Annual Report (Form 10-K), fiscal year 1994

ITEM 1. BUSINESS
Southern California Gas Company (The Gas Company or the Company) is a public utility owning and operating a natural gas distribution, transmission and storage system that supplies natural gas in 535 cities and communities throughout a 23,000-square mile service territory comprising most of southern California and parts of central California. The Gas Company is the principal subsidiary of Pacific Enterprises (the "Parent").
The Gas Company is the nation's largest natural gas distribution utility. It serves approximately 17 million residential, commercial, industrial, utility electric generation and wholesale customers through approximately 4.7 million meters in its service territory. Most of those meters represent "core" customers, which are primarily residential and small commercial and industrial accounts. The Gas Company's "noncore" customers are served by over 1,200 meters. Noncore customers consist of large-volume gas users such as electric utilities, wholesale and large commercial and industrial customers.
The Company is subject to regulation by the California Public Utilities Commission (CPUC) which, among other things, establishes rates the Company may charge for gas service, including an authorized rate of return on investment. Under current ratemaking policies, the Company's future earnings and cash flow will be determined primarily by the allowed rate of return on common equity, the growth in rate base, noncore market pricing and the variance in gas volumes delivered to noncore customers versus CPUC-adopted forecast deliveries and the ability of management to control expenses and investment in line with the amounts authorized by the CPUC to be collected in rates. The impact of any future regulatory restructuring, such as performance based ratemaking ("PBR") (See "Rates and Regulation"), and increased competitiveness in the industry, including the continuing threat of customers bypassing the Company's system and obtaining service directly from interstate pipelines, and electric industry restructuring, may also affect the Company's performance.
For 1995, the CPUC has authorized the Company to earn a rate of return on rate base of 9.67 percent and a 12.00 percent rate of return on common equity compared to 9.22 percent and 11.00 percent, respectively, in 1994. Growth in rate base for 1994 was approximately 3 percent. Rate base is expected to remain at the same level in 1995. The Company has achieved or exceeded its authorized rate of return on rate base for the last twelve consecutive years.
The Gas Company was incorporated in California in 1910. Its principal executive offices are located at 555 West Fifth Street, Los Angeles, California 90013 and its telephone number is (213) 244-1200.
OPERATING STATISTICS
The following table sets forth certain operating statistics of the Company from 1990 through 1994.
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OPERATING STATISTICS
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SERVICE AREA
The Gas Company distributes natural gas throughout a 23,000-square mile service territory with a population of approximately 17 million people. As indicated by the following map, its service territory includes most of southern California and parts of central California.
[MAP OF THE GAS COMPANY'S SERVICE TERRITORY]
Natural gas service is also provided on a wholesale basis to the distribution systems of the City of Long Beach, San Diego Gas & Electric Company and Southwest Gas Company.
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UTILITY SERVICES
The Gas Company's customers are separated, for regulatory purposes, into core and noncore customers. Core customers are primarily residential and small commercial and industrial customers, without alternative fuel capability. Noncore customers primarily include utility electric generation, wholesale and large commercial and industrial customers. Noncore customers are sensitive to the price relationship between natural gas and alternate fuels, and are capable of readily switching from one fuel to another, subject to air quality regulations.
The Gas Company offers two basic utility services, sale of gas and transmission of gas. Residential customers and most other core customers purchase gas directly from The Gas Company. Noncore customers and large core customers have the option of purchasing gas either from The Gas Company or from other sources (such as brokers or producers) for delivery through the Company's transmission and distribution system. Smaller customers are permitted to aggregate their gas requirements and also to purchase gas directly from brokers or producers, up to a limit of 10 percent of the Company's core market. The Gas Company generally earns the same margin whether the Company buys the gas and sells it to the customer or transports gas already owned by the customer. (See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations-Operating Results.")
The Gas Company continues to be obligated to purchase reliable supplies of natural gas to serve the requirements of its core customers. However, the only gas supplies that the Company may offer for sale to noncore customers are the same supplies that it purchases to serve its core customers.
The Gas Company also provides a gas storage service for noncore customers on a bid basis. The storage service program provides opportunities for customers to store gas on an "as available" basis during the summer to reduce winter purchases when gas costs are generally higher, or to reduce their level of winter curtailment in the event temperatures are unusually cold. During 1994, The Gas Company stored approximately 24 billion cubic feet of customer-owned gas.
DEMAND FOR GAS
Natural gas is a principal energy source in the Company's service area for residential, commercial and industrial uses as well as utility electric generation (UEG) requirements. Gas competes with electricity for residential and commercial cooking, water heating and space heating uses, and with other fuels for large industrial, commercial and UEG uses. Demand for natural gas in southern California is expected to continue to increase but at a slower rate due primarily to a slowdown in housing starts, new energy efficient building construction and appliance standards and general recessionary business conditions.
During 1994, 97 percent of residential energy customers in the Company's service territory used natural gas for water heating and 94 percent for space heating. Approximately 78 percent of those customers used natural gas for cooking and 72 percent for clothes drying.
Demand for natural gas by noncore customers such as large volume commercial, industrial and electric generating customers is very sensitive to the price of alternative competitive fuels. These customers number only approximately 1,200; however, during 1994, they accounted for approximately 17 percent of total gas revenues, 67 percent of total gas volumes delivered and 14 percent of the authorized gas margin. Changes in the cost of gas or alternative fuels, primarily fuel oil, can result in significant shifts in this market, subject to air quality regulations. Demand
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for gas for UEG use is also affected by the price and availability of electric power generated in other areas and purchased by the Company's UEG customers.
COMPETITION
Since interstate pipelines began operations in The Gas Company's service territories, the Company's throughput to customers in the Kern County area who use natural gas to produce steam for enhanced oil recovery projects has decreased significantly because of the bypass of the Company's system. The decrease in revenues from enhanced oil recovery customers is subject to full balancing account treatment, except for a five percent incentive to the Company for attaining certain throughput levels, and therefore, does not have a material impact on earnings. However, bypass of other Company markets also may occur. The Company is fully at risk for lost noncore volumes due to competition, and would not receive balancing account treatment except in the enhanced oil recovery market.
In order to respond to certain bypass threats, the Company has received authorization from the CPUC for expedited review of price discounts proposed for long-term gas transportation contracts with some noncore customers. The CPUC has also approved changes in the methodology for allocating the Company's costs between core and noncore customers to reduce the subsidization of core customer rates by noncore customers. These decisions have resulted in a reduction of noncore rates and a corresponding increase in core rates that better reflects the cost of serving each customer class and, together with price discounting authority, has enabled the Company to better compete with new interstate pipelines for noncore customers. In addition, in August 1993 a capacity brokering program was implemented. Under the program, for a fee, the Company provides to noncore customers, or others, a portion of its control of interstate pipeline capacity to allow more direct access to producers. Also, the Comprehensive Settlement (See "Item 7. Management's Discussion and Analysis of Financial Condition and Result of Operations - Ratemaking Procedures - Comprehensive Settlement of Regulatory Issues.") will help improve the Company's competitiveness by reducing the cost of transportation service to noncore customers.
Historically, environmental laws have favorably impacted the use of natural gas in the Company's service territory, particularly by utility electric generation customers. However, increasingly complex administrative requirements may discourage natural gas use by large commercial and industrial customers.
In April 1994, the CPUC announced it would review the structure of California's electric utility service, a review that could lead to significant changes in the way investor-owned utilities conduct business, including the amount of electricity purchased from out-of-state suppliers. The CPUC's proposed deregulation of electricity sales by the year 2002 may affect the future volumes of natural gas the Company transports for electric utilities. Utility electric generation customers currently account for 26 percent of the Company's annual throughput. See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operation - Factors Influencing Future Performance - Electric Industry Restructuring."
SUPPLIES OF GAS
In 1994, The Gas Company delivered approximately 1 trillion cubic feet of natural gas through its system. Approximately 65 percent of these deliveries were customer-owned gas for which The Gas Company provided transportation services, compared to 64 percent in 1993. The balance of gas deliveries was gas purchased by The Gas Company and resold to customers.
Most of the natural gas delivered by The Gas Company is produced outside of California. These supplies are delivered to the California border by interstate pipeline companies
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(primarily El Paso Natural Gas Company and Transwestern Natural Gas Company) that provide transportation services for supplies purchased from other sources by The Gas Company or its transportation customers. These supplies enter The Gas Company's intrastate transmission system at the California border for delivery to customers.
The Gas Company currently has paramount rights to daily deliveries of up to 2,200 million cubic feet of natural gas over the interstate pipeline systems of El Paso Natural Gas Company (up to 1,450 million cubic feet) and Transwestern Pipeline Company (up to 750 million cubic feet). The rates that interstate pipeline companies may charge for gas and transportation services and other terms of service are regulated by the Federal Energy Regulatory Commission (FERC).
Existing interstate pipeline capacity into California exceeds current demand by over 1 billion cubic feet per day. Up to 2 billion cubic feet per day of capacity on the El Paso and Transwestern interstate pipeline systems, representing over $175 million and $55 million, respectively, of reservation charges annually, may be relinquished within the next few years based on existing contract reduction options and contract expirations. Some of this capacity may not be resubscribed. Current FERC regulation could permit costs of unsubscribed capacity to be allocated to remaining firm service customers, including The Gas Company. Under existing regulation in California, the Company would have the opportunity to include its portion of any such reallocated costs in its rates. If competitive conditions did not support higher rates resulting from these reallocated costs, then the Company would be at risk for lost revenues in the noncore market.
The Company, as a part of a coalition of customers who hold 90 percent of the firm transportation capacity rights on the El Paso and Transwestern systems, has offered a proposal for market based rates with balanced incentives to El Paso and Transwestern to resolve the issue of unsubscribed capacity. See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Factors Influencing Future Performance - Excess Interstate Pipeline Capacity."
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The following table sets forth the sources of gas deliveries by The Gas Company from 1990 through 1994.
SOURCES OF GAS --------------
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Market sensitive 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 approximately 64 percent of total gas volumes purchased by the Company during 1994, as compared with 66 percent and 61 percent, respectively, during 1993 and 1992. These supplies were generally purchased at prices significantly below those for other long-term sources of supply.
On March 16, 1994, the CPUC approved a new process for evaluating the Company's gas purchases substantially replacing the previous process of reasonableness reviews. The new "Gas Cost Incentive Mechanism" ("GCIM") is a three-year pilot program that began in April 1994. The GCIM essentially compares the Company's cost of gas with a benchmark level. See "Item 7. "Management's Discussion and Analysis of Financial Condition and Results of Operations - Ratemaking Procedures - GCIM."
The Gas Company estimates that sufficient natural gas supplies will be available to meet the requirements of its customers into the next century.
RATES AND REGULATION
The Gas Company is regulated by the CPUC. The CPUC consists of five commissioners appointed by the Governor of California for staggered six-year terms. It is the responsibility of the CPUC to determine that utilities operate in the best interest of the ratepayer with an opportunity to earn a reasonable profit. The regulatory structure is complex and has a very substantial impact on the profitability of the Company.
Under current ratemaking procedures, the return that the Company is authorized to earn is the product of an authorized rate of return on rate base and the amount of rate base. Rate base consists primarily of net investment in utility plant. Thus, the Company's earnings are affected by changes in the authorized rate of return on rate base and the growth in rate base and by the Company's ability to control expenses and investment in rate base within the amounts authorized by the CPUC in setting rates. In addition, the Company's ability to achieve its authorized rate of return is affected by other regulatory and operating factors. See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Ratemaking Procedures."
The Gas Company's operating and fixed costs, including return on rate base, are allocated between core and noncore customers under a methodology that is based upon the costs incurred in serving these customer classes. For 1995, approximately 89 percent of the CPUC-authorized gas margin has been allocated to core customers and 11 percent to noncore customers, including wholesale customers. Under the current regulatory framework, costs may be reallocated between the core and the noncore customer classes once every other year in a biennial cost allocation proceeding (BCAP).
During 1994, the Company began exploring a new approach for setting rates to its customers known as "Performance Based Ratemaking." This new approach, PBR, would maintain cost based rates but would link financial performance with increases and decreases in productivity and generally would allow for rates to increase by the rate of inflation, less an agreed upon adjustment for productivity improvements. The Gas Company proposes to file a PBR application with the CPUC in 1995, and if approved, the change would not take effect until January 1, 1997, at the earliest. Although PBR could result in increased earnings volatility, the Company would have the opportunity to improve financial performance to the extent it was able to reduce expenses, increase energy deliveries and generate profits from new products and
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services. See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations--Factors Influencing Future Performance."
ENVIRONMENTAL MATTERS
The Gas Company has identified and reported to California environmental authorities 42 former gas manufacturing sites for which it (together with other utilities as to 21 of the sites) may have remedial obligations under environmental laws. As of December 31, 1994, eight of the sites have been remediated, of which five have received certification from the California Environmental Protection Agency. Preliminary investigations, at a minimum, have been completed on thirty-three of the sites, including those sites at which the remediations described above have been completed. In addition, the Company is one of a large number of major corporations that have been identified as a potentially responsible party for environmental remediation of three industrial waste disposal sites and a landfill site. These 46 sites are in various stages of investigation or remediation. It is anticipated that the investigation, and if necessary, remediation of these sites will be completed over a period of from ten years to twenty years.
In May 1994, the CPUC approved a collaborative settlement between the Company and other California utilities and the Division of Ratepayer Advocates which provides for rate recovery of 90 percent of environmental investigation and remediation costs without reasonableness review. In addition, the utilities have the opportunity to retain a percentage of any insurance recovery to offset the 10 percent of costs not recovered in rates.
At December 31, 1994, the Company's estimated remaining liability for investigation and remediation for the 46 sites was approximately $65 million, which it is authorized to recover through the rate recovery mechanism described above. The estimated liability is subject to future adjustment pending further investigation. See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operation - Factors Influencing Future Performance - Environmental Matters." Because of the current and expected rate recovery, the Company believes that compliance with environmental laws and regulations will not have a material adverse effect on its financial statements.
EMPLOYEES
The Company employs approximately 8,200 persons. Most field, clerical and technical employees of the Company are represented by the Utility Workers' Union of America or the International Chemical Workers' Union. Collective bargaining agreements covering these approximately 5,560 employees expire with respect to wages and working conditions on March 31, 1996 and with respect to medical benefits on December 31, 1995. The agreement with respect to all benefits except medical expires on March 31, 1995, and the Company is currently in the process of negotiating a new agreement.
In order to enhance its overall competitiveness, the Company has also continued to downsize. In 1994, approximately 800 positions were eliminated and the Company expects to eliminate another 300-500 positions in 1995 as a result of efficiency and productivity improvements, and more reductions will result from organizational realignment. In addition, the Company has a competitive benchmarking program that compares the costs of retaining certain support functions versus outsourcing them. Functions which cannot be performed at competitive rates may be contracted to outside providers.
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MANAGEMENT
The executive officers of Southern California Gas Company are as follows:
All of the Company's executive officers have been employed by the Company, the Parent, or its affiliates in management positions for more than the past five years, except for Mr. Arriola. From 1987 until joining the Company in August 1994, Mr. Arriola was a Vice President of Bank of America NT&SA (1992-1994) and a Vice President of Security Pacific National Bank (1987-1992).
Executive officers are elected annually and serve at the pleasure of the Board of Directors. There are no family relationships among any of the Company's executive officers.
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ITEM 2.



ITEM 2. PROPERTIES
At December 31, 1994, The Gas Company owned approximately 3,040 miles of transmission and storage pipeline, 42,683 miles of distribution pipeline and 42,647 miles of service piping. It also owned 13 transmission compressor stations and 6 underground storage reservoirs (with a combined working storage capacity of approximately 116 billion cubic feet) and general office buildings, shops, service facilities, and certain other equipment necessary in the conduct of its business.
Southern California Gas Tower, a wholly-owned subsidiary of The Gas Company, has a 15 percent limited partnership interest in a 52-story office building in downtown Los Angeles. The Gas Company occupies about half of the building.
ITEM 3.

ITEM 3. LEGAL PROCEEDINGS
Except for the matters referred to in the financial statements filed with or incorporated by reference in Item 8 or referred to elsewhere in this Annual Report, neither the Company nor any of its subsidiaries is a party to, nor is their property the subject of, any material pending legal proceedings other than routine litigation incidental to their businesses.
ITEM 4.

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
No matters were submitted during the fourth quarter of 1994 to a vote of the Company's security holders.
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PART II
ITEM 5.

ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
The Parent owns all of the Company's Common Stock. The information required by this item concerning dividends declared is included in the Statement of Consolidated Shareholders' Equity set forth in Item 8 of this Annual Report. Such information is incorporated herein by reference.
RANGE OF MARKET PRICES OF PREFERRED STOCK
Market prices for the preferred stock were obtained from the Pacific Stock Exchange. (The 7 3/4% preferred stock began trading in April 1993 therefore, estimates for the first quarter were obtained from the underwriter). The 6% Preferred Stock and the Flexible Auction Series Preferred Stock, Series A and Series C are not listed on any exchange.
ITEM 6.

ITEM 6. SELECTED FINANCIAL DATA
The following table sets forth certain selected financial data of the Company for 1990 through 1994.
SELECTED FINANCIAL DATA
The Gas Company's parent, Pacific Enterprises, owns 96 percent of the voting stock, including all of the issued and outstanding common stock; therefore, per share data have been omitted.
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ITEM 7.

ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Southern California Gas Company (the "Company") is a subsidiary of Pacific Enterprises (the "Parent"). The Company, a public utility, provides natural gas distribution, transmission and storage in a 23,000-square mile service area in southern California and parts of central California. This section includes management's analysis of operating results from 1992 through 1994, and is intended to provide additional information about the Company's financial performance. This section also focuses on major factors expected to influence future operating results and discusses future investment and financing plans. This section should be read in conjunction with the Consolidated Financial Statements set forth in Item 8.


ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
STATEMENT OF CONSOLIDATED INCOME
SEE NOTES TO CONSOLIDATED FINANCIAL STATEMENTS.
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CONSOLIDATED BALANCE SHEET
SEE NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
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STATEMENT OF CONSOLIDATED CASH FLOWS
SEE NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
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STATEMENT OF CONSOLIDATED SHAREHOLDERS' EQUITY
The number of shares of preferred stock and common stock authorized and outstanding at December 31, 1994 and 1993, is set forth in Note 9 of Notes to Consolidated Financial Statements.
SEE NOTES TO CONSOLIDATED FINANCIAL STATEMENTS.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Southern California Gas Company (the "Company") is a subsidiary of Pacific Enterprises ("Parent"). The Parent owns approximately 96 percent of the Company's voting stock, including all of its issued and outstanding common stock; therefore, per share data have been omitted.
PRINCIPLES OF CONSOLIDATION
The consolidated financial statements include the accounts of the Company and its wholly-owned subsidiary, Southern California Gas Tower. The subsidiary has a 15 percent limited partnership interest in a 52-story office building in which the Company occupies approximately one-half of the leasable space. Investments in 50 percent or less joint ventures and partnerships are accounted for by the equity or cost method, as appropriate.
RECLASSIFICATIONS
Certain changes in account classification have been made in the prior years' consolidated financial statements to conform to the 1994 financial statement presentation.
REGULATION
The Company is a public utility and follows accounting policies prescribed or authorized by the California Public Utilities Commission (CPUC). The Company applies the provisions of Statement of Financial Accounting Standards No. 71, "Accounting for the Effects of Certain Types of Regulation." This statement requires cost-based rate regulated entities that meet certain criteria to reflect the authorized recovery of costs due to regulatory decisions in their financial statements.
GAS IN STORAGE
Gas in storage inventory is stated at last-in, first-out (LIFO) cost. As a result of the regulatory accounting procedure, the pricing of gas in storage does not have any effect on net income. If the first-in, first-out (FIFO) method of accounting for gas in storage inventory had been used by the Company, inventory would have been higher than reported at December 31, 1994 and 1993 by $34 million and $58 million, respectively. Materials and supplies are generally stated at the lower of cost, determined on an average cost basis, or market.
UTILITY PLANT
The cost of additions, renewals and improvements to utility plant are charged to the appropriate plant accounts. These costs include labor, material, other direct costs, indirect charges and an allowance for funds used during construction. The cost of utility plant retired or otherwise disposed of, plus removal costs and less salvage, is charged to accumulated depreciation. Depreciation is recorded on the straight-line remaining life basis.
REGULATORY ACCOUNTS RECEIVABLE - NET
Authorized regulatory balancing accounts are maintained to accumulate undercollections and overcollections from the revenue and cost estimates adopted by the CPUC in setting rates. The Company makes periodic filings with the CPUC to adjust future gas rates to account for such variances.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION (AFUDC)
AFUDC represents the cost of funds used to finance the construction of utility plant and is added to the cost of utility plant. Interest expense of $4 million in 1994, $7 million in 1993 and $6 million in 1992 was capitalized.
OTHER
Cash equivalents include short-term investments purchased with maturities of less than 90 days. Other major accounting policies are included in the following notes.
2. REGULATORY MATTERS
RESTRUCTURING OF GAS SUPPLY CONTRACTS
In 1993, the Company and its gas supply affiliates restructured long-term gas supply contracts with suppliers of California offshore and Canadian gas. In the past, the Company's cost of these supplies had been substantially in excess of its average delivered cost of gas for all gas supplies.
The restructured contracts substantially reduced the ongoing delivered costs of these gas supplies and provided lump sum payments totaling $391 million to the suppliers. The expiration date for the Canadian gas supply contract was also shortened from 2012 to 2003.
COMPREHENSIVE SETTLEMENT OF REGULATORY ISSUES
On July 20, 1994, the CPUC approved a comprehensive settlement (Comprehensive Settlement) of a number of pending regulatory issues including rate recovery of a significant portion of the restructuring costs associated with long-term gas supply contracts discussed above. The Comprehensive Settlement permits the Company 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, over a period of approximately five years. In addition to the gas supply issues, the Comprehensive Settlement addresses the following other regulatory issues:
NONCORE CUSTOMER RATES. The Comprehensive Settlement changed the procedures for determining noncore rates to be charged by the Company to its customers for the five-year period commencing August 1, 1994. Rates charged to the customers are established based upon the Company's recorded throughput to these customers for 1991. The Company 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. The Company's ability to report as earnings the results from revenues in excess of its authorized return from noncore customers due to volume increases has been substantially eliminated for the five years beginning August 1, 1994 as a consequence of the Comprehensive Settlement described above. This is because forecasted deliveries in excess of the 1991 throughput levels used to establish noncore rates were contemplated in estimating the costs of the Comprehensive Settlement at December 31, 1993.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
REASONABLENESS REVIEWS. The Comprehensive Settlement includes settlement of all pending reasonableness reviews with respect to the Company's gas purchases from April, 1989 through March, 1992 as well as certain other future reasonableness review issues. The Comprehensive Settlement also allows recovery of future excess interstate pipeline capacity costs in the Company's rates.
GAS COST INCENTIVE MECHANISM. On March 16, 1994, the CPUC approved a new process for evaluating the Company's gas purchases, substantially replacing the previous process of reasonableness reviews. The new Gas Cost Incentive Mechanism (GCIM) is a three-year pilot program beginning April 1, 1994. The GCIM essentially compares the Company's cost of gas with a benchmark level, which is the average market price of 30-day firm spot supplies delivered to the Company's service area.
All savings from gas purchased below the benchmark are shared equally between ratepayers and shareholders. The Company can recover all costs in excess of the benchmark but within a tolerance band. If the Company's cost of gas exceeds the tolerance band, then the excess costs will be shared equally between ratepayers and shareholders. For the first year of the program, the GCIM provides a 4.5 percent tolerance band above the benchmark. For the second and third years of the program, the tolerance band decreases to 4.0 percent. In 1994, since the inception of the GCIM, the Company's gas purchases were within the tolerance band (See Note 8).
ATTRITION ALLOWANCES. The Comprehensive Settlement authorizes the Company annual allowances for operational attrition for 1995 and 1996 to the extent that the annual inflation rate for those years exceeds 2 percent and 3 percent, respectively, for operating and maintenance expenses. This compares to a 3 percent productivity adjustment authorized for 1994. The rate base attrition will continue based upon a three year rolling average of recorded net utility plant additions. This is a departure from past regulatory practice of allowing recovery of the full effect of inflation on operating and maintenance expenses in rates. The Company intends to continue to attempt to control operating expenses and investment in those years to amounts authorized in rates to offset the effect of this regulatory change.
The Company recorded the impact of the Comprehensive Settlement in 1993 and, upon giving effect to liabilities previously recognized at the Company, the costs of the Comprehensive Settlement, including the restructuring of gas supply contracts, did not result in any additional charge to the Company's consolidated earnings.
Regulatory Accounts Receivable-Net and Regulatory Assets include a total of approximately $327 million and $465 million in 1994 and 1993 respectively, for the recovery of costs as provided in the Comprehensive Settlement. At December 31, 1993, Accounts Payable-Other included the remaining liability for settlement payments of $375 million, which were paid in 1994, to restructure the long-term gas supply contracts. The CPUC authorized the borrowing of up to $425 million primarily to provide for funds needed under the Comprehensive Settlement. As of December 31, 1994, the Company has $524 million in commercial paper outstanding, of which $330 million relates to the Comprehensive Settlement (See Note 6).
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
3. INCOME TAXES
In 1992, the Company adopted Statement of Financial Accounting Standards No. 109, "Accounting for Income Taxes," the effect of which was not material to the financial statements.
A reconciliation of the difference between computed statutory federal income tax expense and actual income tax expense is as follows:
The components of income tax expense are as follows:
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
The principal components of net deferred tax liabilities are as follows:
The Parent files a consolidated federal income tax return and combined California franchise tax reports which include the Company and the Parent's other subsidiaries. The Company pays the amount of taxes applicable to itself had it filed a separate return.
The Company generally provides for income taxes on the basis of amounts expected to be paid currently, except for the provision for deferred income taxes on regulatory accounts, customer advances for construction and accelerated depreciation of property placed in service after 1980. In addition, the Company recognizes certain other deferred tax liabilities (primarily accelerated depreciation of property placed in service prior to 1981 and deferred investment tax credits) which are expected to be recovered through future rates. At December 31, 1994 and 1993, $97 million and $109 million, respectively, of deferred income taxes have been offset by an equivalent amount in regulatory assets.
4. COMMITMENTS AND CONTINGENT LIABILITIES
ENVIRONMENTAL OBLIGATIONS
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 the sites) may have environmental obligations under environmental laws. As of December 31, 1994, eight of these sites have been remediated, of which five have received certification from the California Environmental Protection Agency. Preliminary investigations, at a minimum, have been completed on 33 of the gas plant sites including those sites at which the remediations described above have been completed. In addition, the Company has been named as a potentially responsible party of one landfill site and three industrial waste disposal sites.
On May 4, 1994, the CPUC approved a collaborative settlement between the Company and other California energy utilities and the Division of Ratepayer Advocates which provides for rate recovery of 90 percent of environmental investigation and remediation costs without reasonableness review. In addition, the utilities have the opportunity to retain a percentage of any insurance recoveries to offset the 10 percent of costs not recovered in rates.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
At December 31, 1994, the Company's estimated remaining investigation and remediation liability was approximately $65 million which it is authorized to recover through the mechanism discussed above. The estimated liability is subject to future adjustment pending further investigation. In 1993 and 1992, the Company charged $7 million and $5 million, respectively, to income and the remaining amount is included in Regulatory Assets. There were no related charges to income in 1994. 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 financial statements.
LITIGATION
The Company is a defendant in various lawsuits arising in the normal course of business. Management believes that the resolution of these pending claims and legal proceedings will not have a material effect on the Company's financial statements.
OTHER COMMITMENTS AND CONTINGENCIES
At December 31, 1994, commitments for capital expenditures were approximately $33 million.
On January 17, 1994, the Company's service area was struck by a major earthquake. The result was a disruption in service to 150,000, or less than 3 percent, of its customers and damage to some facilities. The financial impact of the damages related to the earthquake not recovered by insurance is expected to be recovered in rates under an existing balancing account mechanism, and should have no material effect on the Company's financial statements.
5. LEASES
The Company has leases on real and personal property expiring at various dates from 1995 to 2011. 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 the Company. Rental expense under operating leases was $42 million, $39 million and $37 million, in 1994, 1993 and 1992, respectively.
The following is a schedule of future minimum operating lease commitments as of December 31, 1994:
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
6. COMPENSATING BALANCES AND SHORT-TERM BORROWING ARRANGEMENTS
The Company has $750 million of unsecured revolving lines of credit, of which $350 million is a multi-year credit agreement requiring annual fees of .10 percent and $400 million is a 364 day credit agreement requiring annual fees of .07 percent. The interest rates on these lines vary and are derived from formulas based on market rates and the Company's credit rating. The multi-year credit agreement expires on February 8, 2000. At December 31, 1994, all bank lines of credit were unused. The unused bank lines of credit support the Company's commercial paper program and provide liquidity for the Company.
At December 31, 1994 and 1993, the Company had $524 million and $267 million, respectively, of commercial paper obligations outstanding. The weighted average annual interest rate of commercial paper obligations outstanding was 5.96 percent and 3.25 percent at December 31, 1994 and 1993, respectively. At December 31, 1994, the Company has classified $246 million of the commercial paper as long-term debt since it is the Company's intent (supported by the $350 million multi-year credit agreement above) to continue to refinance that portion of the debt on a long-term basis.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
7. LONG-TERM DEBT
The annual principal payment requirements of long-term debt for the years 1995 through 1998 are $86 million, $95 million, $147 million, and $497 million, respectively. No amounts are due in 1999. Substantially all utility plant is pledged as collateral for the first mortgage bonds.
CURRENCY RATE SWAPS
In February 1986, the Company issued SFr. 100 million of 5 1/8 percent bonds which will mature on February 6, 1998. The Company has entered into a swap transaction with a major international bank to hedge the currency exposure. The terms of the swap result in a U.S. dollar liability of $47 million at an interest rate of 9.725 percent with the principal payable on February 6, 1998.
In May 1986, the Company issued SFr. 150 million of 7 1/2 percent Foreign Interest Payment Securities which are renewable at 10-year intervals at reset interest rates. Interest is payable in U.S. dollars. The principal was exchanged into $75 million at an exchange rate of 1.9925, which is also the minimum rate of exchange for determining the amount of principal repayable in Swiss francs.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
8. FINANCIAL INSTRUMENTS
The carrying amount of cash and cash equivalents approximates fair value because of the short maturity of those instruments. The Company's Flexible Auction Series preferred stocks approximate fair value since they are remarketed periodically.
The fair value of the Company's long-term debt, 6 percent preferred, 6 percent Series A preferred and 7 3/4 percent preferred stock is estimated based on the quoted market prices for the same or similar issues or on the current rates offered to the Company for debt of similar remaining maturities. The fair value of the currency rate swap is the estimated amount that the bank would receive or pay to terminate the swap agreement at the reporting date, taking into account current exchange rates and the current credit worthiness of the swap counterparty. The fair value of these financial instruments is different from the carrying amount.
The following financial instruments have a fair value which is different from the carrying amount as of December 31.
In October, 1994, the Financial Accounting Standards Board (FASB) issued Statement of Financial Accounting Standards No. 119 (SFAS 119), "Disclosure about Derivative Financial Instruments and Fair Value of Financial Instruments." SFAS 119 is effective for financial statements issued for fiscal years ending after December 15, 1994 and requires certain disclosures about financial instruments not covered by SFAS 105, "Disclosure of Information about Financial Instruments with Off-Balance Sheet Risk and Financial Instruments with Concentrations of Credit Risk." As a result of the Gas Cost Incentive Mechanism (GCIM) (See Note 2), the Company enters into a certain amount of gas futures contracts in the open market to help reduce gas costs within the GCIM tolerance band. The Company's policy is to use gas futures contracts to mitigate risk and better manage gas costs. The CPUC has approved the use of gas futures for managing risk associated with the GCIM. For the year ended December 31, 1994, gains or losses from gas futures contracts are not material to the Company's financial statements.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
9. CAPITAL STOCK
The amount of capital stock outstanding is as follows:
(a) The Company's Articles of Incorporation authorize the following stocks: 100 million shares of Common Stock; 160,000 shares of 6% Preferred Stock; 840,000 shares of 6% Preferred Stock, Series A; 5 million shares of Series Preferred Stock and 5 million shares of Preference Stock.
(b) Each issue of the Flexible Auction Series Preferred Stock is auctioned on specified dividend dates. The term of each subsequent dividend period is, at the Company's option, 49 days or longer, not to exceed ten years. The weighted average dividend rates for the Flexible Auction Series Preferred Stock for 1994, 1993 and 1992 were: Series A, 3.40 percent, 2.67 percent and 3.21 percent, respectively; and Series C, 3.33 percent, 2.75 percent and 3.28 percent, respectively. Subsequent dividend rates may be affected by general market conditions and the credit rating assigned to the Flexible Auction Series Preferred Stock. The Company has the option of redeeming the shares, in whole or in part, at $100,000 per share plus accumulated dividends, on any scheduled dividend payment date.
(c) In the event of any liquidation, dissolution or winding up of the Company, the holders of shares of each series of Preferred Stock and of each series of Series Preferred Stock would be entitled to receive the stated value or the liquidation preference for their shares, plus accrued dividends before any amount shall be paid to the holders of Preference Stock or Common Stock. If the amounts payable with respect to the shares of each series of Preferred Stock or Series Preferred Stock are not paid in full, the holders of such shares will share ratably in any such distribution. After payment in full to the holders of each series of Preferred Stock, Series Preferred Stock and Preference Stock of the liquidating distributions to which they are entitled, the remaining assets and funds of the Company would be divided pro rata among the holders of the 6% Preferred Stock and the holders of Common Stock.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
10. TRANSACTIONS WITH AFFILIATES
Pacific Interstate Transmission Company, Pacific Interstate Offshore Company and Pacific Offshore Pipeline Company, subsidiaries of the Parent and gas supply affiliates of the Company, sell and transport gas to the Company under tariffs approved by the Federal Energy Regulatory Commission. During 1994, 1993 and 1992, billings for such gas purchases totaled $215 million, $344 million, and $356 million, respectively. The Company has long-term 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 previously discussed (see Note 2).
11. PENSION, POSTRETIREMENT AND OTHER EMPLOYEE BENEFIT PLANS
PENSION PLAN
The Company has a noncontributory defined benefit pension plan covering substantially all of its employees. Benefits are based on employees' years of service and compensation during their last years of employment. The Company's policy is to fund the plan annually at a level which is fully deductible for federal income tax purposes and as necessary on an actuarial basis to provide assets sufficient to meet the benefits to be paid to plan members.
In conformity with generally accepted accounting principles for a rate regulated enterprise, the Company has recorded regulatory adjustments to reflect, in net income, pension costs calculated under the actuarial method allowed for ratemaking. The cumulative difference between the net periodic pension cost calculated for financial reporting and ratemaking purposes has been included as a deferred charge or credit in the Consolidated Balance Sheet.
Pension expense is as follows:
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
A reconciliation of the pension plan's funded status to the pension liability recognized in the Consolidated Balance Sheet is as follows:
POSTRETIREMENT BENEFIT PLAN
In 1993, the Company adopted Statement of Financial Accounting Standards No. 106, "Employers' Accounting for Postretirement Benefits Other Than Pensions" (SFAS 106). SFAS 106 requires the accrual of the cost of certain postretirement benefits other than pensions over the active service period of the employee. The Company previously recorded these costs when paid or funded. In accordance with SFAS 106, the Company elected to amortize the unfunded transition obligation of $256 million over 20 years. The CPUC in late 1992 authorized SFAS 106 amounts to be recovered in rates.
As with pensions, the Company has recorded regulatory adjustments to reflect, in net income, postretirement benefit costs calculated under the actuarial method allowed for ratemaking. The cumulative difference between the net periodic postretirement benefit cost calculated for financial reporting and ratemaking purposes has been included as a deferred charge or credit in the Consolidated Balance Sheet.
The Company's postretirement benefit plan currently provides medical and life insurance benefits to qualified retirees. In the past, employee cost-sharing provisions have been implemented to control the increasing costs of these benefits. Other changes could occur in the future. The Company's policy is to fund these benefits at a level which is fully tax deductible for federal income tax purposes, not to exceed amounts recoverable in rates, and as necessary on an actuarial basis to provide assets sufficient to be paid to plan participants. The net postretirement benefit expense was as follows:
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Prior to 1993, the Company commenced funding its future liability for postretirement benefits through the pension plan. Amounts funded were subject to the respective income tax limitations and amounts provided through rates. In 1992, the amounts funded totaled $22 million.
A reconciliation of the plan's funded status to the postretirement benefit liability recognized in the Consolidated Balance Sheet is as follows:
The assumed health care cost trend rate is 7.5 percent for 1995. The trend rate is expected to decrease from 1995 to 1998 with a 6 percent ultimate trend rate thereafter. The effect of a one-percentage-point increase in the assumed health care cost trend rate for each future year is $7.1 million on the aggregate of the service and interest cost components of net periodic postretirement cost for 1994 and $54.4 million on the accumulated postretirement benefit obligation at December 31, 1994. The estimated income tax rate used in the return on plan assets is zero since the plan is tax exempt.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
POSTEMPLOYMENT BENEFITS
Effective January 1, 1994, the Company adopted SFAS 112, "Employers' Accounting for Postemployment Benefits". SFAS 112 requires the accrual of the obligation to provide benefits to former or inactive employees after employment but before retirement. The adoption of SFAS 112 had no impact on earnings since these costs are currently recovered in rates as paid, and as such, have been reflected as a regulatory asset. At December 31, 1994 and 1993, the total postemployment benefit liability was $49 million and $39 million, respectively, and represents primarily workers' compensation and disability benefits.
EARLY RETIREMENT PROGRAM
In 1994 and 1993, the Company offered a special early retirement program for a limited period to certain eligible employees. The cost of this program is included in the total pension expense for 1994 and 1993, respectively.
RETIREMENT SAVINGS PLAN
Upon completion of one year of service, all employees of the Company are also eligible to participate in the Company's retirement savings plan administered by bank trustees. Employees may contribute from 1 to 14 percent of their regular earnings. The Company generally contributes an amount of cash or a number of shares of the Parent's common stock of equivalent fair market value which, when added to prior forfeitures, will equal 50 percent of the first 6 percent of eligible base salary contributed by employees. The employees' contributions, at the direction of the employees, are primarily invested in the Parent's common stock, mutual funds or guaranteed investment contracts. The Company's contributions, which were invested in the Parent's common stock, were $8 million in 1994 and $9 million each in 1993 and 1992.
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STATEMENT OF MANAGEMENT RESPONSIBILITY FOR CONSOLIDATED FINANCIAL STATEMENTS
The consolidated financial statements have been prepared by management. The integrity and objectivity of these financial statements and the other financial information in the Annual Report, including the estimates and judgments on which they are based, are the responsibility of management. The financial statements have been audited by Deloitte & Touche LLP, independent certified public accountants, appointed by the Board of Directors. Their report is shown on the following page. Management has made available to Deloitte & Touche LLP all of the Company's financial records and related data, as well as the minutes of shareholders' and directors' meetings.
Management maintains a system of internal accounting control which it believes is adequate to provide reasonable, but not absolute, assurance that assets are properly safeguarded and accounted for, that transactions are executed in accordance with management's authorization and are properly recorded and reported, and for the prevention and detection of fraudulent financial reporting. Management monitors the system of internal control for compliance through its own review and a strong internal auditing program which also independently assesses the effectiveness of the internal controls. In establishing and maintaining internal controls, the Company exercises judgment in determining that the costs of such controls do not exceed the benefits to be derived.
Management acknowledges its responsibility to provide financial information (both audited and unaudited) that is representative of the Company's operations, reliable on a consistent basis, and relevant for a meaningful financial assessment of the Company. Management believes that the control process enables them to meet this responsibility.
Management also recognizes its responsibility for fostering a strong ethical climate so that the Company's affairs are conducted according to the highest standards of personal and corporate conduct. This responsibility is characterized and reflected in the Parent's code of corporate conduct, which is publicized throughout the Company. The Parent maintains a systematic program to assess compliance with this policy.
The Board of Directors has an Audit Committee composed solely of directors who are not officers or employees of the Company. The Committee recommends for approval by the full Board the appointment of the independent auditors. The Committee meets regularly with management, with the Company's internal auditors and with the independent auditors. The independent auditors and the internal auditors periodically meet alone with the Audit Committee and have free access to the Audit Committee at any time.
Warren I. Mitchell, President
Ralph Todaro, Vice President and Controller
January 31, 1995
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INDEPENDENT AUDITORS' REPORT
Southern California Gas Company:
We have audited the consolidated financial statements of Southern California Gas Company and its subsidiaries (pages 25 to 42) as of December 31, 1994 and 1993, and for each of the three years in the period ended December 31, 1994. 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, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Southern California Gas Company and its subsidiaries as of December 31, 1994 and 1993, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 1994 in conformity with generally accepted accounting principles.
DELOITTE & TOUCHE LLP
Los Angeles, California January 31, 1995
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OTHER INFORMATION
QUARTERLY FINANCIAL DATA (UNAUDITED)
ITEM 9.

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
None.
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PART III
ITEM 10.



ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
Information required by this Item with respect to the Company's directors is set forth under the caption "Election of Directors" in the Company's Information Statement for its Annual Meeting of Shareholders scheduled to be held on May 2, 1995. Such information is incorporated herein by reference.
Information required by this Item with respect to the Company's executive officers is set forth in Item 1 of this Annual Report.
ITEM 11.

ITEM 11. EXECUTIVE COMPENSATION
Information required by this Item is set forth under the caption "Election of Directors" and "Executive Compensation" in the Company's Information Statement for its Annual Meeting of Shareholders scheduled to be held on May 2, 1995. Such information is incorporated herein by reference.
ITEM 12.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
Information required by this Item is set forth under the caption "Election of Directors" in the Company's Information Statement for its Annual Meeting of Shareholders scheduled to be held on May 2, 1995. Such information is incorporated herein by reference.
ITEM 13.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Not applicable.
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PART IV
ITEM 14.

ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K
(a) Documents filed as part of this report:
1. CONSOLIDATED FINANCIAL STATEMENTS (SET FORTH IN ITEM 8 OF THIS ANNUAL REPORT ON FORM 10-K):
1.01 Report of Deloitte & Touche LLP, Independent Certified Public Accountants.
1.02 Statement of Consolidated Income for the years ended December 31, 1994, 1993 and 1992.
1.03 Consolidated Balance Sheet at December 31, 1994 and 1993.
1.04 Statement of Consolidated Cash Flows for the years ended December 31, 1994, 1993 and 1992.
1.05 Statement of Consolidated Shareholders' Equity for the years ended December 31, 1994, 1993, 1992 and 1991.
1.06 Notes to Consolidated Financial Statements.
3. ARTICLES OF INCORPORATION AND BY-LAWS:
3.01 Restated Articles of Incorporation of Southern California Gas Company (Note 25; Exhibit 3.01).
3.02 Bylaws of Southern California Gas Company.
4. INSTRUMENTS DEFINING THE RIGHTS OF SECURITY HOLDERS:
(Note: As permitted by Item 601(b)(4)(iii) of Regulation S-K, certain instruments defining the rights of holders of long-term debt for which the total amount of securities authorized thereunder does not exceed ten percent of the total assets of Southern California Gas Company and its subsidiaries on a consolidated basis are not filed as exhibits to this Annual Report. 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 (Note 13; Exhibit 4.01).
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4.02 First Mortgage Indenture of Southern California Gas Company to American Trust Company dated as of October 1, 1940 (Note 1; Exhibit B-4).
4.03 Supplemental Indenture of Southern California Gas Company to American Trust Company dated as of July 1, 1947 (Note 2; Exhibit B-5).
4.04 Supplemental Indenture of Southern California Gas Company to American Trust Company dated as of August 1, 1955 (Note 3; Exhibit 4.07).
4.05 Supplemental Indenture of Southern California Gas Company to American Trust Company dated as of June 1, 1956 (Note 4; Exhibit 2.08).
4.06 Supplemental Indenture of Southern California Gas Company to Wells Fargo Bank, National Association dated as of August 1, 1972 (Note 7; Exhibit 2.19).
4.07 Supplemental Indenture of Southern California Gas Company to Wells Fargo Bank, National Association dated as of May 1, 1976 (Note 6; Exhibit 2.20).
4.08 Supplemental Indenture of Southern California Gas Company to Wells Fargo Bank, National Association dated as of September 15, 1981 (Note 12; 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 (Note 16; 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 (Note 18; 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 (Note 24; Exhibit 4.37).
4.12 Specimen Flexible Auction Series A Preferred Stock Certificate (Note 21; Exhibit 4.11).
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4.13 Specimen Flexible Auction Series B Preferred Stock Certificate (Note 22; Exhibit 4.12).
4.14 Specimen Flexible Auction Series C Preferred Stock Certificate (Note 23; Exhibit 4.13).
4.15 Specimen 7 3/4% Series Preferred Stock Certificate (Note 25; Exhibit 4.15).
10. MATERIAL CONTRACTS
10.01 Restatement and Amendment of Pacific Enterprises 1979 Stock Option Plan (Note 10; Exhibit 1.1).
10.02 Pacific Enterprises Supplemental Medical Reimbursement Plan for Senior Officers (Note 11; Exhibit 10.24).
10.03 Pacific Enterprises Financial Services Program for Senior Officers (Note 11; Exhibit 10.25).
10.04 Southern California Gas Company Retirement Savings Plan, as amended and restated as of August 30, 1988 (Note 15; Exhibit 28.02).
10.05 Southern California Gas Company Statement of Life Insurance, Disability Benefit and Pension Plans, as amended and restated as of January 1, 1985 (Note 16; Exhibit 10.27).
10.06 Southern California Gas Company Pension Restoration Plan For Certain Management Employees (Note 11; Exhibit 10.29).
10.07 Pacific Enterprises Executive Incentive Plan (Note 18; Exhibit 10.13)
10.08 Pacific Enterprises Deferred Compensation Plan for Key Management Employees (Note 15; Exhibit 10.41).
10.09 Pacific Enterprises Stock Incentive Plan (Note 19; Exhibit 4.01).
10.10 Pacific Enterprises Employee Stock Option Plan (Note 27; Exhibit 4.01).
21. SUBSIDIARIES OF THE REGISTRANT
21.01 List of subsidiaries of Southern California Gas Company.
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23. CONSENTS OF EXPERTS AND COUNSEL
23.01 Consent of Deloitte & Touche LLP, Independent Certified Public Accountants.
24. POWER OF ATTORNEY
24.01 Power of Attorney of Certain Officers and Directors of Southern California Gas Company (contained on the signature pages of this Annual Report on Form 10-K).
27. Financial Data Schedule
27.01 Financial Data Schedule
(b) REPORTS ON FORM 8-K: The following report on Form 8-K was filed during the last quarter of 1994. REPORT DATE ITEM REPORTED
Nov. 23, 1994 Item 5
NOTE: Exhibits referenced to the following notes were filed with the documents cited below under the exhibit or annex number following such reference. Such exhibits are incorporated herein by reference.
Note REFERENCE DOCUMENT
1 Registration Statement No. 2-4504 filed by Southern California Gas Company on September 16, 1940.
2 Registration Statement No. 2-7072 filed by Southern California Gas Company on March 15, 1947.
3 Registration Statement No. 2-11997 filed by Pacific Lighting Corporation on October 26, 1955.
4 Registration Statement No. 2-12456 filed by Southern California Gas Company on April 23, 1956.
5 Registration Statement No. 2-45361 filed by Southern California Gas Company on August 16, 1972.
6 Registration Statement No. 2-56034 filed by Southern California Gas Company on April 14, 1976.
7 Registration Statement No. 2-59832 filed by Southern California Gas Company on September 6, 1977.
8 Registration Statement No. 2-42239 filed by Pacific Lighting Gas Supply Company (under its former name of Pacific Lighting Service Company) on October 29, 1971.
9 Registration Statement No. 2-43834 filed by Pacific Lighting Corporation on April 17, 1972.
10 Registration Statement No. 2-66833 filed by Pacific Lighting Corporation on March 5, 1980.
11 Annual Report on Form 10-K for the year ended December 31, 1980, filed by Pacific Lighting Corporation.
12 Annual Report on Form 10-K for the year ended December 31, 1981, filed by Pacific Lighting Corporation.
13 Annual Report on Form 10-K for the year ended December 31, 1980 filed by Southern California Gas Company.
14 Quarterly Report on Form 10-Q for the quarter ended September 30, 1983, filed by Southern California Gas Company.
15 Registration Statement No. 33-6357 filed by Pacific Enterprises on December 30, 1988.
16 Annual Report on Form 10-K for the year ended December 31, 1984, filed by Southern California Gas Company.
17 Current Report on Form 8-K for the month of March 1986, filed by Southern California Gas Company.
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18 Annual Report on Form 10-K for the year ended December 31, 1987 filed by Pacific Lighting Corporation.
19 Registration Statement No. 33-21908 filed by Pacific Enterprises on May 17, 1988.
20 Annual Report on Form 10-K for the year ended December 31, 1988, filed by Southern California Gas Company.
21 Annual Report on Form 10-K for the year ended December 31, 1989, filed by Southern California Gas Company.
22 Annual Report on Form 10-K for the year ended December 31, 1990, filed by Southern California Gas Company.
23 Annual Report on Form 10-K for the year ended December 31, 1991, filed by Southern California Gas Company.
24 Registration Statement No. 33-50826 filed by Southern California Gas Company on August 13, 1992.
25 Annual Report on Form 10-K for the year ended December 31, 1992, filed by Southern California Gas Company.
26 Annual Report on Form 10-K for the year ended December 31, 1993, filed by Southern California Gas Company.
27 Registration Statement No. 33-54055 filed by Pacific Enterprises on June 9, 1994.
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SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
SOUTHERN CALIFORNIA GAS COMPANY
By: /s/ Warren I. Mitchell -------------------------- Name: Warren I. Mitchell Title: President Dated: March 17, 1995
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Each person whose signature appears below hereby authorizes Warren I. Mitchell, Lloyd A. Levitin, Ralph Todaro, and each of them, severally, as attorney-in-fact, to sign on his or her behalf, individually and in each capacity stated below, and file all amendments to this Annual Report.
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the dates indicated.
SIGNATURE TITLE DATE
/s/ Warren I. Mitchell - ----------------------- President March 17, 1995 (Warren I. Mitchell) (Principal Executive Officer)
/s/ Lloyd A. Levitin - ----------------------- Executive Vice President and (Lloyd A. Levitin) Chief Financial Officer (Principal Financial Officer) March 17, 1995
/s/ Ralph Todaro - ----------------------- Vice President and Controller March 17, 1995 (Ralph Todaro)
/s/ Hyla H. Bertea - ----------------------- Director March 17, 1995 (Hyla H. Bertea)
/s/ Herbert L. Carter - ----------------------- Director March 17, 1995 (Herbert L. Carter)
/s/ Richard D. Farman - ----------------------- Director March 17, 1995 (Richard D. Farman)
/s/ Wilford D. Godbold, Jr. - ----------------------- Director March 17, 1995 (Wilford D. Godbold, Jr.)
/s/ Ignacio E. Lozano, Jr. - ----------------------- Director March 17, 1995 (Ignacio E. Lozano, Jr.)
/s/ Harold M. Messmer, Jr. - ----------------------- Director March 17, 1995 (Harold M. Messmer, Jr.)
/s/ Paul A. Miller - ----------------------- Director March 17, 1995 (Paul A. Miller)
/s/ Joseph R. Rensch - ----------------------- Director March 17, 1995 (Joseph R. Rensch)
/s/ Diana L. Walker - ----------------------- Director March 17, 1995 (Diana L. Walker)
/s/ Willis B. Wood, Jr. - ----------------------- Director March 17, 1995 (Willis B. Wood, Jr.)
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