 
  SDG&E
$
 3,373 
 34 
%
$
 3,049 
 34 
%
$
 2,916 
 36 
%
  SoCalGas
 
 3,816 
 38 
 
 
 3,822 
 42 
 
 
 3,355 
 41 
 
  Sempra Generation
 
 886 
 9 
 
 
 1,172 
 13 
 
 
 1,179 
 15 
 
  Sempra Pipelines & Storage
 
 1,443 
 14 
 
 
 350 
 4 
 
 
 465 
 6 
 
  Sempra LNG
 
 714 
 7 
 
 
 711 
 8 
 
 
 278 
 3 
 
  Adjustments and eliminations
 
 (1)
 ― 
 
 
 (5)
 ― 
 
 
 ― 
 ― 
 
  Intersegment revenues(1)
 
 (195)
 (2)
 
 
 (96)
 (1)
 
 
 (87)
 (1)
 
      Total
$
 10,036 
 100 
%
$
 9,003 
 100 
%
$
 8,106 
 100 
%
INTEREST EXPENSE
 
 
 
 
 
 
 
 
 
 
 
 
  SDG&E
$
 142 
 
 
$
 136 
 
 
$
 104 
 
 
  SoCalGas
 
 69 
 
 
 
 66 
 
 
 
 68 
 
 
  Sempra Generation
 
 13 
 
 
 
 13 
 
 
 
 12 
 
 
  Sempra Pipelines & Storage
 
 77 
 
 
 
 36 
 
 
 
 34 
 
 
  Sempra LNG
 
 42 
 
 
 
 48 
 
 
 
 24 
 
 
  All other
 
 233 
 
 
 
 244 
 
 
 
 229 
 
 
  Intercompany eliminations(2)
 
 (111)
 
 
 
 (107)
 
 
 
 (104)
 
 
      Total
$
 465 
 
 
$
 436 
 
 
$
 367 
 
 
INTEREST INCOME
 
 
 
 
 
 
 
 
 
 
 
 
  SDG&E
$
 ― 
 
 
$
 ― 
 
 
$
 1 
 
 
  SoCalGas
 
 1 
 
 
 
 1 
 
 
 
 3 
 
 
  Sempra Generation
 
 8 
 
 
 
 16 
 
 
 
 12 
 
 
  Sempra Pipelines & Storage
 
 31 
 
 
 
 15 
 
 
 
 17 
 
 
  Sempra LNG
 
 4 
 
 
 
 1 
 
 
 
 ― 
 
 
  All other
 
 ― 
 
 
 
 1 
 
 
 
 ― 
 
 
  Intercompany eliminations(2)
 
 (18)
 
 
 
 (18)
 
 
 
 (12)
 
 
      Total
$
 26 
 
 
$
 16 
 
 
$
 21 
 
 
DEPRECIATION AND AMORTIZATION
 
 
 
 
 
 
 
 
 
 
 
 
  SDG&E
$
 422 
 43 
%
$
 381 
 44 
%
$
 329 
 42 
%
  SoCalGas
 
 331 
 34 
 
 
 309 
 36 
 
 
 293 
 38 
 
  Sempra Generation
 
 70 
 7 
 
 
 65 
 7 
 
 
 58 
 8 
 
  Sempra Pipelines & Storage
 
 92 
 10 
 
 
 44 
 5 
 
 
 45 
 6 
 
  Sempra LNG
 
 51 
 5 
 
 
 51 
 6 
 
 
 35 
 4 
 
  All other
 
 12 
 1 
 
 
 17 
 2 
 
 
 15 
 2 
 
      Total
$
 978 
 100 
%
$
 867 
 100 
%
$
 775 
 100 
%
INCOME TAX EXPENSE (BENEFIT)
 
 
 
 
 
 
 
 
 
 
 
 
  SDG&E
$
 237 
 
 
$
 173 
 
 
$
 177 
 
 
  SoCalGas
 
 143 
 
 
 
 176 
 
 
 
 144 
 
 
  Sempra Generation
 
 (3)
 
 
 
 (7)
 
 
 
 108 
 
 
  Sempra Pipelines & Storage
 
 70 
 
 
 
 26 
 
 
 
 (20)
 
 
  Sempra LNG
 
 42 
 
 
 
 25 
 
 
 
 (15)
 
 
  All other
 
 (123)
 
 
 
 (291)
 
 
 
 28 
 
 
      Total
$
 366 
 
 
$
 102 
 
 
$
 422 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 



SEGMENT INFORMATION (Continued)
(Dollars in millions)
 
 
At December 31 or for the years ended December 31,
 
 
2011 
2010 
2009 
EARNINGS (LOSSES)
 
 
 
 
 
 
 
 
 
 
 
 
   SDG&E(3)
$
 431 
 32 
%
$
 369 
 50 
%
$
 344 
 31 
%
   SoCalGas(3)
 
 287 
 21 
 
 
 286 
 39 
 
 
 273 
 25 
 
   Sempra Generation
 
 137 
 10 
 
 
 103 
 14 
 
 
 169 
 15 
 
   Sempra Pipelines & Storage
 
 527 
 39 
 
 
 159 
 21 
 
 
 101 
 9 
 
   Sempra LNG
 
 99 
 7 
 
 
 68 
 9 
 
 
 16 
 1 
 
   All other
 
 (124)
 (9)
 
 
 (246)
 (33)
 
 
 216 
 19 
 
       Total
$
 1,357 
 100 
%
$
 739 
 100 
%
$
 1,119 
 100 
%
ASSETS
 
 
 
 
 
 
 
 
 
 
 
 
   SDG&E
$
 13,555 
 41 
%
$
 12,077 
 40 
%
$
 10,229 
 36 
%
   SoCalGas
 
 8,475 
 25 
 
 
 7,986 
 26 
 
 
 7,287 
 25 
 
   Sempra Generation
 
 2,285 
 7 
 
 
 2,401 
 8 
 
 
 2,049 
 7 
 
   Sempra Pipelines & Storage
 
 7,146 
 21 
 
 
 5,175 
 17 
 
 
 4,485 
 16 
 
   Sempra LNG
 
 2,411 
 7 
 
 
 2,379 
 8 
 
 
 2,277 
 8 
 
   All other
 
 553 
 2 
 
 
 1,691 
 6 
 
 
 2,775 
 10 
 
   Intersegment receivables
 
 (1,069)
 (3)
 
 
 (1,426)
 (5)
 
 
 (590)
 (2)
 
       Total
$
 33,356 
 100 
%
$
 30,283 
 100 
%
$
 28,512 
 100 
%
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
 
 
 
 
 
 
 
 
 
 
 
 
   SDG&E
$
 1,831 
 64 
%
$
 1,210 
 59 
%
$
 955 
 50 
%
   SoCalGas
 
 683 
 24 
 
 
 503 
 24 
 
 
 480 
 25 
 
   Sempra Generation
 
 267 
 9 
 
 
 135 
 7 
 
 
 38 
 2 
 
   Sempra Pipelines & Storage
 
 252 
 9 
 
 
 192 
 9 
 
 
 200 
 11 
 
   Sempra LNG
 
 11 
 1 
 
 
 18 
 1 
 
 
 235 
 12 
 
   All other
 
 5 
 ― 
 
 
 4 
 ― 
 
 
 4 
 ― 
 
   Intercompany eliminations(4)
 
 (205)
 (7)
 
 
 ― 
 ― 
 
 
 ― 
 ― 
 
       Total
$
 2,844 
 100 
%
$
 2,062 
 100 
%
$
 1,912 
 100 
%
GEOGRAPHIC INFORMATION
 
 
 
 
 
 
 
 
 
 
 
 
Long-lived assets:
 
 
 
 
 
 
 
 
 
 
 
 
   United States
$
 21,505 
 85 
%
$
 19,905 
 87 
%
$
 19,870 
 88 
%
   Mexico
 
 2,196 
 9 
 
 
 2,217 
 10 
 
 
 1,954 
 9 
 
   South America
 
 1,542 
 6 
 
 
 705 
 3 
 
 
 780 
 3 
 
      Total
$
 25,243 
 100 
%
$
 22,827 
 100 
%
$
 22,604 
 100 
%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Revenues:
 
 
 
 
 
 
 
 
 
 
 
 
   United States
$
 8,135 
 81 
%
$
 8,118 
 90 
%
$
 7,476 
 92 
%
   South America
 
 1,080 
 11 
 
 
 1 
 ― 
 
 
 1 
 ― 
 
   Mexico
 
 821 
 8 
 
 
 884 
 10 
 
 
 629 
 8 
 
      Total
$
 10,036 
 100 
%
$
 9,003 
 100 
%
$
 8,106 
 100 
%
(1)
Revenues for reportable segments include intersegment revenues of:
 
$6 million, $53 million and $47 million for 2011, $6 million, $44 million and $46 million for 2010, and $7 million, $43 million and $37 million for 2009 for SDG&E, SoCalGas and Sempra Pipelines & Storage, respectively. Revenues in 2011 also included $88 million and $1 million of intersegment revenues at Sempra LNG and Sempra Generation, respectively.
(2)
Prior year amounts have been revised to present amounts after eliminations between Parent and corporate entities.
(3)
After preferred dividends.
(4)
Amount represents elimination of intercompany sale of El Dorado power plant in 2011, as discussed in Note 14.




 

NOTE 17. QUARTERLY FINANCIAL DATA (UNAUDITED)
 


SEMPRA ENERGY
(In millions, except for per share amounts)
 
 
Quarters ended
 
 
March 31
June 30
September 30
December 31
2011 
 
 
 
 
 
 
 
 
Revenues
$
 2,434 
$
 2,422 
$
 2,576 
$
 2,604 
Expenses and other income
$
 2,092 
$
 1,836 
$
 2,188 
$
 2,199 
 
 
 
 
 
 
 
 
 
 
Net income
$
 264 
$
 502 
$
 326 
$
 315 
Earnings attributable to Sempra Energy
$
 258 
$
 511 
$
 296 
$
 292 
 
 
 
 
 
 
 
 
 
 
Basic per-share amounts(1):
 
 
 
 
 
 
 
 
    Net income
$
 1.10 
$
 2.10 
$
 1.36 
$
 1.31 
    Earnings attributable to Sempra Energy
$
 1.07 
$
 2.14 
$
 1.23 
$
 1.22 
    Weighted average common shares outstanding
 
 240.1 
 
 239.4 
 
 239.5 
 
 239.8 
 
 
 
 
 
 
 
 
 
 
Diluted per-share amounts(1):
 
 
 
 
 
 
 
 
    Net income
$
 1.09 
$
 2.09 
$
 1.35 
$
 1.30 
    Earnings attributable to Sempra Energy
$
 1.07 
$
 2.12 
$
 1.22 
$
 1.21 
    Weighted average common shares outstanding
 
 241.9 
 
 240.8 
 
 241.9 
 
 241.8 
2010 
 
 
 
 
 
 
 
 
Revenues
$
 2,534 
$
 2,008 
$
 2,116 
$
 2,345 
Expenses and other income
$
 2,395 
$
 1,771 
$
 2,017 
$
 2,034 
 
 
 
 
 
 
 
 
 
 
Net income
$
 100 
$
 205 
$
 127 
$
 301 
Earnings attributable to Sempra Energy
$
 106 
$
 222 
$
 131 
$
 280 
 
 
 
 
 
 
 
 
 
 
Basic per-share amounts(1):
 
 
 
 
 
 
 
 
    Net income
$
 0.41 
$
 0.83 
$
 0.52 
$
 1.26 
    Earnings attributable to Sempra Energy
$
 0.43 
$
 0.90 
$
 0.53 
$
 1.17 
    Weighted average common shares outstanding
 
 246.1 
 
 246.8 
 
 246.7 
 
 239.5 
 
 
 
 
 
 
 
 
 
 
Diluted per-share amounts(1):
 
 
 
 
 
 
 
 
    Net income
$
 0.40 
$
 0.82 
$
 0.51 
$
 1.24 
    Earnings attributable to Sempra Energy
$
 0.42 
$
 0.89 
$
 0.53 
$
 1.15 
    Weighted average common shares outstanding
 
 250.4 
 
 249.7 
 
 249.8 
 
 242.5 
(1)
Earnings per share are computed independently for each of the quarters and therefore may not sum to the total for the year.
 

In the second quarter of 2011, Expenses and Other Income, Net Income and Earnings Attributable to Sempra Energy were impacted by a $277 million gain (both before and after tax) resulting from the remeasurement of our equity method investments at Sempra Pipelines & Storage related to its acquisition of additional interests in Chilquinta Energía and Luz del Sur on April 6, 2011, as we discuss in Note 3. Earnings Attributable to Sempra Energy were impacted by $11 million in the third quarter of 2011 and $24 million in the fourth quarter of 2011 from higher earnings from the acquisition of the additional interests in Chilquinta Energía and Luz del Sur.
 
Revenues increased $324 million, $335 million and $350 million in the second, third and fourth quarters of 2011 compared to 2010, respectively, due to the consolidation of Chilquinta Energía and Luz del Sur beginning April 6, 2011.
 
In the first quarter of 2010, Expenses and Other Income included $159 million in litigation expense related to the agreement in principle to settle certain energy crisis litigation. The litigation expense negatively impacted Net Income and Earnings Attributable to Sempra Energy by $96 million. Also in the first quarter of 2010, Earnings Attributable to Sempra Energy were negatively impacted by a $16 million write-down of deferred tax assets as a result of the change to U.S. tax law regarding the Medicare Part D subsidy.
 
In the third quarter of 2010, Expenses and Other Income included a $305 million write-down of our investment in RBS Sempra Commodities. This write-down and a write-down of our investment in Argentina negatively impacted Net Income and Earnings Attributable to Sempra Energy by $139 million and $24 million, respectively.
 
We discuss quarterly fluctuations related to SDG&E and SoCalGas below.
 

SDG&E
(Dollars in millions)
 
Quarters ended
 
March 31
June 30
September 30
December 31
2011 
 
 
 
 
 
 
 
 
Operating revenues
$
 840 
$
 697 
$
 868 
$
 968 
Operating expenses
 
 677 
 
 584 
 
 658 
 
 699 
Operating income
$
 163 
$
 113 
$
 210 
$
 269 
 
 
 
 
 
 
 
 
 
Net income
$
 94 
$
 53 
$
 136 
$
 172 
(Earnings) losses attributable to noncontrolling interests
 
 (4)
 
 19 
 
 (21)
 
 (13)
Earnings
 
 90 
 
 72 
 
 115 
 
 159 
Dividends on preferred stock
 
 (1)
 
 (1)
 
 (2)
 
 (1)
Earnings attributable to common shares
$
 89 
$
 71 
$
 113 
$
 158 
2010 
 
 
 
 
 
 
 
 
Operating revenues
$
 742 
$
 692 
$
 811 
$
 804 
Operating expenses
 
 604 
 
 546 
 
 613 
 
 629 
Operating income
$
 138 
$
 146 
$
 198 
$
 175 
 
 
 
 
 
 
 
 
 
Net income
$
 76 
$
 55 
$
 103 
$
 124 
(Earnings) losses attributable to noncontrolling interests
 
 8 
 
 21 
 
 5 
 
 (18)
Earnings
 
 84 
 
 76 
 
 108 
 
 106 
Dividends on preferred stock
 
 (1)
 
 (1)
 
 (2)
 
 (1)
Earnings attributable to common shares
$
 83 
$
 75 
$
 106 
$
 105 
 

In the fourth quarter of 2011 compared to the same quarter in 2010, Operating Revenues, Net Income and Earnings for SDG&E were favorably impacted by $57 million, $34 million and $34 million, respectively, related to higher revenues associated with incremental wildfire insurance premiums.

Net Income and Earnings for the second, third and fourth quarters of 2011 were favorably impacted by $7 million, $10 million and $13 million, respectively, related to higher allowance for equity funds used during construction, net of changes in interest expense.


SOCALGAS
(Dollars in millions)
 
Quarters ended
 
March 31
June 30
September 30
December 31
2011 
 
 
 
 
 
 
 
 
Operating revenues
$
 1,056 
$
 876 
$
 844 
$
 1,040 
Operating expenses
 
 937 
 
 773 
 
 709 
 
 911 
Operating income
$
 119 
$
 103 
$
 135 
$
 129 
 
 
 
 
 
 
 
 
 
Net income
$
 68 
$
 60 
$
 81 
$
 79 
Dividends on preferred stock
 
 ― 
 
 (1)
 
 ― 
 
 ― 
Earnings attributable to common shares
$
 68 
$
 59 
$
 81 
$
 79 
2010 
 
 
 
 
 
 
 
 
Operating revenues
$
 1,182 
$
 834 
$
 776 
$
 1,030 
Operating expenses
 
 1,048 
 
 716 
 
 642 
 
 900 
Operating income
$
 134 
$
 118 
$
 134 
$
 130 
 
 
 
 
 
 
 
 
 
Net income
$
 65 
$
 70 
$
 78 
$
 74 
Dividends on preferred stock
 
 ― 
 
 (1)
 
 ― 
 
 ― 
Earnings attributable to common shares
$
 65 
$
 69 
$
 78 
$
 74 

In the first quarter of 2011, SoCalGas’ Operating Revenues decreased by $176 million due to lower natural gas prices compared to the first quarter of 2010.
 
Compared to the first quarter of 2010, Operating Revenues and Operating Expenses were lower in the remaining quarters of 2010 due to lower natural gas prices and volumes.
 

 
NOTE 18. SUBSEQUENT EVENT
 

Effective January 1, 2012, in connection with several key executive appointments made in September 2011, management realigned some of the company’s major operating units to better fit its strategic direction and to enhance the management and integration of our assets. This realignment will result in a change in reportable segments in 2012, primarily to regroup the Sempra Global business units under two operating units, Sempra U.S. Gas & Power and Sempra International.
 



GLOSSARY
 
 
 
 
 
 
 
 
 
 
 
2010 Tax Act
Tax Relief, Unemployment Insurance Reauthorization, and Job Creation Act of 2010
 
EPA
Environmental Protection Agency
AB 32
California Assembly Bill 32
 
EPS
Earnings per common share
AFUDC
Allowance for funds used during construction
 
ERRP
Early Retiree Reinsurance Program
AMI
Advanced Metering Infrastructure
 
ESOP
Employee stock ownership plan
AOCI
Accumulated other comprehensive income (loss)
 
FERC
Federal Energy Regulatory Commission
AROs
Asset retirement obligations
 
Fowler Ridge 2
Fowler Ridge 2 Wind Farm
ASC
Accounting Standards Codification
 
GAAP
Accounting Principles Generally Accepted in the United States of America
ASU
Accounting Standards Update
 
Gazprom
Gazprom Marketing & Trading Mexico
Bay Gas
Bay Gas Storage, LLC
 
GCIM
Gas Cost Incentive Mechanism
Bcf
Billion cubic feet
 
GHG
Greenhouse Gas
Black-Scholes Model
Black-Scholes option-pricing model
 
GRC
General Rate Case
BLM
Bureau of Land Management
 
IBLA
Interior Board of Land Appeals
Cal Fire
California Department of Forestry and Fire Protection
 
ICSID
International Center for the Settlement of Investment Disputes
CARB
California Air Resources Board
 
IFRS
International Financial Reporting Standards
CBD
Center for Biological Diversity/Sierra Club
 
IOUs
Investor-owned Utilities
CEC
California Energy Commission
 
ISFSI
Independent spent fuel storage installation
Cedar Creek 2
Cedar Creek 2 Wind Farm
 
ISO
Independent System Operator
CEQA
California Environmental Quality Act
 
JP Morgan
J.P. Morgan Chase & Co.
CFE
Comisión Federal de Electricidad (Federal Electricity Commission)
 
J.P. Morgan Ventures
J.P. Morgan Ventures Energy Corporation
CFTC
U.S. Commodity Futures Trading Commission
 
KMP
Kinder Morgan Energy Partners, L.P.
Chilquinta Energía
Chilquinta Energía S.A.
 
kV
Kilovolt
CMS 2
Copper Mountain Solar 2
 
Liberty
Liberty Gas Storage, LLC
CNE
Comisión Nacional de Energía (National Energy Commission)
 
LIBOR
London interbank offered rate
Conoco
ConocoPhillips
 
LIFO
Last-in first-out inventory
Cox
Cox Communications
 
LNG
Liquefied natural gas
CPSD
Consumer Protection and Safety Division
 
Luz del Sur
Luz del Sur S.A.A.
CPUC
California Public Utilities Commission
 
MAOP
Maximum allowable operating pressure
CRE
Comisión Reguladora de Energía (Energy Regulatory Commission)
 
MBFC
Mississippi Business Finance Corporation
CRRs
Congestion revenue rights
 
Mcf
Thousand cubic feet
DOE
U.S. Department of Energy
 
MHI
Mitsubishi Heavy Industries
DRA
Division of Ratepayer Advocates
 
MICAM
Market Indexed Capital Adjustment Mechanism
DWR
California Department of Water Resources
 
Midstream Services
Sempra Midstream Services
EBITDA
Earnings before interest, taxes, depreciation and amortization
 
Mississippi Hub
Mississippi Hub, LLC
Ecogas
Ecogas Mexico, S de RL de CV
 
MMBtu
Million British Thermal Units (of natural gas)
Edison
Southern California Edison Company
 
MMcf
Million cubic feet
Elk Hills
Elk Hills Power
 
Mobile Gas
Mobile Gas Service Corporation



GLOSSARY (CONTINUED)
 
 
 
 
 
 
 
 
 
 
 
MSCI
Morgan Stanley Capital International
 
ROE
Return on equity
MSCI EAFE Index
MSCI Index for equity market performance in Europe, Australasia and Far East
 
ROR
Rate of return
MW
Megawatt
 
RPS
Renewables Portfolio Standard
MWh
Megawatt hour
 
RSAs
Restricted stock awards
Noble Group
Noble Group Ltd.
 
RSUs
Restricted stock units
NOLs
Net operating losses
 
SDG&E
San Diego Gas & Electric Company
NRC
Nuclear Regulatory Commission
 
Sempra Utilities
San Diego Gas & Electric Company and Southern California Gas Company
NTSB
National Transportation Safety Board
 
SFP
Secondary Financial Protection
OCI
Other comprehensive income
 
Shell
Shell México Gas Natural
OMEC
Otay Mesa Energy Center
 
SoCalGas
Southern California Gas Company
OMEC LLC
Otay Mesa Energy Center LLC
 
SONGS
San Onofre Nuclear Generating Station
OSINERGMIN
Organismo Supervisor de la Inversión en Energía y Minería (Energy and Mining Investment Supervisory Body)
 
SPPR Group
Southwest Public Power Resources Group
Otay Mesa VIE
Otay Mesa Energy Center LLC
 
S&P
Standard & Poor’s
OTC
Over-the-counter
 
Tangguh PSC
Tangguh PSC Contractors
PBOP
Other postretirement benefit plans
 
Tecnored
Tecnored S.A.
PBOP plan trusts
Postretirement benefit plan trusts
 
Tecsur
Tecsur S.A.
PCBs
Polychlorinated biphenyls
 
The Committee
Pension and Benefits Investment Committee
PE
Pacific Enterprises
 
The Plan
Sempra Energy 2008 Long Term Incentive Plan for EnergySouth, Inc. Employees and Other Eligible Individuals
PEMEX
Petroleos Mexicanos (Mexican state-owned oil company)
 
The Prior Plan
2008 Incentive Plan of EnergySouth, Inc.
PG&E
Pacific Gas and Electric Company
 
Trust
ESOP trust
PPACA
Patient Protection and Affordable Care Act
 
TURN
The Utility Reform Network
PRP
Potentially Responsible Party
 
UCAN
Utility Consumers’ Action Network
PSEP
Pipeline Safety Enhancement Plan
 
USFS
United States Forest Service
RBS
The Royal Bank of Scotland plc
 
VaR
Value at Risk
RBS Sempra Commodities
RBS Sempra Commodities LLP
 
VEBA
Voluntary Employee Beneficiary Association
RDS
Retiree Drug Subsidy
 
VIE
Variable Interest Entity
REX
Rockies Express Pipeline
 
VNR
Valor Nuevo de Reemplazo (New replacement value)
Rockies Express
Rockies Express Pipeline LLC
 
Williams
Williams Midstream Natural Gas Liquids, Inc.
 
 
 
 
 



Exhibit 21.1

Exhibit 21.1

Sempra Energy

Schedule of Significant Subsidiaries

at December 31, 2011



Subsidiary

State of Incorporation or Other Jurisdiction

AEI Asosiacion en Participacion

Peru

Enova Corporation

California

Pacific Enterprises

California

Pacific Enterprises International

California

San Diego Gas & Electric Company

California

Sempra Chile S.A.

Chile

Sempra Commodities, Inc.

Delaware

Sempra Energy International

California

Sempra Energy Holdings III B.V.

Netherlands

Sempra Energy Holdings VIII B.V.

Netherlands

Sempra Energy International Holdings N.V.

Netherlands

Sempra Global

Delaware

Southern California Gas Company

California











Exhibit 23.2

Exhibit 23.2

 

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

 

We consent to the incorporation by reference in Registration Statement No. 333-176855 on Form S-3 of Sempra Energy and Registration Statement Nos. 333-56161, 333-50806, 333-49732, 333-121073, 333-128441, 333-151184, 333-155191, 333-129774 and 333-157567 on Form S-8 of Sempra Energy of our report dated February 22, 2010 (which report expresses an unqualified opinion and includes an explanatory paragraph relating to an agreement to sell certain businesses), relating to the consolidated statement of financial condition of RBS Sempra Commodities LLP and subsidiaries as of December 31, 2009, and the related consolidated statements of income, cash flows, and changes in members’ capital, for the year ended December 31, 2009 and the period from April 1, 2008 (Date of Commencement) to December 31, 2008, which report is incorporated by reference in this Annual Report on Form 10-K of Sempra Energy for the year ended December 31, 2011.

 

/s/ Deloitte & Touche LLP

 

New York, New York

February 28, 2012




Sempra Energy Ex 31.1

EXHIBIT 31.1

CERTIFICATION


I, Debra L. Reed, certify that:


1.

I have reviewed this report on Form 10-K of Sempra Energy;


2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13(a)-15(f) and 15d-15(f)) for the registrant and have:


a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and


d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and


5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):


a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and


b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.



February 28, 2012


/S/  Debra L. Reed

Debra L. Reed  

Chief Executive Officer




Sempra Energy Ex 31.2

EXHIBIT 31.2

CERTIFICATION


I, Joseph A. Householder, certify that:


1.

I have reviewed this report on Form 10-K of Sempra Energy;


2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13(a)-15(f) and 15d-15(f)) for the registrant and have:


a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and


d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and


5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):


a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and


b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.



February 28, 2012


/S/  Joseph A. Householder

Joseph A. Householder

Chief Financial Officer




SDG&E Ex 31.3

EXHIBIT 31.3

CERTIFICATION


I, Jessie J. Knight, Jr., certify that:


1.

I have reviewed this report on Form 10-K of San Diego Gas & Electric Company;


2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13(a)-15(f) and 15d-15(f)) for the registrant and have:


a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and


d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and


5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):


a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and


b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.


February 28, 2012


/S/  Jessie J. Knight, Jr.

Jessie J. Knight, Jr.

Chief Executive Officer




SDG&E Ex 31.4

EXHIBIT 31.4

CERTIFICATION


I, Robert M. Schlax, certify that:


1.

I have reviewed this report on Form 10-K of San Diego Gas & Electric Company;


2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13(a)-15(f) and 15d-15(f)) for the registrant and have:


a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and


d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and


5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):


a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and


b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.


February 28, 2012


/S/  Robert M. Schlax

Robert M. Schlax

Chief Financial Officer




SCG Ex 31.5

EXHIBIT 31.5

CERTIFICATION


I, Michael W. Allman, certify that:


1.

I have reviewed this report on Form 10-K of Southern California Gas Company;


2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13(a)-15(f) and 15d-15(f)) for the registrant and have:


a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and


d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and


5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):


a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and


b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.


February 28, 2012


/S/  Michael W. Allman

Michael W. Allman

Chief Executive Officer




SCG Ex 31.6

EXHIBIT 31.6

CERTIFICATION


I, Robert M. Schlax, certify that:


1.

I have reviewed this report on Form 10-K of Southern California Gas Company;


2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13(a)-15(f) and 15d-15(f)) for the registrant and have:


a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and


d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and


5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):


a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and


b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.


February 28, 2012


/S/  Robert M. Schlax

Robert M. Schlax

Chief Financial Officer




Sempra Energy Ex 32.1

Exhibit 32.1



Statement of Chief Executive Officer


Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned Chief Executive Officer of Sempra Energy (the "Company") certifies that:


(i)

the Annual Report on Form 10-K of the Company filed with the Securities and Exchange Commission for the year ended December 31, 2011 (the "Annual Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and


(ii)

the information contained in the Annual Report fairly presents, in all material respects, the financial condition and results of operations of the Company.




February 28, 2012

                                            

/S/  Debra L. Reed

Debra L. Reed

Chief Executive Officer





Sempra Energy Ex 32.2

Exhibit 32.2


Statement of Chief Financial Officer


Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned Chief Financial Officer of Sempra Energy (the "Company") certifies that:


(i)

the Annual Report on Form 10-K of the Company filed with the Securities and Exchange Commission for the year ended December 31, 2011 (the "Annual Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and


(ii)

the information contained in the Annual Report fairly presents, in all material respects, the financial condition and results of operations of the Company.




February 28, 2012

                                          

/S/  Joseph A. Householder

Joseph A. Householder

Chief Financial Officer




SDG&E Ex 32.3

Exhibit 32.3


Statement of Chief Executive Officer


Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned Chief Executive Officer of San Diego Gas & Electric Company (the "Company") certifies that:


(i)

the Annual Report on Form 10-K of the Company filed with the Securities and Exchange Commission for the year ended December 31, 2011 (the "Annual Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and


(ii)

the information contained in the Annual Report fairly presents, in all material respects, the financial condition and results of operations of the Company.




February 28, 2012

                                             

/S/  Jessie J. Knight, Jr.

Jessie J. Knight, Jr.

Chief Executive Officer






SDG&E Ex 32.4

Exhibit 32.4


Statement of Chief Financial Officer


Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned Chief Financial Officer of San Diego Gas & Electric Company (the "Company") certifies that:


(i)

the Annual Report on Form 10-K of the Company filed with the Securities and Exchange Commission for the year ended December 31, 2011 (the "Annual Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and


(ii)

the information contained in the Annual Report fairly presents, in all material respects, the financial condition and results of operations of the Company.




February 28, 2012

                                                

/S/  Robert M. Schlax

Robert M. Schlax

Chief Financial Officer




SCG Ex 32.5

Exhibit 32.5


Statement of Chief Executive Officer


Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned Chief Executive Officer of Southern California Gas Company (the "Company") certifies that:


(i)

the Annual Report on Form 10-K of the Company filed with the Securities and Exchange Commission for the year ended December 31, 2011 (the "Annual Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and


(ii)

the information contained in the Annual Report fairly presents, in all material respects, the financial condition and results of operations of the Company.




February 28, 2012

                                                

/S/  Michael W. Allman

Michael W. Allman

Chief Executive Officer





SCG Ex 32.6

Exhibit 32.6


Statement of Chief Financial Officer


Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned Chief Financial Officer of Southern California Gas Company (the "Company") certifies that:


(i)

the Annual Report on Form 10-K of the Company filed with the Securities and Exchange Commission for the year ended December 31, 2011 (the "Annual Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and


(ii)

the information contained in the Annual Report fairly presents, in all material respects, the financial condition and results of operations of the Company.




February 28, 2012


                                               

/S/  Robert M. Schlax

Robert M. Schlax

Chief Financial Officer