SEC Filing | Sempra

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, 1998 -------------------- OR [ ] Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 for the transition period from to - ------ ------- SOUTHERN CALIFORNIA GAS COMPANY - ------------------------------------------------------------------- (Exact name of registrant as specified in its charter) CALIFORNIA 1-1402 95-1240705 - ------------------------------------------------------------------- (State of incorporation (Commission (I.R.S. Employer or organization) File Number) Identification No. 555 WEST FIFTH STREET, LOS ANGELES, CALIFORNIA 90013 - ------------------------------------------------------------------- (Address of principal executive offices) (Zip Code) Registrant's telephone number, including area code (213)244-1200 -------------- SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT: Name of each exchange Title of each class on which registered - ------------------- --------------------- Preferred Stock Pacific First Mortgage Bonds: Series Y, due 2021 Series Z, due 2002 Series BB, due 2023 New York Series DD, due 2023 Series EE, due 2025 Series FF, due 2003 SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT: None Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months and (2) has been subject to such filing requirements for the past 90 days. 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 registrant's 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. [ ] Exhibit Index on page 53. Glossary on page 56. Aggregate market value of the voting preferred stock held by non- affiliates of the registrant as of March 26, 1999 was $19.9 million. Registrant's common stock outstanding as of March 26, 1999 was wholly owned by Pacific Enterprises. DOCUMENTS INCORPORATED BY REFERENCE: Portions of the Information Statement prepared for the May 1999 annual meeting of shareholders are incorporated by reference into Part III. TABLE OF CONTENTS PART I Item 1. Business . . . . . . . . . . . . . . . . . . . . . . . 3 Item 2. Properties . . . . . . . . . . . . . . . . . . . . . . 11 Item 3. Legal Proceedings. . . . . . . . . . . . . . . . . . . 11 Item 4. Submission of Matters to a Vote of Security Holders. . 11 Executive Officers of the Registrant . . . . . . . . . 12 PART II Item 5. Market for Registrant's Common Equity and Related Stockholder Matters . . . . . . . . . . . . . . . . 12 Item 6. Selected Financial Data. . . . . . . . . . . . . . . . 13 Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations . . . . . . . . 13 Item 7A. Quantitative and Qualitative Disclosures About Market Risk . . . . . . . . . . . . . . . . . 26 Item 8. Financial Statements and Supplementary Data. . . . . . 27 Item 9. Changes In and Disagreements with Accountants on Accounting and Financial Disclosure . . . . . . . . 50 PART III Item 10. Directors and Executive Officers of the Registrant . . 50 Item 11. Executive Compensation . . . . . . . . . . . . . . . . 50 Item 12. Security Ownership of Certain Beneficial Owners and Management. . . . . . . . . . . . . . . . . . . 51 Item 13. Certain Relationships and Related Transactions . . . . 51 PART IV Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K . . . . . . . . . . . . . . . . . . . . 51 Signatures. . . . . . . . . . . . . . . . . . . . . . . . . . . 52 Exhibit Index . . . . . . . . . . . . . . . . . . . . . . . . . 53 Glossary. . . . . . . . . . . . . . . . . . . . . . . . . . . . 56 This report includes forward-looking statements within the definition of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. The words "estimates," "believes," "expects," "anticipates," "plans" and "intends," variations of such words, and similar expressions, are intended to identify forward-looking statements that involve risks and uncertainties which could cause actual results to differ materially from those anticipated. These statements are necessarily based upon various assumptions involving judgments with respect to the future including, among others, local, regional, national and international economic, competitive, political and regulatory conditions and developments, technological developments, capital market conditions, inflation rates, interest rates, energy markets, weather conditions, business and regulatory or legal decisions, the pace of deregulation of retail natural gas and electricity industries, the timing and success of business development efforts, and other uncertainties, all of which are difficult to predict and many of which are beyond the control of the Company. Accordingly, while the Company believes that the assumptions are reasonable, there can be no assurance that they will approximate actual experience, or that the expectations will be realized. Readers are urged to carefully review and consider the risks, uncertainties and other factors which affect the Company's business described in this annual report and other reports filed by the Company from time to time with the Securities and Exchange Commission. PART I ITEM 1. BUSINESS DESCRIPTION OF BUSINESS Southern California Gas Company (SoCalGas or the Company) is the nation's largest natural gas distribution utility, serving 4.8 million meters throughout most of southern California and part of central California. SoCalGas is the principal subsidiary of Pacific Enterprises (PE). Effective June 26, 1998, PE and Enova Corporation (Enova) combined to form Sempra Energy, a California-based Fortune 500 energy-services company (PE/Enova Business Combination). San Diego Gas & Electric Company (SDG&E), an operating public utility providing electric and natural gas services to San Diego County and southern Orange County, is the principal subsidiary of Enova. Further discussion of SoCalGas and the PE/Enova Business Combination are included in "Management's Discussion and Analysis of Financial Condition and Results of Operations" and in Note 1 of the "Notes to Consolidated Financial Statements," herein. GOVERNMENT REGULATION Local Regulation SoCalGas has gas franchises with the 236 legal jurisdictions in its service territory. These franchises allow SoCalGas to locate facilities for the transmission and distribution of natural gas in the streets and other public places. Most of the franchises do not have fixed terms and continue indefinitely. The range of expiration dates for the franchises with definite terms is 2003 to 2041. State Regulation The California Public Utilities Commission (CPUC) regulates SoCalGas' rates and conditions of service, sales of securities, rate of return, rates of depreciation, uniform systems of accounts, examination of records, and long-term resource procurement. The CPUC also conducts various reviews of utility performance and conducts investigations into various matters, such as deregulation, competition and the environment, to determine its future policies. Federal Regulation The Federal Energy Regulatory Commission (FERC) regulates the interstate sale and transportation of natural gas, the uniform systems of accounts and rates of depreciation. Licenses and Permits SoCalGas obtains a number of permits, authorizations and licenses in connection with the transmission and distribution of natural gas. They require periodic renewal, which results in continuing regulation by the granting agency. Other regulatory matters are described throughout this report. SOURCES OF REVENUE (In Millions of Dollars) 1998 1997 1996 - ------------------------------------------------------------------- Revenue by type of customer: Gas Sales, Transportation & Exchange- Residential $ 1,987 $ 1,736 $ 1,613 Commercial/Industrial 727 757 709 Utility Electric Generation 66 76 70 Wholesale 66 67 70 --------- --------- ---------- 2,846 2,636 2,462 Balancing and Other (419) 5 (40) --------- --------- ---------- Total Gas Revenues $ 2,427 $ 2,641 $ 2,422 ========= ========= ========== Industry segment information is contained in "Management's Discussion and Analysis of Financial Condition and Results of Operations" and in Note 12 of the "Notes to Consolidated Financial Statements" herein. NATURAL GAS OPERATIONS UTILITY SERVICES SoCalGas distributes natural gas throughout a 23,000-square-mile service territory with a population of approximately 17.6 million people. Its service territory includes most of southern California and part of central California. The Company offers two basic utility services, sale of natural gas and transportation of natural gas, through two business units. One business unit focuses on core distribution customers and the other on large volume gas transportation customers. Natural gas service is also provided on a wholesale basis to the distribution systems of the City of Long Beach, affiliated company SDG&E and Southwest Gas Corporation. Supplies of Natural Gas The Company buys natural gas under several short-term and long-term contracts. Short-term purchases are based on monthly-spot-market prices. The Company has pipeline capacity contracts with pipeline companies that expire at various dates through 2006. Most of the natural gas purchased and delivered by the Company is produced outside of California. These supplies are delivered to the Company's intrastate transmission system by interstate pipeline companies, primarily El Paso Natural Gas Company and Transwestern Natural Gas Company. These interstate companies provide transportation services for supplies purchased from other sources by the Company or its transportation customers. The rates that interstate pipeline companies may charge for natural gas and transportation services are regulated by the FERC. Existing pipeline capacity into California exceeds current demand by over 1 billion cubic feet (bcf) per day. The implications of this excess are described in "Management's Discussion and Analysis of Financial Condition and Results of Operations" herein. The following table shows the sources of natural gas deliveries from 1994 through 1998.

* Fixed charges primarily include pipeline demand charges, take or pay settlement costs and other direct billed amounts allocated over the quantities delivered by the interstate pipelines serving SoCalGas. ** The average commodity cost of natural gas purchased excludes fixed charges. Market sensitive natural gas supplies (supplies purchased on the spot market as well as under longer-term contracts ranging from one month to ten years based on spot prices) accounted for 72 percent of total natural gas volumes purchased by the Company during 1998, as compared with 70 percent and 68 percent during 1997 and 1996, respectively. These supplies were generally purchased at prices significantly below those of long-term sources of supply. During 1998, the Company delivered 962 bcf of natural gas through its system. Approximately 66 percent of these deliveries were customer-owned natural gas for which the Company provided transportation services. The balance of natural gas deliveries was gas purchased by the Company and resold to customers. The Company estimates that sufficient natural gas supplies will be available to meet the requirements of its customers for the next several years. Customers For regulatory purposes, customers are separated into core and noncore customers. Core customers are primarily residential and small commercial and industrial customers, without alternative fuel capability. There are approximately 4.8 million core customers (4.6 million residential and 200,000 small commercial and industrial). Noncore customers consist primarily of utility electric generation (UEG), wholesale, and large commercial and industrial customers, and total approximately 1,600. Most core customers purchase natural gas directly from the Company. Core aggregate transportation customers are permitted to aggregate their natural gas requirement and, up to a CPUC-imposed limit of 10 percent of the Company's core market, to purchase natural gas directly from brokers or producers. The Company continues to be obligated to purchase reliable supplies of natural gas to serve the requirements of its core customers. However, the only natural gas supplies that the Company may offer for sale to noncore customers are the same supplies that it purchases for its core customers. Noncore customers have the option of purchasing natural gas either from the Company or from other sources, such as brokers or producers, for delivery through the Company's transmission and distribution system. Most noncore customers procure their own natural gas supply. For 1998, approximately 87 percent of the CPUC-authorized natural gas margin was allocated to the core customers, with 13 percent allocated to the noncore customers. Although revenue from transportation throughput is less than for natural gas sales, the Company generally earns the same margin whether the Company buys the gas and sells it to the customer or transports natural gas already owned by the customer. The Company also provides natural gas storage services for noncore and off-system customers on a bid and negotiated contract basis. The storage service program provides opportunities for customers to store natural gas on an "as available" basis, usually during the summer to reduce winter purchases when natural gas costs are generally higher. As of December 31, 1998, the Company stored approximately 26 bcf of customer-owned gas. Demand for Natural Gas Natural gas is a principal energy source for residential, commercial, industrial and UEG customers. Natural gas competes with electricity for residential and commercial cooking, water heating, space heating and clothes drying, and with other fuels for large industrial, commercial and UEG uses. Growth in the natural gas markets is largely dependent upon the health and expansion of the southern California economy. The Company added approximately 46,000 new meters in 1998. This represents a growth rate of approximately 0.9 percent. The Company expects its growth for 1999 will continue at about the 1998 level. During 1998, 97 percent of residential energy customers in the Company's service area used natural gas for water heating, 94 percent for space heating, 78 percent for cooking and 72 percent for clothes drying. Demand for natural gas by noncore customers is very sensitive to the price of alternative competitive fuels. Although the number of noncore customers in 1998 was only 1,600, it accounted for 13 percent of the authorized natural gas revenues and 62 percent of total natural gas volumes. External factors such as weather, electric deregulation, the increased use of hydro-electric power, competing pipeline bypass and general economic conditions can result in significant shifts in this market. Natural gas demand for big UEG customers is also greatly affected by the price and availability of electric power generated in other areas and purchased by the Company's UEG customers. Natural gas demand in 1998 for UEG customer use decreased as a result of decreased demand for electricity. UEG customer demand increased in 1997 as a result of higher demand for electricity and less availability of hydro- electricity. As a result of electric industry restructuring, natural gas demand for electric generation within southern California competes with electric power generated throughout the western United States. Effective March 31, 1998, California consumers were given the option of selecting their electric energy provider from a variety of local and out-of-state producers. Although the electric industry restructuring has no direct impact on the Company's natural gas operations, future volumes of natural gas transported for UEG customers may be adversely affected to the extent that regulatory changes divert electricity from the Company's service area. Other Additional information concerning customer demand and other aspects of natural gas operations is provided under "Management's Discussion and Analysis of Financial Condition and Results of Operations" and in Notes 10 and 11 of the "Notes to Consolidated Financial Statements" herein. RATES AND REGULATION SoCalGas is regulated by the CPUC, which consists of five commissioners appointed by the Governor of California for staggered six-year terms. Two of the five commissioner positions are currently vacant. It is the responsibility of the CPUC to determine that utilities operate within the best interests of their customers. The regulatory structure is complex and has a substantial impact on SoCalGas' profitability. The natural gas industry is currently undergoing transitions to competition (see below). Natural Gas Industry Restructuring The natural gas industry experienced an initial phase of restructuring during the 1980s by deregulating natural gas sales to noncore customers. In January 1998, the CPUC released a staff report initiating a project to assess the current market and regulatory framework for California's natural gas industry. The general goals of the plan are to consider reforms to the current regulatory framework emphasizing market-oriented policies benefiting California natural gas customers. Additional information on natural gas industry restructuring is discussed in "Management's Discussion and Analysis of Financial Condition and Results of Operations" and in Note 11 of the "Notes to Consolidated Financial Statements" herein. Balancing Accounts In general, earnings fluctuations from changes in the costs of natural gas and consumption levels for the majority of natural gas are eliminated by balancing accounts authorized by the CPUC. Additional information on balancing accounts is discussed in "Management's Discussion and Analysis of Financial Condition and Results of Operations" and in Note 2 of the "Notes to Consolidated Financial Statements" herein. Performance-Based Regulation (PBR) To promote efficient operations and improved productivity and to move away from reasonableness reviews and disallowances, the CPUC has been directing utilities to use PBR. PBR has replaced the general rate case and certain other regulatory proceedings for SoCalGas. Under PBR, regulators require future income potential to be tied to achieving or exceeding specific performance and productivity measures, as well as cost reductions, rather than relying solely on expanding utility rate base in a market where a utility already has a highly developed infrastructure. Additional information on PBR is discussed in "Management's Discussion and Analysis of Financial Condition and Results of Operations" and in Note 11 of the "Notes to Consolidated Financial Statements" herein. Biennial Cost Allocation Proceeding (BCAP) Rates to recover the changes in natural gas fuel costs and changes in the cost of natural gas transportation services are determined in the BCAP. The BCAP adjusts rates to reflect variances in core customer demand from estimates previously used in establishing core customer rates. The mechanism substantially eliminates the effect on core income of variances in core market demand and natural gas costs subject to the limitations of the Gas Cost Incentive Mechanism (GCIM) discussed below. The BCAP will continue under PBR. Additional information on the BCAP is discussed in "Management's Discussion and Analysis of Financial Condition and Results of Operations" and in Note 11 of the "Notes to Consolidated Financial Statements" herein. Gas Cost Incentive Mechanism (GCIM) The GCIM is a process SoCalGas uses to evaluate its natural gas purchases, substantially replacing the previous process of reasonableness reviews. Additional information on the GCIM is discussed in "Management's Discussion and Analysis of Financial Condition and Results of Operations" and in Note 11 of the "Notes to Consolidated Financial Statements" herein. Affiliate Transactions In December 1997, the CPUC adopted rules establishing uniform standards of conduct governing the manner in which California investor-owned utilities conduct business with their affiliates. The objective of these rules is to ensure that the utilities' energy affiliates do not gain an unfair advantage over other competitors in the marketplace and that utility customers do not subsidize affiliate activities. Additional information on affiliate transactions is discussed in "Management's Discussion and Analysis of Financial Condition and Results of Operations" and in Note 11 of the "Notes to Consolidated Financial Statements" herein. Cost of Capital Under PBR, annual Cost of Capital proceedings have been replaced by an automatic adjustment mechanism if changes in certain indices exceed established tolerances. For 1999, SoCalGas is authorized to earn a rate of return on rate base of 9.49 percent and a rate of return on common equity of 11.6 percent, the same as in 1998, unless interest-rate changes are large enough to trigger an automatic adjustment. Additional information on the utilities' cost of capital is discussed in "Management's Discussion and Analysis of Financial Condition and Results of Operations" and in Note 11 of the "Notes to Consolidated Financial Statements" herein. ENVIRONMENTAL MATTERS Discussions about environmental issues affecting SoCalGas, including hazardous substances, are included in "Management's Discussion and Analysis of Financial Condition and Results of Operations" herein. The following should be read in conjunction with those discussions. Hazardous Substances The utility lawfully disposed of wastes at facilities owned and operated by other entities. Operations at these facilities may result in actual or threatened risks to the environment or public health. Under California law, redevelopment agencies are authorized to require landowners to cleanup property within their jurisdiction or, where the landowner or operator of such a facility fails to complete any corrective action required, applicable environmental laws may impose an obligation to undertake corrective actions on the utilities and others who disposed of hazardous wastes at the facility. SoCalGas has been named as a potential responsible party (PRP) for two landfill sites and two industrial waste disposal sites, as described below. The Casmalia former waste disposal site operated as a Class I waste disposal site which was composed of 6 landfills, 58 surface impoundments, 11 disposal wells, 7 disposal trenches, 2 treatment systems and one former pre-Resource Conservation and Recovery Act drum burial area. The utility has estimated the costs of remediation at Casmalia to be $0.7 million. In 1998, SoCalGas completed work efforts of $82,000. Remedial actions and negotiations with other PRPs and the United States Environmental Protection Agency (EPA) have been continuing since March 1993. SoCalGas is currently negotiating a final remedy with the EPA for Operating Industries, Inc. (OII), a former landfill for both household and industrial wastes. The total costs for remediation of OII are estimated at $3 million, of which $0.6 million was completed during 1998. Remedial actions and negotiations have been in progress since June 1986. In the early 1990s, SoCalGas was notified of hazards at two former industrial waste treatment facilities, Industrial Waste Processing (Industrial) and Cal Compact (Compact), where SoCalGas had disposed of wastes. A feasibility study and remedial investigation have been submitted and accepted by the EPA for Industrial. The total cost estimate for remediation of Industrial is $300,000, of which $4,000 of remedial action was completed in 1998. The nature and extent for remediation of the Compact site indicates an estimated cost of $120,000. During 1998, the utility completed remedial efforts of this site at a cost of $50,000 and is involved in ongoing negotiations with the California Department of Toxic Substances Control. At December 31, 1998, the utility's estimated remaining investigation and remediation liability related to hazardous waste sites not detailed above was $68 million, of which 90 percent is authorized to be recovered through the Hazardous Waste Collaborative mechanism. SoCalGas believes that any costs not ultimately recovered through rates, insurance or other means, upon giving effect to previously established liabilities, will not have a material adverse effect on the Company's consolidated results of operations or financial position. Estimated liabilities for environmental remediation are recorded when amounts are probable and estimable. Amounts authorized to be recovered in rates under the Hazardous Waste Collaborative mechanism are recorded as a regulatory asset. Possible recoveries of environmental remediation liabilities from third parties are not deducted from the liability. OTHER Year 2000 A discussion of the Company's plans to prepare its computer systems and applications for the year 2000 and beyond is included in "Management's Discussion and Analysis of Financial Condition and Results of Operations" herein. Research, Development and Demonstration (RD&D) The SoCalGas RD&D portfolio is focused in five major areas: Operations, Utilization Systems, Power Generation, Public Interest and Transportation. Each of these activities provides benefits to customers and society by providing more cost-effective, efficient natural gas equipment with lower emissions, increased safety and reduced environmental mitigation and other utility operating costs. The CPUC has authorized SoCalGas to recover its operating cost associated with RD&D. An annual average of $7.7 million has been spent for the last three years. Employees of Registrant As of December 31, 1998 SoCalGas had 6,148 employees, compared to 6,615 at December 31, 1997. This decrease is related to synergies resulting from the PE/Enova Business Combination and the shifting of certain functions to Sempra Energy. Field, technical and most clerical employees of SoCalGas are represented by the Utility Workers' Union of America or the International Chemical Workers' Council. The collective bargaining agreement on wages, hours and working conditions remains in effect through March 31, 2000. ITEM 2. PROPERTIES Natural Gas Properties At December 31, 1998, SoCalGas owned 2,857 miles of transmission and storage pipeline, 44,097 miles of distribution pipeline and 43,825 miles of service piping. It also owned 10 transmission compressor stations and 6 underground storage reservoirs (with a combined working storage capacity of approximately 116 Bcf). Other Properties Southern California Gas Tower, a wholly owned subsidiary of SoCalGas, has a 15-percent limited partnership interest in a 52- story office building in downtown Los Angeles. SoCalGas leases approximately half of the building through the year 2011. The lease has six separate five-year renewal options. The Company owns or leases other offices, operating and maintenance centers, shops, service facilities, and certain equipment necessary in the conduct of business. ITEM 3. LEGAL PROCEEDINGS Except for the matters referred to in the financial statements in Item 8 or referred to elsewhere in this Annual Report, neither the Company nor any of its affiliates is a party to, nor is its property the subject of, any material pending legal proceedings other than routine litigation incidental to its businesses. ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS None. ITEM 4. EXECUTIVE OFFICERS OF THE REGISTRANT Name Age* Positions - ------------------------------------------------------------------- Warren I. Mitchell 61 Chairman and President Lee M. Stewart 53 Senior Vice President and Corporate Secretary; President-Energy Transportation Services Debra L. Reed 42 Senior Vice President and Chief Financial Officer; President-Energy Distribution Services Richard M. Morrow 49 Vice President Roy M. Rawlings 54 Vice President Anne S. Smith 45 Vice President George E. Strang 59 Vice President * As of December 31, 1998 Each Executive Officer has been an officer of SoCalGas for more than five years. PART II ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS All of the issued and outstanding common stock of SoCalGas is owned by PE, a wholly owned subsidiary of Sempra Energy. The information required by Item 5 concerning dividends declared is included in the "Statements of Consolidated Changes in Shareholders' Equity" set forth in Item 8 of this Annual Report herein. Dividend Restrictions The CPUC regulates SoCalGas' capital structure, limiting the dividends it may pay. At December 31, 1998, $233 million of SoCalGas' retained earnings was available for future dividends. ITEM 6. SELECTED FINANCIAL DATA (Dollars in millions)

Gas Sales, Transportation & Exchange (Dollars in millions, volumes in billion cubic feet)

Although the revenues from transportation throughput are less than for natural gas sales, the Company generally earns the same margin whether it buys the natural gas and sells it to the customer or transports natural gas already owned by the customer. Throughput, the total natural gas sales and transportation volumes moved through the Company's system, increased in 1998 compared to 1997, primarily because of higher residential sales due to colder weather in 1998. The increase in throughput in 1997 compared to 1996 is primarily due to higher demand for electricity from gas-fired electric generation and less availability of hydro-electricity. Factors Influencing Future Performance Performance of the Company in the near future will depend primarily on the ratemaking and regulatory process, electric and natural gas industry restructurings, and the changing energy marketplace. These factors are summarized below. KN Energy Acquisition. On February 22, 1999, Sempra Energy announced a definitive agreement to acquire KN Energy, Inc., subject to approval by the shareholders of both companies and by various regulatory agencies. See Note 13 of the notes to Consolidated Financial Statements for additional information. Performance-Based Regulation. Under PBR, regulators allow future income potential to be tied to achieving or exceeding specific performance and productivity measures, as well as cost reductions, rather than relying solely on expanding utility rate base. See additional discussion in Note 11 of the notes to Consolidated Financial Statements. Regulatory Accounting Standards. SoCalGas has been accounting for the economic effects of regulation on its utility operations in accordance with Statement of Financial Accounting Standards (SFAS) No. 71, "Accounting for the Effects of Certain Types of Regulation." Under SFAS No. 71, a regulated entity records a regulatory asset if it is probable that, through the ratemaking process, the utility will recover the asset from customers. Regulatory liabilities represent future reductions in revenues for amounts due to customers. See Notes 2 and 11 of the notes to Consolidated Financial Statements for additional information. Affiliate Transactions. On December 16, 1997, the CPUC adopted rules establishing uniform standards of conduct governing the manner in which California investor owned utilities (IOUs) conduct business with their affiliates. The objective of these rules, effective January 1, 1998, is to ensure that the utilities' energy affiliates do not gain an unfair advantage over other competitors in the marketplace and that utility customers do not subsidize affiliate activities. The CPUC excluded utility-to-utility transactions between SDG&E and SoCalGas from the affiliate-transaction rules in its March 1998 decision approving the PE/Enova Business Combination. As a result, the affiliate transaction rules will not substantially impact the Company's ability to achieve anticipated synergy savings. See Notes 1 and 11 of the notes to Consolidated Financial Statements for additional information. Allowed Rate of Return. For 1998, the Company was authorized to earn a rate of return on rate base of 9.49 percent and a rate of return on common equity of 11.6 percent, which is unchanged from 1997. See additional discussion in Note 11 of the notes to Consolidated Financial Statements. Management Control of Expenses and Investment. In the past, management has been able to control operating expenses and investments within the amounts authorized to be collected in rates. It is the intent of management to control operating expenses and investments within the amounts authorized to be collected in rates in the PBR decision. The Company intends to make the efficiency improvements, changes in operations and cost reductions necessary to achieve this objective and earn its authorized rate of return. However, in view of the earnings-sharing mechanism and other elements of the PBR, it is more difficult to exceed authorized returns to the degree experienced in past years. See additional discussion of PBR in Note 11 of the notes to Consolidated Financial Statements. Electric Industry Restructuring. As a result of electric industry restructuring, natural gas generated electricity within the Company's service area competes with electric power generated throughout the western United States. The State of California in September 1996 enacted a law restructuring California's electric-utility industry (AB 1890). Consumers have the opportunity to choose to continue to purchase their electricity from the local utility under regulated tariffs, to enter into contracts with other energy-service providers (direct access) or to buy their power from the independent Power Exchange (PX) that serves as a wholesale power pool allowing all energy producers to participate competitively. The implementation of electric industry restructuring has no direct impact on the Company's operations. However, future volumes of natural gas transported for current utility electric generation customers may be adversely affected to the extent these regulatory changes divert electricity generated from the Company's service territory. Natural Gas Industry Restructuring. The natural gas industry experienced an initial phase of restructuring during the 1980s by deregulating natural gas sales to noncore customers. On January 21, 1998, the CPUC released a staff report initiating a project to assess the current market and regulatory framework for California's natural gas industry. The general goals of the plan are to consider reforms to the current regulatory framework emphasizing market- oriented policies benefiting California natural gas consumers. On August 25, 1998 California enacted a law prohibiting the CPUC from enacting any natural gas industry-restructuring decision for core customers prior to January 1, 2000. The CPUC continues to study the issue. Noncore Bypass. The Company's throughput to enhanced oil recovery (EOR) customers in the Kern County area has decreased significantly since 1992 because of the bypass of the Company's system by competing interstate pipelines. The decrease in revenues from EOR customers did not have a material impact on the Company's earnings. Bypass of other markets also may occur, and the Company is fully at risk for a reduction in non-EOR, noncore volumes due to bypass. However, significant additional bypass would require construction of additional facilities by competing pipelines. The Company is continuing to reduce its costs to maintain cost competitiveness in order to retain transportation customers. Noncore Pricing. To respond to bypass, the Company has received authorization from the CPUC for expedited review of long-term natural gas transportation service contracts with some noncore customers at lower than tariff rates. In addition, the CPUC approved changes in the methodology that eliminates subsidization of core customer rates by noncore customers. This allocation flexibility, together with negotiating authority, has enabled the Company to better compete with new interstate pipelines for noncore customers. Noncore Throughput. The Company's earnings may be adversely impacted if natural gas throughput to its noncore customers varies from estimates adopted by the CPUC in establishing rates. There is a continuing risk that an unfavorable variance in noncore volumes may result from external factors such as weather, electric deregulation, the increased use of hydro-electric power, competing pipeline bypass of the Company's system and a downturn in general economic conditions. In addition, many noncore customers are especially sensitive to the price relationship between natural gas and alternate fuels, as they are capable of readily switching from one fuel to another, subject to air-quality regulations. SoCalGas is at risk for the lost revenue. Through July 31, 1999, any favorable earnings effect of higher revenues resulting from higher throughput to noncore customers has been limited as a result of the Comprehensive Settlement discussed in Note 11 of the notes to Consolidated Financial Statements. Excess Interstate Pipeline Capacity. Existing interstate pipeline capacity into California exceeds current demand by over one billion cubic feet (Bcf) per day. This situation has reduced the market value of the capacity well below the Federal Energy Regulatory Commission's (FERC) tariffs. The Company has exercised its step- down option on both the El Paso and Transwestern systems, thereby reducing its firm interstate capacity obligation from 2.25 Bcf per day to 1.45 Bcf per day. FERC-approved settlements have resulted in a reduction in the costs that the Company may have been required to pay for the capacity released back to El Paso and Transwestern that cannot be remarketed. Of the 1.45 Bcf per day of capacity, the Company's core customers use 1.05 Bcf per day at the full FERC tariff rate. The remaining 0.4 Bcf per day of capacity is marketed at significant discounts. Under existing California regulation, unsubscribed capacity costs associated with the remaining 0.4 Bcf per day are recoverable in customer rates. While including the unsubscribed pipeline cost in rates may impact the Company's ability to compete in highly contested markets, the Company does not believe its inclusion will have a significant impact on volumes transported or sold. Environmental Matters The Company's operations are conducted in accordance with applicable federal, state and local environmental laws and regulations governing such things as hazardous wastes, air and water quality, and the protection of wildlife. These costs of compliance are normally recovered in customer rates. It is anticipated that the environmental costs associated with the natural gas operations will continue to be recoverable in rates. Capital expenditures to comply with environmental laws and regulations were $1 million in 1998 and 1997 and $3 million in 1996. In 1994, the CPUC approved the Hazardous Waste Collaborative Mechanism, which allows utilities to recover cleanup costs of hazardous waste contamination at sites where the utility may have responsibility or liability under the law to conduct or participate in any required cleanup. In general, utilities are allowed to recover 90 percent of their cleanup costs and any related costs of litigation with responsible parties. Estimated liabilities for environmental remediation are recorded when amounts are probable and estimable. Amounts authorized to be recovered in rates under the Hazardous Waste Collaborative Mechanism are recorded as a regulatory asset. Possible recoveries of environmental remediation liabilities from third parties are not deducted from the liability. For further discussion of environmental matters, see Note 10 of the notes to Consolidated Financial Statements. Other Income, Interest Expense and Income Taxes Other Income Other income, which primarily consists of interest income from short-term investments and regulatory balancing accounts, decreased in 1998 to $1 million from $7 million in 1997. The decrease was primarily the result of lower regulatory interest in 1998. Other income increased in 1997 to $7 million from $1 million in 1996. The increase was primarily due to higher regulatory interest in 1997. Interest Expense Interest expense for 1998 decreased to $80 million from $87 million in 1997. The decrease is primarily due to repayment of short-term debt in 1998. Interest expense for 1997 slightly increased to $87 million from $86 million in 1996. Income Taxes Income tax expense was $128 million, $178 million and $148 million in 1998, 1997 and 1996, respectively. This represents an effective tax rate of 45 percent for 1998, 43 percent for 1997 and 42 percent for 1996. See Note 5 of the notes to Consolidated Financial Statements for additional information. Derivative Financial Instruments The Company's policy is to use derivative financial instruments to manage exposure to fluctuations in interest rates, foreign currency exchange rates and energy prices. Transactions involving these financial instruments are with reputable firms and major exchanges. The use of these instruments may expose the Company to market and credit risks. At times, credit risk may be concentrated with certain counterparties, although counterparty nonperformance is not anticipated. The Company's operations use energy derivatives to manage natural gas price risk associated with servicing their load requirements. These instruments include forward contracts, futures, swaps, options and other contracts, with maturities ranging from 30 days to 12 months. In the case of price-risk management activities, the use of derivative financial instruments by the Company is subject to certain limitations imposed by established Company policy and regulatory requirements. See Note 8 of the notes to Consolidated Financial Statements and the "Market Risk Management Activities" section below for further information regarding the use of energy derivatives by the Company's operations. Market Risk Management Activities Market risk is the risk of erosion of the Company's cash flows, net income and asset values due to adverse changes in interest and foreign-currency rates, and in prices for energy. Sempra Energy has adopted corporate-wide policies governing its market-risk management activities. An Energy Risk Management Oversight Committee, consisting of senior corporate officers, oversees energy-price risk-management activities to ensure compliance with Sempra Energy's stated energy risk-management policies. In addition, all affiliates have groups that monitor and control energy-price risk-management activities independently from the groups responsible for creating or actively managing these risks. Along with other tools, the Company uses Value at Risk (VaR) to measure its exposure to market risk. 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 level. The Company has adopted the variance/covariance methodology in its calculation of VaR, and uses a 95 percent confidence level. Holding periods are specific to the types of positions being measured, and are determined based on the size of the position or portfolios, market liquidity, tenor and other factors. Historical volatilities and correlations between instruments and positions are used in the calculation. The following is a discussion of the Company's primary market- risk exposures as of December 31, 1998, including a discussion of how these exposures are managed. Interest-Rate Risk The Company is exposed to fluctuations in interest rates primarily as a result of its fixed-rate long-term debt. The Company has historically funded its operations through long-term bond issues with fixed interest rates. With the restructuring of the regulatory process, greater flexibility has been permitted within the debt- management process. As a result, recent debt offerings have been selected with short-term maturities to take advantage of yield curves or used a combination of fixed- and floating-rate debt. Interest rate swaps, subject to regulatory constraints, may be used to adjust interest-rate exposures when appropriate, based upon market conditions. However, no such swaps are in place at December 31, 1998. A portion of the Company's borrowings are denominated in foreign currencies, which expose the Company to market risk associated with exchange-rate movements. The Company's policy generally is to hedge major foreign-currency cash exposures through swap transactions. These contracts are entered into with major international banks, thereby minimizing the risk of credit loss. The VaR on the Company's fixed-rate long-term debt is estimated at approximately $168 million as of December 31, 1998, assuming a one-year holding period. The VaR attributable to currency exchange rates nets to zero as a result of a currency swap that is directly matched to the Company's Swiss Franc debt obligation, its only non- dollar-denominated debt. Energy-Price Risk Market risk related to physical commodities is based upon potential fluctuations in natural gas exchange prices and basis. The Company's market risk is impacted by changes in volatility and liquidity in the markets in which these instruments are traded. The Company is exposed, in varying degrees, to price risk in the natural gas markets. The Company's policy is to manage this risk within a framework that considers the unique markets, and operating and regulatory environment. The Company is exposed to market risk on its natural gas purchase, sale and storage activities whenever natural gas prices fall outside the GCIM tolerance band. The Company manages this risk within the parameters of the Company's market risk management framework. As of December 31, 1998, the total VaR of the Company's natural gas positions was not material. Credit Risk Credit risk relates to the risk of loss that would be incurred as a result of nonperformance by counterparties pursuant to the terms of their contractual obligations. The Company avoids concentration of counterparties and maintains credit policies with regard to counterparties that management believes significantly minimize overall credit risk. These policies include an evaluation of potential counterparties' financial condition (including credit rating), collateral requirements under certain circumstances, and the use of standardized agreements that allow for the netting of positive and negative exposures associated with a single counterparty. The Company monitors credit risk through a credit-approval process and the assignment and monitoring of credit limits. These credit limits are established based on risk and return considerations under terms customarily available in the industry. Year 2000 Issues Most companies are affected by the inability of many automated systems and applications to process the year 2000 and beyond. The Year 2000 issues are the result of computer programs and other automated processes using two digits to identify a year, rather than four digits. Any of the Company's computer programs that include date-sensitive software may recognize a date using "00" as representing the year 1900, instead of the year 2000, or "01" as 1901, etc., which could lead to system malfunctions. The Year 2000 issues impact both Information Technology (IT) systems and also non-IT systems, including systems incorporating "embedded processors." To address this problem, in 1996, both Pacific Enterprises and Enova Corporation established company-wide Year 2000 programs. These programs have now been consolidated into Sempra Energy's overall Year 2000 readiness effort. Sempra Energy has established a central Year 2000 Program Office which reports to the its Chief Information Technology Officer and reports periodically to the audit committee of the Board of Directors. The Company's State of Readiness Sempra Energy is identifying all IT and non-IT systems that might not be Year 2000 ready and categorizing them in the following areas: IT applications, computer hardware and software infrastructure, telecommunications, embedded systems and third parties. Sempra Energy is currently evaluating its exposure in all of these areas. These systems and applications are being tracked and measured through four key phases: inventory, assessment, remediation/testing, and Year 2000 readiness. Those applications and systems which, if not appropriately remediated, may have a significant impact on energy delivery, revenue collection or the safety of personnel, customers or facilities are being assessed and modified/replaced first. The testing effort includes functional testing of Year 2000 dates and validating that changes have not altered existing functionality. Sempra Energy uses an independent, internal-review process to verify that the appropriate testing has occurred. Inventory and assessment for all company systems were completed by January 1999 and ongoing inventory and assessment will be performed, as necessary, on any new applications. The project is on schedule and the Company estimates that by June 30, 1999, all critical systems will be suitable for continued use into the year 2000 with no significant operational problems. Sempra Energy's current schedule for Year 2000 testing, readiness and development of contingency plans is subject to change depending upon the remediation and testing phases of its compliance effort and upon developments that may arise as the Company continues to assess its computer-based systems and operations. In addition, this schedule is dependent upon the efforts of third parties, such as suppliers (including energy producers) and customers. Accordingly, delays by third parties may cause Sempra Energy's schedule to change. Costs to Address Sempra Energy's Year 2000 Issues Sempra Energy's budget for the Year 2000 program is $48 million, of which $38 million has been spent. As Sempra Energy continues to assess its systems and as the remediation and testing efforts progress, cost estimates may change. Sempra Energy's Year 2000 readiness effort is being funded entirely by operating cash flows. The Risks of Sempra Energy's Year 2000 Issues Based upon its current assessment and testing of the Year 2000 issue, Sempra Energy believes the reasonably likely worst case Year 2000 scenarios would have the following impacts upon its operations. With respect to Sempra Energy's ability to provide energy to its domestic utility customers, it believes that the reasonably likely worst case scenario is for small, localized interruptions of natural gas or electrical service which are restored in a timeframe that is within normal service levels. With respect to services that are essential to Sempra Energy's operations, such as customer service, business operations, supplies and emergency response capabilities, the scenario is for minor disruptions of essential services with rapid recovery and all essential information and processes ultimately recovered. To assist in preparing for and mitigating these possible scenarios, Sempra Energy is a member of several industry-wide efforts established to deal with Year 2000 problems affecting embedded systems and equipment used by the nation's natural gas and electric power companies. Under these efforts, participating utilities are working together to assess specific vendors' system problems and to test plans. These assessments will be shared by the industry as a whole to facilitate Year 2000 problem solving. A portion of this risk is due to the various Year 2000 schedules of critical third-party suppliers and customers. Sempra Energy is in the process of contacting its critical suppliers and customers to survey their Year 2000 remediation programs. While risks related to the lack of Year 2000 readiness by third parties could materially and adversely affect the Company's business, results of operations and financial condition, the Company expects its Year 2000 readiness efforts to reduce significantly the Company's level of uncertainty about the impact of third party Year 2000 issues on both its IT systems and non-IT systems. Company's Contingency Plans Sempra Energy's contingency plans for interruptions related to year 2000 issues are being incorporated in its existing overall emergency preparedness plans. To the extent appropriate, such plans will include emergency backup and recovery procedures, remediation of existing systems parallel with installation of new systems, replacing electronic applications with manual processes, identification of alternate suppliers and increasing inventory levels. Sempra Energy expects these contingency plans to be completed by June 30, 1999. Due to the speculative and uncertain nature of contingency planning, there can be no assurances that such plans actually will be sufficient to reduce the risk of material impacts on Sempra Energy's operations due to Year 2000 issues. New Accounting Standards In June 1998, the Financial Accounting Standards Board issued Statement of Financial Accounting Standards (SFAS) No. 133 "Accounting for Derivative Instruments and Hedging Activities." This statement, which is effective January 1, 2000, requires that an entity recognize all derivatives as either assets or liabilities in the statement of financial position, measure those instruments at fair value and recognize changes in the fair value of derivatives in earnings in the period of change unless the derivative qualifies as an effective hedge that offsets certain exposures. The effect of this standard on the Company's Consolidated Financial Statements has not yet been determined. Information Regarding Forward-Looking Statements This report includes forward-looking statements within the definition of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. The words "estimates," "believes," "expects," "anticipates," "plans" and "intends," variations of such words, and similar expressions are intended to identify forward-looking statements that involve risks and uncertainties which could cause actual results to differ materially from those anticipated. These statements are necessarily based upon various assumptions involving judgments with respect to the future including, among others, local, regional, national, and international economic, competitive, political and regulatory conditions and developments, technological developments, capital market conditions, inflation rates, interest rates, energy markets, weather conditions, business and regulatory or legal decisions, the pace of deregulation of retail natural gas and electricity industries, the timing and success of business development efforts, and other uncertainties, all of which are difficult to predict and many of which are beyond the control of the Company. Accordingly, while the Company believes that the assumptions are reasonable, there can be no assurance that they will approximate actual experience, or that the expectations will be realized. Readers are urged to carefully review and consider the risks, uncertainties and other factors which affect the Company's business described in this annual report and other reports filed by the Company from time to time with the Securities and Exchange Commission. ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK The information required by Item 7A is set forth under "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Market Risk Management Activities." ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA INDEPENDENT AUDITORS' REPORT 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 as of December 31, 1998 and 1997, and the related statements of consolidated income, changes in shareholders' equity, and cash flows for each of the three years in the period ended December 31, 1998. 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 generally accepted auditing standards. 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, 1998 and 1997, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 1998 in conformity with generally accepted accounting principles. /s/ DELOITTE & TOUCHE LLP San Diego, California January 27, 1999, except for Note 13 as to which the date is February 22, 1999 SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES STATEMENTS OF CONSOLIDATED INCOME In millions of dollars

SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES CONSOLIDATED BALANCE SHEETS In millions of dollars

SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES CONSOLIDATED BALANCE SHEETS In millions of dollars

SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARIES STATEMENTS OF CONSOLIDATED CASH FLOWS In millions of dollars

SOUTHERN CALIFORNIA GAS COMPANY STATEMENTS OF CONSOLIDATED CHANGES IN SHAREHOLDERS' EQUITY For the years ended December 31, 1998, 1997, 1996 (Dollars in millions)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS NOTE 1: BUSINESS COMBINATION On June 26, 1998, Enova Corporation (Enova), and Pacific Enterprises (PE), parent company of Southern California Gas Company (SoCalGas), combined into a new company named Sempra Energy. As a result of the combination, (i) each outstanding share of common stock of Enova was converted into one share of common stock of Sempra Energy, (ii) each outstanding share of common stock of PE was converted into 1.5038 shares of common stock of Sempra Energy and (iii) the preferred stock and preference stock of Enova's principal subsidiary, San Diego Gas & Electric Company (SDG&E); PE; and SoCalGas remained outstanding. The combination was approved by the shareholders of both companies on March 11, 1997 and was a tax-free transaction. The Consolidated Financial Statements of Sempra Energy and its subsidiaries give effect to the business combination using the pooling-of-interests method. As required by the March 1998 decision of the California Public Utilities Commission (CPUC) approving the business combination, SDG&E has entered into agreements to sell its fossil-fueled generation units. The sales are subject to regulatory approvals and are expected to close during its first half of 1999. In addition, SoCalGas has sold its options to purchase the California portions of the Kern River and Mojave Pipeline natural gas transmission facilities. The Federal Energy Regulatory Commission's (FERC) approval of the combination includes conditions that the combined company will not unfairly use any potential market power regarding natural gas transportation to fossil-fueled generation plants. The FERC also specifically noted that the divestiture of SDG&E's fossil- fueled generation plants would eliminate any concerns about vertical market power arising from transactions between SDG&E and SoCalGas. NOTE 2: SIGNIFICANT ACCOUNTING POLICIES Utility Plant and Depreciation Utility plant represents the buildings, equipment and other facilities used by the Company to provide natural gas service. The cost of utility plant includes labor, materials, contract services and related items, and an allowance for funds used during construction. The cost of retired depreciable utility plant, plus removal costs minus salvage value, is charged to accumulated depreciation. Depreciation expense is based on the straight-line method over the useful lives of the assets or a shorter period prescribed by the CPUC. The provisions for depreciation as a percentage of average depreciable utility plant in 1998, 1997 and 1996, respectively are: 4.36, 4.35 and 4.39. Allowance for Funds Used During Construction (AFUDC) The allowance represents the cost of funds used to finance the construction of utility plant and is added to the cost of utility plant. AFUDC also increases income, although it is not a current source of cash. Inventories Materials and supplies are generally valued at the lower of average cost or market; natural gas in storage is valued by the last-in first-out method. Effects of Regulation SoCalGas accounting policies conform with generally accepted accounting principles for regulated enterprises and reflect the policies of the CPUC. SoCalGas has been preparing its financial statements in accordance with the provisions of Statement of Financial Accounting Standards (SFAS) No. 71, "Accounting for the Effects of Certain Types of Regulation," under which a regulated utility may record a regulatory asset if it is probable that, through the ratemaking process, the utility will recover that asset from customers. Regulatory liabilities represent future reductions in rates for amounts due to customers. In addition, SFAS No. 121, "Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to Be Disposed Of," affects utility plant and regulatory assets such that a loss must be recognized whenever a regulator excludes all or part of an asset's cost from rate base. Additional information concerning regulatory assets and liabilities is described in Note 11. Revenues and Regulatory Balancing Accounts Revenues from utility customers consist of deliveries to customers and the changes in regulatory balancing accounts. Earnings fluctuations from changes in the costs of natural gas and consumption levels for the majority of natural gas are eliminated by balancing accounts authorized by the CPUC. Regulatory Assets Regulatory assets include unrecovered premium on early retirement of debt, post-retirement benefit costs, deferred income taxes recoverable in rates and other regulatory-related expenditures that the Company expects to recover in future rates. See Note 11 for additional information. Comprehensive Income In 1998, the Company adopted SFAS No. 130, "Reporting Comprehensive Income." This statement requires reporting of comprehensive income and its components (revenues, expenses, gains and losses) in any complete presentation of general-purpose financial statements. Comprehensive income describes all changes, except those resulting from investments by owners and distributions to owners, in the equity of a business enterprise from transactions and other events including, as applicable, foreign-currency items, minimum pension liability adjustments and unrealized gains and losses on certain investments in debt and equity securities. Comprehensive income was equal to net income for the years ended December 31, 1998, 1997, and 1996. Use of Estimates in the Preparation of the Financial Statements The preparation of the consolidated financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Statements of Consolidated Cash Flows Cash equivalents are highly liquid investments with original maturities of three months or less, or investments that are readily convertible to cash. New Accounting Standard In June 1998, the Financial Accounting Standards Board issued Statement of Financial Accounting Standards (SFAS) No. 133 "Accounting for Derivative Instruments and Hedging Activities." This statement, which is effective January 1, 2000, requires that an entity recognize all derivatives as either assets or liabilities in the statement of financial position, measure those instruments at fair value and recognize changes in the fair value of derivatives in earnings in the period of change unless the derivative qualifies as an effective hedge that offsets certain exposures. The effect of this standard on the Company's consolidated financial statements has not yet been determined. NOTE 3: SHORT-TERM BORROWINGS SoCalGas has a $400 million multi-year credit agreement. This agreement expires in 2001 and bears interest at various rates based on market rates and the Company's credit ratings. SoCalGas' lines of credit are available to support commercial paper. At December 31, 1998 and 1997, SoCalGas' bank line of credit was unused. At December 31, 1998, there were no commercial-paper obligations outstanding. At December 31, 1997, SoCalGas had $351 million of commercial-paper obligations outstanding, of which approximately $94 million related to the restructuring costs associated with certain long-term natural gas supply contracts under the Comprehensive Settlement. See Note 11 for additional information. NOTE 4: LONG-TERM DEBT - ------------------------------------------------------------------- December 31, (In millions of dollars) 1998 1997 - ------------------------------------------------------------------- First-Mortgage Bonds 5.250% March 1, 1998 $ -- $ 100 6.875% August 15, 2002 100 100 5.750% November 15, 2003 100 100 8.750% October 1, 2021 150 150 7.375% March 1, 2023 100 100 7.500% June 15, 2023 125 125 6.875% November 1, 2025 175 175 ---------------------------- 750 850 Other Long-Term Debt 6.210% Notes, November 7, 1999 75 75 6.375% Notes, October 29, 2001 120 120 8.750% Notes, July 6, 2000 30 30 5.670% Notes, January 15, 2003 75 -- SFr. 100,000,000 5.125% Bonds, February 6, 1998 (foreign currency exposure hedged through currency swap at an interest rate of 9.725%) -- 47 SFr. 15,695,000 6.375% Foreign Interest Payment Securities, May 14, 2006 8 8 ---------------------------- Total 1,058 1,130 Less: Long term debt due within one year 75 147 Unamortized debt discount on long-term debt 16 15 ---------------------------- 91 162 ---------------------------- Total $ 967 $ 968 - ------------------------------------------------------------------- Maturities of long-term debt are $75 million in 1999, $30 million in 2000, $120 million in 2001, $100 million in 2002 and $175 million in 2003. First-Mortgage Bonds First-mortgage bonds are secured by a lien on substantially all utility plant. SoCalGas may issue additional first-mortgage bonds upon compliance with the provisions of its bond indenture, which provides for, among other things, the issuance of an additional $750 million of first-mortgage bonds as of December 31, 1998. Other Long-Term Debt During 1998, SoCalGas issued $75 million of unsecured debt in medium-term notes used to finance working capital requirements. Currency Rate Swaps In May 1996, SoCalGas issued SFr. 15,695,000 of 6.375% Foreign Interest Payment Securities maturing on May 14, 2006. SoCalGas hedged the currency exposure by entering into a swap transaction with a major international bank. As a result, the bond issue, interest payments and other ongoing costs were swapped for fixed annual payments. The Foreign Interest Payment Securities are renewable at ten-year intervals at reset interest rates. The next put date for the $8 million Foreign Interest Payment Securities is in the year 2006. NOTE 5: INCOME TAXES The reconciliation of the statutory federal income tax rate to the effective income tax rate is as follows: - ------------------------------------------------------------------ 1998 1997 1996 - ------------------------------------------------------------------ Statutory federal income tax rate 35.0% 35.0% 35.0% Depreciation 9.4 5.5 6.6 State income taxes - net of federal income tax benefit 4.7 6.3 5.4 Tax credits (0.9) (0.7) (0.9) Capitalized expenses not deferred (0.9) (0.7) (3.2) Other - net (2.7) (2.6) (.5) ------------------------------ Effective income tax rate 44.6% 42.8% 42.4% - ------------------------------------------------------------------ The components of income tax expense are as follows: - ------------------------------------------------------------------ (Dollars in millions) 1998 1997 1996 - ------------------------------------------------------------------ Current: Federal $233 $138 $100 State 64 38 30 ------------------------------ Total current taxes 297 176 130 ------------------------------ Deferred: Federal (128) 6 21 State (38) (1) - ------------------------------ Total deferred taxes (166) 5 21 ------------------------------ Deferred investment tax credits-net (3) (3) (3) ------------------------------ Total income tax expense $128 $178 $148 - ------------------------------------------------------------------ Deferred income taxes at December 31 result from the following: - ------------------------------------------------------------------ (Dollars in millions) 1998 1997 - ------------------------------------------------------------------ Deferred Tax Liabilities: Differences in financial and tax bases of utility plant $449 $455 Regulatory balancing accounts - 161 Regulatory assets 1 11 Other 50 48 ------------------------------ Total deferred tax liabilities 500 675 ------------------------------ Deferred Tax Assets: Unamortized investment tax credits 25 27 Regulatory balancing accounts 51 - Comprehensive settlement (see Note 11) 95 114 Other deferred liabilities 153 158 Other 10 14 ------------------------------ Total deferred tax assets 334 313 ------------------------------ Net deferred income tax liability 166 362 Current portion (net asset) 157 11 ------------------------------ Non-current portion (net liability) $323 $373 - ------------------------------------------------------------------ NOTE 6: EMPLOYEE BENEFIT PLANS The information presented below describes the plans of the Company. In connection with the PE/Enova Business Combination described in Note 1, certain of these plans have been or will be replaced or modified, and numerous participants have been or will be transferred from the Company's plans to those of Sempra Energy. Pension and Other Postretirement Benefits The Company sponsors qualified and nonqualified pension plans and other postretirement benefit plans for its employees. The following tables provide a reconciliation of the changes in the plans' benefit obligations and fair value of assets over the two years, and a statement of the funded status as of each year end:

The following table provides the components of net periodic benefit cost for the plans:

Assumed health care cost trend rates have a significant effect on the amounts reported for the health care plans. A 1% change in assumed health care cost trend rates would have the following effects: - ------------------------------------------------------------------------ (Dollars in millions) 1% Increase 1% Decrease - ------------------------------------------------------------------------ Effect on total of service and interest cost components of net periodic postretirement health care benefit cost $10 $ (9) Effect on the health care component of the accumulated postretirement benefit obligation $67 $(61) - ------------------------------------------------------------------------ The projected benefit obligation and accumulated benefit obligation for the pension plan were $15 million and $12 million, respectively, as of December 31, 1998, and $12 million and $10 million, respectively, as of December 31, 1997. Other postretirement benefits include medical benefits for retirees and their spouses, and retiree life insurance. Savings Plans SoCalGas offers a savings plan, administered by plan trustees, to all eligible employees. Eligibility to participate in the various employer plans begins after one month of completed service. Employees may contribute, subject to plan provisions, from 1 percent to 15 percent of their regular earnings. Employer contributions, after one year of completed service, are made in shares of Sempra Energy common stock. Employer contributions are equal to 50 percent of the first 6 percent of eligible base salary contributed by employees. The employee's contributions, at the direction of the employees, are primarily invested in Sempra Energy stock, mutual funds or guaranteed investment contracts. Employer contributions for the SoCalGas plan are partially funded by the Pacific Enterprises Employee Stock Ownership Plan and Trust. Annual expense for the savings plans was $7 million in 1998, 1997 and 1996. NOTE 7: STOCK-BASED COMPENSATION Sempra Energy has stock-based compensation plans that align employee and shareholder objectives related to Sempra Energy's long-term growth. The long-term incentive stock compensation plan provides for aggregate awards of Sempra Energy non-qualified stock options, incentive stock options, restricted stock, stock appreciation rights, performance awards, stock payments or dividend equivalents to eligible employees of Sempra Energy and its subsidiaries. In 1995, Statement of Financial Accounting Standards (SFAS) No. 123, "Accounting for Stock-Based compensation," was issued. It encourages a fair-value-based method of accounting for stock-based compensation. As permitted by SFAS No. 123, Sempra Energy and its subsidiaries adopted its disclosure-only requirements and continue to account for stock-based compensation in accordance with the provisions of accounting Principles Board Opinion No. 25, "Accounting for Stock Issued to Employees." To the extent that subsidiary employees participate in the plans or that subsidiaries are allocated a portion of Sempra Energy's costs of the plans, the subsidiaries record an expense for the plans. SoCalGas recorded expenses of $4 million in each of 1998 and 1997, and $1 million in 1996. NOTE 8: FINANCIAL INSTRUMENTS Fair Value The fair values of the Company's financial instruments are not materially different from the carrying amounts, except for long- term debt and preferred stock. The carrying amounts and fair values of long-term debt are $1.0 billion and $1.1 billion, respectively, at December 31, 1998, and $1.1 billion and $1.2 billion, respectively, at December 31, 1997. The carrying amounts and fair values of preferred stock are $22 million and $8 million, respectively, at December 31, 1998, and $97 million and $95 million, respectively, at December 31, 1997. The fair values of the first-mortgage bonds and preferred stock are estimated based on quoted market prices for them or for similar issues. The fair values of long-term notes payable are based on the present value of the future cash flows, discounted at rates available for similar notes with comparable maturities. Off-Balance-Sheet Financial Instruments The Company's policy is to use derivative financial instruments to manage its exposure to fluctuations in interest rates, foreign- currency exchange rates and energy prices. Transactions involving these financial instruments expose the Company to market and credit risks which may at times be concentrated with certain counterparties, although counterparty nonperformance is not anticipated. Energy Derivatives As a result of the GCIM (see Note 11), the Company enters into a certain amount of natural gas futures contracts in the open market with the intent of reducing natural gas costs within the GCIM tolerance band. The Company's policy is to use natural gas futures contracts to mitigate risk and better manage natural gas costs. The CPUC has approved the use of natural gas futures for managing risk associated with the GCIM. For the years ended December 31, 1998, 1997 and 1996, gains and losses from natural gas futures contracts are not material to SoCalGas' financial statements. NOTE 9: SHAREHOLDERS' EQUITY - ----------------------------------------------------------------- At December 31, (Dollars in millions) 1998 1997 - ----------------------------------------------------------------- COMMON EQUITY: Common stock, without par value, authorized 100,000,000 shares, 91,300,000 shares outstanding $ 835 $ 835 Retained earnings 525 535 -------------------------- Total common equity $ 1,360 $ 1,370 - ----------------------------------------------------------------- All shares of SoCalGas common stock are wholly owned by Pacific Enterprises. - ----------------------------------------------------------------- December 31, (Dollars in millions) 1998 1997 - ----------------------------------------------------------------- PREFERRED STOCK: Not subject to mandatory redemption: $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 Without par value, authorized 10,000,000 shares 7.75% Series - 75 -------------- $22 $97 - ----------------------------------------------------------------- None of SoCalGas' series of preferred stock are callable. All series have one vote per share and cumulative preferences as to dividends. On February 2, 1998, SoCalGas redeemed all outstanding shares of 7.75% Series Preferred Stock at a price per share of $25 plus $0.09 of dividends accruing to the date of redemption. The total cost to SoCalGas was approximately $75.3 million. Dividend Restrictions The CPUC regulates SoCalGas' capital structure, limiting the dividends it may pay. At December 31, 1998, $233 million of SoCalGas' retained earnings was available for future dividends. NOTE 10: CONTINGENCIES AND COMMITMENTS Natural Gas Contracts SoCalGas buys natural gas under several short-term and long-term contracts. Short-term purchases are based on monthly spot market prices. SoCalGas has commitments for firm pipeline capacity under contracts with pipeline companies that expire at various dates through the year 2006. These agreements provide for payments of an annual reservation charge. SoCalGas recovers such fixed charges in rates. At December 31, 1998, the future minimum payments under natural gas contracts were: - --------------------------------------------------------------------- Storage and (Dollars in millions) Transportation Natural Gas - --------------------------------------------------------------------- 1999 $ 184 $ 270 2000 186 150 2001 188 153 2002 188 157 2003 184 158 Thereafter 460 - ------------------------------- Total minimum payments $1,390 $ 888 - --------------------------------------------------------------------- Total payments under the short-term and long-term contracts were $0.9 billion in 1998, $1.1 billion in 1997, and $0.9 billion in 1996. Leases SoCalGas has operating leases on real and personal property expiring at various dates from 1999 to 2030. The rentals payable under these leases are determined on both fixed and percentage bases, and most leases contain options to extend, which are exercisable by SoCalGas. The minimum rental commitments payable in future years under all noncancellable leases are: Operating (Dollars in millions) Leases - ----------------------------------------------------------------- 1999 $ 30 2000 30 2001 29 2002 29 2003 30 Thereafter 248 - ----------------------------------------------------------------- Total future rental commitment $ 396 - ----------------------------------------------------------------- Rent expense totaled $43 million in 1998, $44 million in 1997 and $45 million in 1996. Other Commitments and Contingencies At December 31, 1998 commitments for capital expenditures were approximately $8 million. Environmental Issues SoCalGas believes that its operations are conducted in accordance with federal, state and local environmental laws and regulations governing hazardous wastes, air and water quality, land use, and solid waste disposal. SoCalGas incurs significant costs to operate its facilities in compliance with these laws and regulations. The costs of compliance with environmental laws and regulations generally have been recovered in customer rates. In 1994, the CPUC approved the Hazardous Waste Collaborative Memorandum account allowing utilities to recover their hazardous waste costs, including those related to Superfund sites or similar sites requiring cleanup. Recovery of 90 percent of cleanup costs and related third-party litigation costs and 70 percent of the related insurance-litigation expenses is permitted. In addition, the Company has the opportunity to retain a percentage of any insurance recoveries to offset the 10 percent of costs not recovered in rates. Environmental liabilities that may arise are recorded when remedial efforts are probable and the costs can be estimated. SoCalGas' capital expenditures to comply with environmental laws and regulations were $1 million in 1998, $1 million in 1997, and $3 million in 1996, and are not expected to be significant over the next five years. The Company has identified and reported to California environmental authorities 42 former manufactured-gas plant sites for which it (together with other utilities as to 21 of these sites) may have remedial obligations under environmental laws. As of December 31, 1998, 12 of these sites have been remediated, of which 10 have received certification from the California Environmental Protection Agency. Preliminary investigations, at a minimum, have been completed on 39 of the gas plant sites. At December 31, 1998, the Company's estimated remaining investigation and remediation liability for these sites was $68 million, of which 90 percent is authorized to be recovered through the Hazardous Waste Collaborative Mechanism. In addition, the Company has been named as a potentially responsible party for two landfill sites and two industrial waste disposal sites. The total cost estimate for remediation of these four sites is $4 million. The Company believes that any costs not ultimately recovered through rates, insurance or other means, upon giving effect to previously established liabilities, will not have a material adverse effect on the Company's consolidated results of operations or financial position. SoCalGas has been associated with various other sites which may require remediation under federal, state or local environmental laws. SoCalGas is unable to determine the extent of its responsibility for remediation of these sites until assessments are completed. Furthermore, the number of others that also may be responsible, and their ability to share in the cost of the cleanup, is not known. The Company does not anticipate that such costs, net of the portion recoverable in rates, will be significant. Litigation SoCalGas is involved in various legal matters arising out of the ordinary course of business. Management believes that these matters will not have a material adverse effect on the Company's results of operations, financial condition or liquidity. Concentration of Credit Risk SoCalGas grants credit to its utility customers, substantially all of whom are located in its service territory, which covers most of Southern California and a portion of central California. NOTE 11: REGULATORY MATTERS Natural Gas Industry Restructuring The natural gas industry experienced an initial phase of restructuring during the 1980s by deregulating natural gas sales to noncore customers. On January 21, 1998, the CPUC released a staff report initiating a project to assess the current market and regulatory framework for California's natural gas industry. The general goals of the plan are to consider reforms to the current regulatory framework emphasizing market-oriented policies benefiting California natural gas consumers. On August 25, 1998, California adopted a law prohibiting the CPUC from enacting any natural gas industry restructuring decision for customers prior to January 1, 2000. During the moratorium, the CPUC will hold hearings throughout the state and intends to give the California Legislature a report for its review detailing specific recommendations for changing the natural gas market within California. SoCalGas will actively participate in this effort. Performance-Based Regulation (PBR) To promote efficient operations and improved productivity and to move away from reasonableness reviews and disallowances, the CPUC has been directing utilities to use PBR. PBR has replaced the general rate case and certain other regulatory proceedings for SoCalGas. Under PBR, regulators require future income potential to be tied to achieving or exceeding specific performance and productivity measures, as well as cost reductions, rather than relying solely on expanding utility rate base in a market where a utility already has a highly developed infrastructure. SoCalGas' PBR is in effect through December 31, 2002; however, the CPUC decision allows for the possibility that changes to the PBR mechanism could be adopted in a decision to be issued in SoCalGas' 1999 Biennial Cost Allocation Proceeding, which is anticipated to become effective before year end 1999. Key elements of the SoCalGas PBR include an initial reduction in base rates, an indexing mechanism that limits future rate increases to the inflation rate less a productivity factor, a sharing mechanism with customers if earnings exceed the authorized rate of return on rate base, and rate refunds to customers if service quality deteriorates. Specifically, the key elements of SoCalGas' PBR include the following: - --Earnings up to 25 basis points in excess of the authorized rate of return on rate base are retained 100 percent by shareholders. Earnings that exceed the authorized rate of return on rate base by greater than 25 basis points are shared between customers and shareholders on a sliding scale that begins with 75 percent of the additional earnings being given back to customers and declining to 0 percent as earned returns approach 300 basis points above authorized amounts. There is no sharing if actual earnings fall below the authorized rate of return. In 1999, SoCalGas is authorized to earn a 9.49 percent return on rate base, the same as in 1998. - --Revenue or base margin per customer is indexed based on inflation less an estimated productivity factor of 2.1 percent in the first year (1998), increasing 0.1 percent per year up to 2.5 percent in the fifth year (2002). This factor includes 1 percent to approximate the projected impact of a declining rate base. - --The CPUC decision allows for pricing flexibility for residential and small commercial customers, with any shortfalls in revenue being borne by shareholders and with any increase in revenue shared between shareholders and customers. Under SoCalGas' PBR, annual cost of capital proceedings are replaced by an automatic adjustment mechanism if changes in certain indices exceed established tolerances. The mechanism is triggered if the 12-month trailing average of actual market interest rates increases or decreases by more than 150 basis points and is forecasted to continue to vary by at least 150 basis points for the next year. If this occurs, there would be an automatic adjustment of rates for the change in the cost of capital according to a preestablished formula, which applies a percentage of the change to various capital components. Comprehensive Settlement Of Natural Gas Regulatory Issues In July 1994, the CPUC approved a comprehensive settlement for SoCalGas (Comprehensive Settlement) of a number of regulatory issues, including rate recovery of a significant portion of the restructuring costs associated with certain long-term contracts with suppliers of California-offshore and Canadian natural gas. In the past, the cost of these supplies had been substantially in excess of SoCalGas' average delivered cost for all natural gas supplies. The restructured contracts substantially reduced the ongoing delivered costs of these supplies. The Comprehensive Settlement permits SoCalGas to recover in utility rates approximately 80 percent of the contract-restructuring costs of $391 million and accelerated amortization of related pipeline assets of approximately $140 million, together with interest, incurred prior to January 1, 1999. In addition to the supply issues, the Comprehensive Settlement addressed the following other regulatory issues: - --Noncore Customer Rates. The Comprehensive Settlement changed the procedures for determining noncore rates to be charged by SoCalGas for the five-year period commencing August 1, 1994. These rates are based upon SoCalGas' recorded throughput to these customers for 1991. SoCalGas will bear the full risk of any declines in noncore deliveries from 1991 levels. Any revenue enhancement from deliveries in excess of 1991 levels will be limited by a crediting account mechanism that will require a credit to customers of 87.5 percent of revenues in excess of certain limits. These annual limits above which the credit is applicable increase from $11 million to $19 million over the five-year period from August 1, 1994, through July 31, 1999. SoCalGas' ability to report as earnings the results from revenues in excess of SoCalGas' authorized return from noncore customers due to volume increases has been limited for the five years beginning August 1, 1994, as a result of the Comprehensive Settlement. The 1999 Biennial Cost Allocation Proceeding is intended to adopt measures to replace this aspect of the Comprehensive Settlement when it expires during 1999. - --Gas Cost Incentive Mechanism (GCIM). On April 1, 1994, SoCalGas implemented a new process for evaluating its natural gas purchases, substantially replacing the previous process of reasonableness reviews. Initially a three-year pilot program, in December 1998 the CPUC extended the GCIM program indefinitely. Automatic annual extensions to the program will continue unless the CPUC issues an order stating otherwise. GCIM compares SoCalGas' cost of natural gas with a benchmark level, which is the average price of 30-day firm spot supplies in the basins in which SoCalGas purchases the natural gas. The mechanism permits full recovery of all costs within a tolerance band above the benchmark price and refunds all savings within a tolerance band below the benchmark price. The costs or savings outside the tolerance band are shared equally between customers and shareholders. The CPUC approved the use of natural gas futures for managing risk associated with the GCIM. SoCalGas enters into natural gas futures contracts in the open market on a limited basis to mitigate risk and better manage natural gas costs. In June 1997, SoCalGas requested a shareholder award of $11 million, which was approved by the CPUC in June 1998 and is included in pretax income in 1998. In June 1998, SoCalGas filed its annual GCIM application with the CPUC, requesting an award of $2 million for the annual period ended March 31, 1998. This request was approved by the CPUC in December 1998 and is included in pretax income in 1998. - --Attrition Allowances. The Comprehensive Settlement authorized SoCalGas an annual allowance for increases in operating and maintenance expenses. However, no attrition allowance was authorized for 1997 and beyond, based on an agreement reached as part of the PBR application. SoCalGas recorded the impact of the Comprehensive Settlement in 1993. Upon giving effect to liabilities previously recognized, the costs of the Comprehensive Settlement, including the restructuring of natural gas supply contracts, did not result in any future charge to earnings. Biennial Cost Allocation Proceeding (BCAP) In the second quarter of 1997, the CPUC issued a decision on SoCalGas' 1996 BCAP filing. In this decision, the CPUC considered SoCalGas' relinquishments of interstate pipeline capacity on both the El Paso and Transwestern pipelines. This resulted in a reduction in the pipeline demand charges allocated to SoCalGas' customers and surcharges allocated to firm capacity holders through pipeline rate-case settlements adopted at the FERC. However, the CPUC and FERC are reviewing the decision. In October 1998, SoCalGas filed 1999 BCAP applications requesting that new rates become effective August 1, 1999 and remain in effect through December 31, 2002. The proposed beginning date follows the conclusion of the Comprehensive Settlement (discussed above), and the proposed end date aligns with the expiration of SoCalGas' PBR. The application seeks overall decreases in natural gas revenues of $204 million. Cost of Capital Under PBR, annual Cost of Capital proceedings were replaced by an automatic adjustment mechanism if changes in certain indices exceed established tolerances. For 1999, SoCalGas is authorized to earn a rate of return on common equity of 11.6 percent and a 9.49 percent return on rate base, the same as in 1998, unless interest-rate changes are large enough to trigger an automatic adjustment as discussed above under "Performance-Based Regulation." Transactions with Affiliates On December 16, 1997, the CPUC adopted rules, effective January 1, 1998, establishing uniform standards of conduct governing the manner in which IOUs conduct business with their energy-related affiliates. The objective of the affiliate-transaction rules is to ensure that these affiliates do not gain an unfair advantage over other competitors in the marketplace and that utility customers do not subsidize affiliate activities. The rules establish standards relating to non-discrimination, disclosure and information exchange, and separation of activities. The CPUC excluded utility-to-utility transactions between SDG&E and SoCalGas from the affiliate-transaction rules in its March 1998 decision approving the business combination of Enova and PE (see Note 1). Other subsidiaries of PE sell and transport natural gas to the Company under tariffs approved by the FERC. Billings for the purchases totaled $252 million in each of the years 1998 and 1997 and $186 million in 1996. The Company has long-term natural gas purchase and transportation agreements with the affiliates extending through the year 2003 requiring certain minimum payments which allow the affiliates to recover the construction cost of their facilities. The Company is obligated to make minimum annual payments to cover the affiliates' operation and maintenance expenses, demand charges paid to their suppliers, current taxes other than income taxes, and debt service costs, including interest expense and scheduled retirement of debt. These long-term agreements were restructured in conjunction with the Comprehensive Settlement described above. During 1998, 1997 and 1996, the Company sold natural gas transportation and storage services to SDG&E in the amount of $55 million to $60 million per year. These sales were at rates established by the CPUC. NOTE 12: SEGMENT INFORMATION The Company has two separately managed reportable segments: natural gas distribution, and natural gas transmission/storage. The accounting policies of the segments are the same as those described in Note 2, and segment performance is evaluated by management based on reported operating income. Intersegment transactions are generally recorded the same as sales or transactions with third parties. Interest expense and income tax expense are not allocated to the reportable segments. Interest revenue ($4 million, $16 million and $5 million for the years ended December 31, 1998, 1997 and 1996, respectively) is included in other income on the Statements of Consolidated Income herein. It is not allocated to the reportable segments and, therefore, is not presented in the tables below. - -------------------------------------------------------------------- For the year ended December 31, (Dollars in millions) 1998 1997 1996 - -------------------------------------------------------------------- Revenues: Distribution $ 2,159 $ 2,283 $ 2,096 Transmission & storage 266 337 343 All other 2 21 (17) ------------------------------------ Total $ 2,427 $ 2,641 $ 2,422 ------------------------------------ Depreciation and amortization: Distribution $ 200 $ 197 $ 193 Transmission & storage 54 54 55 ------------------------------------ Total $ 254 $ 251 $ 248 ------------------------------------ Segment Income: Distribution $ 300 $ 383 $ 379 Transmission & storage 64 87 68 All other -- 22 (16) ------------------------------------ Total segment income 364 492 431 ------------------------------------ Interest expense (80) (87) (86) Income tax expense (128) (178) (148) Nonoperating income 3 11 4 ------------------------------------ Net income $ 159 $ 238 $ 201 ------------------------------------ - -------------------------------------------------------------------- At December 31, or for the year then ended 1998 1997 1996 - -------------------------------------------------------------------- Assets: Distribution $ 2,373 $ 2,946 $ 2,881 Transmission & storage 1,184 1,207 1,211 All other 277 52 262 ------------------------------------ Total $ 3,834 $ 4,205 $ 4,354 ------------------------------------ Capital Expenditures: Distribution $ 92 $ 110 $ 124 Transmission & storage 15 24 29 All other 21 25 44 ------------------------------------ Total $ 128 $ 159 $ 197 ------------------------------------ Geographic Information: Long-lived assets United States $ 2,955 $ 3,077 $ 3,169 - -------------------------------------------------------------------- NOTE 13: SUBSEQUENT EVENT On February 22, 1999, Sempra Energy and KN Energy, Inc. (KN Energy) announced that their respective boards of directors approved Sempra Energy's acquisition of KN Energy, subject to approval by the shareholders of both companies and by various federal and state regulatory agencies. If the transaction is approved, holders of KN Energy common stock will receive 1.115 shares of Sempra Energy common stock or $25 in cash, or some combination thereof, for each share of KN Energy common stock. In the aggregate, the cash portion of the transaction will constitute not more than 30 percent of the total consideration of $1.7 billion. The companies anticipate that the closing will occur in six to eight months. The transaction will be treated as a purchase for accounting purposes. NOTE 14: QUARTERLY FINANCIAL DATA (UNAUDITED)

Item 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE None. PART III ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT The information required on Identification of Directors is incorporated by reference from "Election of Directors" in the Information Statement prepared for the May 1999 annual meeting of shareholders. The information required on the Company's executive officers is set forth in Item 4 herein. ITEM 11. EXECUTIVE COMPENSATION The information required by Item 11 is incorporated by reference from "Election of Directors" and "Executive Compensation" in the Information Statement prepared for the May 1999 annual meeting of shareholders. ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT The information required by Item 12 is incorporated by reference from "Election of Directors" in the Information Statement prepared for the May 1999 annual meeting of shareholders. ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS. None. PART IV ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K (a) The following documents are filed as part of this report: 1. Financial statements Page in This Report Independent Auditors' Report . . . . . . . . . . . . . . 27 Statements of Consolidated Income for the years ended December 31, 1998, 1997 and 1996 . . . . . . . . 28 Consolidated Balance Sheets at December 31, 1998 and 1997. . . . . . . . . . . . . . . . . . . . . 29 Statements of Consolidated Cash Flows for the years ended December 31, 1998, 1997 and 1996 . . . . . 31 Statements of Consolidated Changes in Shareholders' Equity for the years ended December 31, 1998, 1997 and 1996 . . . . . . . . . . . 32 Notes to Consolidated Financial Statements . . . . . . . 33 Quarterly Financial Data (Unaudited) . . . . . . . . . . 50 2. Financial statement schedules None. Schedules for which provision is made in Regulation S-X are not required under the instructions contained therein, are inapplicable, or the information is included in the notes to the Consolidated Financial Statements herein. 3. Exhibits See Exhibit Index on page 53 of this report. (b) Reports on Form 8-K There were no reports on Form 8-K filed after September 30, 1998. 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, hereunto duly authorized. SOUTHERN CALIFORNIA GAS COMPANY By: /s/ Warren I. Mitchell . Warren I. Mitchell Chairman and President Pursuant to the requirements of the Securities Exchange Act of 1934, this report is 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 Officers: Warren I. Mitchell Chairman, President /s/ Warren I. Mitchell March 2, 1999 Principal Financial Officer: Debra L. Reed Senior Vice President, Chief Financial Officer /s/ Debra L. Reed March 2, 1999 Principal Accounting Officer: Debra L. Reed Senior Vice President, Chief Financial Officer /s/ Debra L. Reed March 2, 1999 Directors: Warren I. Mitchell Chairman /s/ Warren I. Mitchell March 2, 1999 Hyla H. Bertea Director /s/ Hyla H. Bertea March 2, 1999 Ann Burr Director /s/ Ann Burr March 2, 1999 Herbert L. Carter Director /s/ Herbert L. Carter March 2, 1999 Richard A. Collato Director /s/ Richard A. Collato March 2, 1999 Daniel W. Derbes Director /s/ Daniel W. Derbes March 2, 1999 Wilford D. Godbold, Jr. Director /s/ Wilford D. Godbold, Jr. March 2, 1999 Robert H. Goldsmith Director /s/ Robert H. Goldsmith March 2, 1999 William D. Jones Director /s/ William D. Jones March 2, 1999 Ignacio E. Lozano, Jr. Director /s/ Ignacio E. Lozano, Jr. March 2, 1999 Ralph R. Ocampo Director /s/ Ralph R. Ocampo March 2, 1999 William G. Ouchi Director /s/ William G. Ouchi March 2, 1999 Richard J. Stegemeier Director /s/ Richard J. Stegemeier March 2, 1999 Thomas C. Stickel Director /s/ Thomas C. Stickel March 2, 1999 Diana L. Walker Director /s/ Diana L. Walker March 2, 1999 EXHIBIT INDEX The Forms 8-K, 10-K and 10-Q referred to herein were filed under Commission File Number 1-14201 (Sempra Energy), Commission File Number 1-40 (Pacific Enterprises) and/or Commission File Number 1-1402 (Southern California Gas Company). Exhibit 3 -- By-Laws and Articles Of Incorporation 3.01 Restated Articles of Incorporation of Southern California Gas Company (Southern California Gas Company 1996 Form 10-K; Exhibit 3.01). 3.02 Bylaws of Southern California Gas Company dated September 1, 1998. Exhibit 4 -- Instruments Defining The Rights Of Security Holders The Company agrees to furnish a copy of each such instrument to the Commission upon request. 4.01 Specimen Preferred Stock Certificates of Southern California Gas Company (Southern California Gas Company 1980 Form 10-K; Exhibit 4.01). 4.02 First Mortgage Indenture of Southern California Gas Company to American Trust Company dated as of October 1, 1940 (Registration Statement No. 2-4504 filed by Southern California Gas Company on September 16, 1940; Exhibit B-4). 4.03 Supplemental Indenture of Southern California Gas Company to American Trust Company dated as of July 1, 1947 (Registration Statement No. 2-7072 filed by Southern California Gas Company on March 15, 1947; Exhibit B-5). 4.04 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). 4.05 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). 4.06 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). 4.07 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). 4.08 Supplemental Indenture of Southern California Gas Company to Wells Fargo Bank, National Association dated as of September 15, 1981 (Pacific Lighting Corporation 1981 Form 10-K; Exhibit 4.25). 4.09 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). 4.10 Supplemental Indenture of Southern California Gas Company to Bankers Trust Company of California, N.A., successor to Wells Fargo Bank, National Association dated as of January 15, 1988 (Pacific Lighting Corporation 1987 Form 10-K; Exhibit 4.11). 4.11 Supplemental Indenture of Southern California Gas Company to First Trust of California, National Association, successor to Bankers Trust Company of California, N.A. dated as of August 15, 1992 (Registration Statement No. 33-50826 filed by Southern California Gas Company on August 13, 1992; Exhibit 4.37). 4.12 Specimen 7 3/4% Series Preferred Stock Certificate (Southern California Gas Company 1992 Form 10-K; Exhibit 4.15). Exhibit 10 -- Material Contracts 10.01 Sempra Energy Supplemental Executive Retirement Plan as amended and restated effective July 1, 1998. (1998 Sempra Energy Form 10-K Exhibit 10.09). 10.02 Sempra Energy Executive Incentive Plan effective June 1, 1998. (1998 Sempra Energy Form 10-K Exhibit 10.11). 10.03 Sempra Energy Executive Deferred Compensation Agreement effective June 1, 1998. (1998 Sempra Energy Form 10-K Exhibit 10.12). 10.04 Sempra Energy 1998 Long Term Incentive Plan (Incorporated by reference from the Registration Statement on Form S-8 Sempra Energy Registration No. 333-56161 dated June 5, 1998 (Exhibit 4.1)). 10.05 Enova Corporation 1986 Long-Term Incentive Plan amended and restated as the Sempra Energy 1986 Long-Term Incentive Plan (Incorporated by reference from the Registration Statement on Form S-8 Sempra Energy Registration No. 333-56161(Exhibit 4.3)). 10.06 Pacific Lighting Corporation Stock Incentive Plan amended and restated as the Sempra Energy Stock Incentive Plan (Incorporated by reference from the Registration Statement on Form S-8 Sempra Energy Registration No. 333-56161 (Exhibit 4.4)). 10.07 Pacific Enterprises Employee Stock Option Plan amended and restated as the Sempra Energy Employee Stock Option Plan (Incorporated by reference from the Registration Statement on Form S-8 Sempra Energy Registration No. 333-56161 (Exhibit 4.5)). 10.08 Restatement and Amendment of Pacific Enterprises 1979 Stock Option Plan (Registration Statement No. 2-66833 filed by Pacific Lighting Corporation on March 5, 1980; Exhibit 1.1). 10.09 Pacific Enterprises Supplemental Medical Reimbursement Plan for Senior Officers (Pacific Lighting Corporation 1980 Form 10-K; Exhibit 10.24). 10.10 Pacific Enterprises Financial Services Program for Senior Officers (Pacific Lighting Corporation 1980 Form 10-K; Exhibit 10.25). 10.11 Southern California Gas Company Retirement Savings Plan, as amended and restated as of August 30, 1988 (Registration Statement No. 33-6357 filed by Pacific Enterprises on December 30, 1988; Exhibit 28.02). 10.12 Southern California Gas Company Statement of Life Insurance, Disability Benefit and Pension Plans, as amended and restated as of January 1, 1985 (Southern California Gas Company 1984 Form 10-K; Exhibit 10.27). 10.13 Southern California Gas Company Pension Restoration Plan For Certain Management Employees (Pacific Lighting Corporation 1980 Form 10-K; Exhibit 10.29). 10.14 Pacific Enterprises Executive Incentive Plan (Pacific Lighting Corporation 1987 Form 10-K; Exhibit 10.13). 10.15 Pacific Enterprises Deferred Compensation Plan for Key Management Employees (Registration Statement No. 33-6357 filed by Pacific Enterprises on December 30, 1988; Exhibit 10.41). 10.16 Pacific Enterprises Stock Incentive Plan (Registration Statement No. 33-21908 filed by Pacific Enterprises on May 17, 1988; Exhibit 4.01). 10.17 Amended and Restated Pacific Enterprises Employee Stock Option Plan (Southern California Gas Company 1996 Form 10-K; Exhibit 10.10). 10.18 Master Affiliate Service Agreement dated as of September 1, 1996 between Southern California Gas Company and Pacific Enterprises Energy Services, as amended (Southern California Gas Company 1996 Form 10-K; Exhibit 10.11). Exhibit 21 -- Subsidiaries 21.01 See Note 1 of the Notes to Consolidated Financial Statements and Management's Discussion and Analysis of Financial Condition and Results of Operations contained in Part II, Items 7 and 8 herein. Exhibit 23 -- Consents Of Experts And Counsel 23.01 Independent Auditors' Consent Exhibit 27 -- Financial Data Schedule 27.01 Financial Data Schedule for the year ended December 31, 1998. GLOSSARY BCAP Biennial Cost Allocation Proceeding Bcf Billion Cubic Feet (of natural gas) CPUC California Public Utilities Commission Enova Enova Corporation EOR Enhanced Oil Recovery FASB Financial Accounting Standards Board FERC Federal Energy Regulatory Commission GCIM Gas Cost Incentive Mechanism GRC General Rate Case IDBs Industrial Development Bonds IOUs Investor-Owned Utilities IT Information Technology Mcf Thousand Cubic Feet (of natural gas) Mmcfd Million Cubic Feet (of natural gas) per day ORA Office of Ratepayer Advocates PBR Performance-Based Ratemaking PE Pacific Enterprises, the Company's parent PRP Potential Responsible Party ROE Return on Equity ROR Rate of Return SDG&E San Diego Gas & Electric Company SEC Securities and Exchange Commission SFAS Statement of Financial Accounting Standards SoCalGas Southern California Gas Company UEG Utility electric generation VaR Value at Risk 55 18

BYLAWS Of SOUTHERN CALIFORNIA GAS COMPANY ____________ ARTICLE I Principal Office SECTION 1. The principal executive office of the Company is located at 555 West Fifth Street, City of Los Angeles, County of Los Angeles, California. ARTICLE II Meetings of Shareholders SECTION 1. All Meetings of Shareholders shall be held either at the principal executive office of the Company or at any other place within or without the state as may be designated by resolution of the Board of Directors. SECTION 2. An Annual Meeting of Shareholders shall be held each year on such date and at such time as may be designated by resolution of the Board of Directors. SECTION 3. At an Annual Meeting of Shareholders, only such business shall be conducted as shall have been properly brought before the Annual Meeting. To be properly brought before an Annual Meeting, business must be (a) specified in the notice of the Annual Meeting (or any supplement thereto) given by or at the direction of the Board of Directors, (b) otherwise properly brought before the Annual Meeting by a Shareholder. For business to be properly brought before an Annual Meeting by a Shareholder, including the nomination of any person (other than a person nominated by or at the direction of the Board of Directors) for election to the Board of Directors, the Shareholder must have given timely and proper written notice to the Secretary of the Company. To be timely, the Shareholder's written notice must be received at the principal executive office of the Company not less than sixty nor more than one hundred twenty days in advance of the date corresponding to the date of the last Annual Meeting; provided, however, that in the event the Annual Meeting to which the Shareholder's written notice relates is to be held on a date which differs by more than sixty days from the date corresponding to the date of the last Annual Meeting, the Shareholder's written notice to be timely must be so received not later than the close of business on the tenth day following the date on which public disclosure of the date of the Annual Meeting is made or given to Shareholders. To be proper, the Shareholder's written notice must set forth as to each matter the Shareholder proposes to bring before the Annual Meeting (a) a brief description of the business desired to be brought before the Annual Meeting, (b) the name and address of the Shareholder as they appear on the Company's books, (c) the class and number of shares of the Company which are beneficially owned by the Shareholder, and (d) any material interest of the Shareholder in such business. In addition, if the Shareholder's written notice relates to the nomination at the Annual Meeting of any person for election to the Board of Directors, such notice to be proper must also set forth (a) the name, age, business address and residence address of each person to be nominated, (b) the principal occupation or employment of each such person, (c) the number of shares of capital stock beneficially owned by each such person, and (d) such other information concerning each such person as would be required under the rules of the Securities and Exchange Commission in a proxy statement soliciting proxies for the election of such person as a Director, and must be accompanied by a consent, signed by each such person, to serve as a Director of the Company if elected. Notwithstanding anything in the Bylaws to the contrary, no business shall be conducted at an Annual Meeting except in accordance with the procedures set forth in this Section 3. SECTION 4. Each Shareholder of the Company shall be entitled to elect voting confidentiality as provided in this Section 4 on all matters submitted to Shareholders by the Board of Directors and each form of proxy, consent, ballot or other written voting instruction distributed by the Company to Shareholders shall include a check box or other appropriate mechanism by which Shareholders who desire to do so may so elect voting confidentiality. All inspectors of election, vote tabulators and other persons appointed or engaged by or on behalf of the Company to process voting instructions (none of whom shall be a Director or Officer of the Company or any of its affiliates) shall be advised of and instructed to comply with this Section 4 and, except as required or permitted hereby, not at any time to disclose to any person (except to other persons engaged in processing voting instructions), the identity and individual vote of any Shareholder electing voting confidentiality; provided, however, that voting confidentiality shall not apply and the name and individual vote of any shareholder may be disclosed to the Company or to any person (i) to the extent that such disclosure is required by applicable law or is appropriate to assert or defend any claim relating to voting or (ii) with respect to any matter for which votes of Shareholders are solicited in opposition to any of the nominees or the recommendations of the Board of Directors unless the persons engaged in such opposition solicitation provide Shareholders of the Company with voting confidentiality (which, if not otherwise provided, will be requested by the Company) comparable in the opinion of the Company to the voting confidentiality provided by this Section 4. ARTICLE III Board of Directors SECTION 1. The Board of Directors shall have power to: a. Conduct, manage and control the business of the Company, and make rules consistent with law, the Articles of Incorporation and the Bylaws; b. Elect, and remove at their discretion, Officers of the Company, prescribe their duties, and fix their compensation; c. Authorize the issue of shares of stock of the Company upon lawful terms: (i) in consideration of money paid, labor done, services actually rendered to the Company or for its benefit or in its reorganization, debts or securities cancelled, and tangible or intangible property actually received either by this Company or by a wholly-owned subsidiary; but neither promissory notes of the purchaser (unless adequately secured by collateral other than the shares acquired or unless permitted by Section 408 of the California Corporations Code) nor future services shall constitute payment or part payment for shares of this Company; or (ii) as a share dividend or upon a stock split, reverse stock split, reclassifications of outstanding shares into shares of another class, conversion of outstanding shares into shares of another class, exchange of outstanding shares for shares of another class or other change affecting outstanding shares; d. Borrow money and incur indebtedness for the purposes of the Company, and cause to be executed and delivered, in the Company name, promissory notes, bonds, debentures, deeds of trust, mortgages, pledges, hypothecations or other evidences of debt; e. Elect an Executive Committee and other committees. SECTION 2. The Board of Directors shall consist of not less than nine nor more than seventeen members. The authorized number of Directors shall be fixed from time to time, within the limits specified, by a resolution duly adopted by the Board of Directors. A majority of the authorized number of Directors shall constitute a quorum of the Board. ARTICLE IV Meeting of Directors SECTION 1. Meetings of the Board of Directors shall be held at any place which has been designated by resolution of the Board of Directors, or by written consent of all members of the Board. In the absence of such designation, regular meetings shall be held in the principal executive office. SECTION 2. Immediately following each Annual Meeting of Shareholders there shall be a regular meeting of the Board of Directors for the purpose of organization, election of Officers and the transaction of other business. In all months other the month in which the Annual Meeting of Shareholders is held there shall be a regular meeting of the Board of Directors on the first Tuesday of each month at such hour as shall be designated by resolution of the Board of Directors. Notice of regular meetings of the Directors shall be given in the manner described in these Bylaws for giving notice of special meetings. No notice of the regular meeting of Board of Directors which follows the Annual Meeting of Shareholders need be given. SECTION 3. Special meetings of the Board of Directors for any purpose may be called at any time by the President, or by any a majority of the authorized number of Directors. Notice of the time and place of special meetings shall be given to each Director. In case notice is mailed or telegraphed, it shall be deposited in the United States mail or delivered to the telegraph company in the city in which the principal executive office is located at least twenty hours prior to the time of the meeting. In case notice is given personally or by telephone, it shall be delivered at least six hours prior to the time of the meeting. SECTION 4. The transactions of any meeting of the Board of Directors, however called or noticed, shall be as valid as though in a meeting duly held after regular call and notice if a quorum be present and each of the Directors, either before or after the meeting, signs a written waiver of notice, a consent to holding such meeting, or an approval of the minutes thereof or attends the meeting without protesting, prior thereto or at its commencement, the lack of notice to such Director. All such waivers, consents or approvals shall be made a part of the minutes of the meeting. SECTION 5. If any regular meeting of Shareholders or of the Board of Directors falls on a legal holiday, then such meeting shall be held on the next succeeding business day at the same hour. But a special meeting of Shareholders or Directors may be held upon a holiday with the same force and effect as if held upon a business day. ARTICLE V Officers SECTION 1. The Officers of the Company shall be a President, Vice Presidents, one or more of whom, in the discretion of the Board of Directors, may be appointed Executive or Senior Vice President, a Secretary and a Treasurer. The Company may have, at the discretion of the Board of Directors, any other Officers and may also have, at the discretion of and upon appointment by the President, one or more Assistant Secretaries and Assistant Treasurers. One person may hold two or more offices. ARTICLE VI The President SECTION 1. The President shall be the principal executive officer of the Company, shall have general charge of all of the Company's business and affairs and all of its Officers and shall have all of the powers and perform all of the duties inherent in that office and such additional powers and duties as may be prescribed by the Board of Directors. ARTICLE VII Vice Presidents SECTION 1. In the President's absence or disability, the Vice Presidents in order of their rank shall perform all of the duties of the President and when so acting shall have all of the powers and be subject to all of the restrictions of the President. The Vice Presidents shall have such other powers and perform such additional duties as may be prescribed by the Board of Directors or the President. ARTICLE VIII Secretary SECTION 1. The Secretary shall keep at the principal executive office, a book of minutes of all meetings of Directors and Shareholders, which shall contain a statement of the time and place of the meeting, whether it was regular or special, and if special, how authorized and the notice given, the names of those present at Directors' meetings, the number of shares present or represented by written proxy at Shareholders' meetings and the proceedings. SECTION 2. The Secretary shall give notice of all meetings of Shareholders and the Board of Directors required by the Bylaws or by law to be given, and shall keep the seal of the Company in safe custody. The Secretary shall have such other powers and perform such additional duties as may be prescribed by the Board of Directors or the President. SECTION 3. It shall be the duty of the Assistant Secretaries to help the Secretary in the performance of the Secretary's duties. In the absence or disability of the Secretary, the Secretary's duties may be performed by an Assistant Secretary. ARTICLE IX Treasurer SECTION 1. The Treasurer shall have custody and account for all funds or moneys of the Company which may be deposited with the Treasurer, or in banks, or other places of deposit. The Treasurer shall disburse funds or moneys which have been duly approved for disbursement. The Treasurer shall sign notes, bonds or other evidences of indebtedness for the Company as the Board of Directors may authorize. The Treasurer shall have such other powers and perform such additional duties as may be prescribed by the Board of Directors or the President. SECTION 2. It shall be the duty of the Assistant Treasurers to help the Treasurer in the performance of the Treasurer's duties. In the Treasurer's absence or disability, the Treasurer's duties may be performed by an Assistant Treasurer. ARTICLE X Record Date SECTION 1. The Board of Directors may fix a time in the future as a record date for ascertaining the Shareholders entitled to notice and to vote at any meeting of Shareholders, to give consent to corporate action in writing without a meeting, to receive any dividend, distribution, or allotment of rights or to exercise rights related to any change, conversion, or exchange of shares. The selected record date shall not be more than sixty nor less than 10 days prior to the date of the Meeting nor more than sixty days prior to any other action or event for the purposes for which it is fixed. When a record date is fixed, only Shareholders of Record on that date are entitled to notice and to vote at the Meeting, to give consent to corporate action, to receive a dividend, distribution, or allotment of rights, or to exercise any rights in respect of any other lawful action, notwithstanding any transfer of shares on the books of the Company after the record date. ARTICLE XI Indemnification of Agents of the Company; Purchase of Liability Insurance SECTION 1. For the purposes of this Article, "agent" means any person who is or was a Director, Officer, employee or other agent of the Company, or is or was serving at the request of the Company as a director, officer, employee or agent of another foreign or domestic corporation, partnership, joint venture, trust or other enterprise, or was a director, officer, employee or agent of a foreign or domestic corporation which was a predecessor corporation of the Company or of another enterprise at the request of such predecessor corporation; "proceeding" means any threatened, pending or completed action or proceeding, whether civil, criminal, administrative, or investigative; and "expenses" includes, without limitation, attorneys' fees and any expenses of establishing a right to indemnification under Section 4 or paragraph (d) of Section 5 of this Article. SECTION 2. The Company shall indemnify any person who was or is a party, or is threatened to be made a party, to any proceeding (other than an action by or in the right of the Company to procure a judgment in its favor) by reason of the fact that such person is or was an agent of the Company, against expenses, judgments, fines, settlements and other amounts actually and reasonably incurred in connection with such proceeding if such person acted in good faith and in a manner such person reasonably believed to be in the best interests of the Company, and, in the case of a criminal proceeding, had no reasonable cause to believe the conduct of such person was unlawful. The termination of any proceeding by judgment, order, settlement, conviction or upon a plea of nolo contendere or its equivalent shall not, of itself, create a presumption that the person did not act in good faith and in a manner which the person reasonably believed to be in the best interests of the Company or that the person had reasonable cause to believe that the person's conduct was unlawful. SECTION 3. The Company shall indemnify any person who was or is a party or is threatened to be made a party to any threatened, pending or completed action by or in the right of the Company to procure a judgment in its favor by reason of the fact that such person is or was an agent of the Company, against expenses actually and reasonably incurred by such person in connection with the defense or settlement of such action if such person acted in good faith and in a manner such person believed to be in the best interests of the Company and its Shareholders. No indemnification shall be made under this Section 3 for any of the following: a. In respect of any claim, issue or matter as to which such person shall have been adjudged to be liable to the Company in the performance of such person's duty to the Company and its Shareholders, unless and only to the extent that the court in which such proceeding is or was pending shall determine upon application that, in view of all the circumstances of the case, such person is fairly and reasonably entitled to indemnity for expenses and then only to the extent that the court shall determine; b. Of amounts paid in settling or otherwise disposing of a pending action without court approval; c. Of expenses incurred in defending a pending action which is settled or otherwise disposed of without court approval. SECTION 4. To the extent that an agent of the Company has been successful on the merits in defense of any proceeding referred to in Section 2 or 3 or in defense of any claim, issue or matter therein, the agent shall be indemnified against expenses actually and reasonably incurred by the agent in connection therewith. SECTION 5. Except as provided in Section 4, any indemnification under this Article shall be made by the Company only if authorized in the specific case, upon a determination that indemnification of the agent is proper in the circumstances because the agent has met the applicable standard of conduct set forth in Section 2 or 3, by any of the following: a. A majority vote of a quorum consisting of Directors who are not parties to such proceeding; b. If such a quorum of Directors is not obtainable, by independent legal counsel in a written opinion; c. Approval of the Shareholders, with the shares owned by the person to be indemnified not being entitled to vote thereon; d. The court in which such proceeding is or was pending upon application made by the Company or the agent or the attorney or other person rendering services in connection with the defense, whether or not such application by the agent, attorney or other person is opposed by the Company. SECTION 6. Expenses incurred in defending any proceeding may be advanced by the Company prior to the final disposition of such proceeding upon receipt of an undertaking by or on behalf of the agent to repay such amount if it shall be determined ultimately that the agent is not entitled to be indemnified as authorized in this Article. SECTION 7. The indemnification provided by this Article shall not be deemed exclusive of any other rights to which those seeking indemnification may be entitled under any agreement, vote of Shareholders or disinterested Directors or otherwise, to the extent such additional rights to indemnification are authorized in the Articles of Incorporation of the Company. The rights to indemnity under this Article shall continue as to a person who has ceased to be a Director, Officer, employee, or agent and shall inure to the benefit of the heirs, executors and administrators of the person. SECTION 8. No indemnification or advance shall be made under this Article, except as provided in Section 4 or paragraph (d) of Section 5, in any circumstance where it appears: a. That it would be inconsistent with a provision of the Articles of Incorporation, these Bylaws, a resolution of the Shareholders or an agreement in effect at the time of the accrual of the alleged cause of action asserted in the proceeding in which the expenses were incurred or other amounts were paid, which prohibits or otherwise limits indemnification; b. That it would be inconsistent with any condition expressly imposed by a court in approving a settlement. SECTION 9. The Company shall have the power to purchase and maintain insurance on behalf of any agent of the Company against any liability asserted against or incurred by the agent in such capacity or arising out of the agent's status as such whether or not the Company would have the power to indemnify the agent against such liability under the provisions of this Article. SECTION 10. This Article does not apply to any proceeding against any trustee, investment manager or other fiduciary of an employee benefit plan in such person's capacity as such, even though such person may also be an agent of the Company as defined in Section 1. Nothing contained in this Article shall limit any right to indemnification to which such a trustee, investment manager or other fiduciary may be entitled by contract or otherwise, which shall be enforceable to the extent permitted by applicable law. BYLAWS OF SOUTHERN CALIFORNIA GAS COMPANY September 1, 1998 O:\USER\SJS\BLAWS-SC

UT THE SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM THE CONDENSED STATEMENT OF CONSOLIDATED INCOME, BALANCE SHEET AND CASH FLOWS AND IS QUALIFIED IN ITS ENTIRETY BY REFERENCE TO SUCH FINANCIAL STATEMENTS. 0000092108 SOUTHERN CALIFORNIA GAS COMPANY 1,000,000 YEAR DEC-31-1998 DEC-31-1998 PER-BOOK 2,952 0 698 184 0 3,834 835 0 525 1,360 0 22 967 0 0 0 75 0 0 0 1,410 3,834 2,427 126 2,063 2,189 238 1 239 80 159 1 158 165 0 782 0 0

EXHIBIT 23.01 INDEPENDENT AUDITORS' CONSENT We consent to the incorporation by reference in Registration Statement Nos. 333-45537, 33-51322, 33-53258, 33-59404, and 33- 52663 of Southern California Gas Company on Forms S-3 of our report dated January 27, 1999, except for Note 13 as to which the date is February 22, 1999, appearing in this Annual Report on Form 10-K of Southern California Gas Company for the year ended December 31, 1998. /s/ DELOITTE & TOUCHE LLP San Diego, California March 31, 1999