Annual Report (Form 10-K), fiscal year 1993





ITEM 3. LEGAL PROCEEDINGS
In El Paso Natural Gas Company and Meridian Oil Gathering Inc. v. Amoco Production Company, filed in Delaware Chancery Court on May 8, 1991, Amoco Production Company ("Amoco") alleged breaches by EPG and a then affiliated company, Meridian Oil Gathering Inc. ("MOGI"), of certain gas purchase, gathering and transportation agreements pertaining to natural gas produced by Amoco in the San Juan Basin. Amoco alleged breach of "favored nations" contractual provisions regarding services to be performed by EPG, including those relating to transportation capacity and rates, and has sought a court order requiring specific performance by EPG and MOGI with respect to future transportation services and an award of monetary damages of an undetermined amount for alleged past breaches of contract. On March 4, 1992, the Court issued a Memorandum Opinion which, among other things, denied Amoco's motion for partial summary judgment and concluded that the Amoco contracts at issue do not contain the general "favored nations" rights claimed by Amoco. The court further concluded that EPG's and MOGI's motions for summary judgment, seeking dismissal of Amoco's counterclaim against MOGI, should be granted. Conoco Inc. ("Conoco") asserted claims similar to Amoco's original claims, involving lesser quantities of gas, in a separate Delaware Chancery Court proceeding filed on December 30, 1991, Conoco Inc. v. El Paso Natural Gas Company. In August 1992, the Amoco and Conoco cases were consolidated, MOGI was dismissed as a party, and Amoco and Conoco filed amended pleadings to restate their claims in lights of the court's March 4, 1992 ruling. EPG and Conoco concluded a settlement agreement which resulted in dismissal of the Conoco claims. Trial of the Amoco claims concluded on July 15, 1993; however, the court's decision has not yet been issued. Post-trial briefing and oral arguments concluded in early November 1993, and the decision of the court is expected in early 1994. Management does not expect the outcome of this matter to have a materially adverse effect on the Company's financial condition.
The Company is a named defendant in numerous lawsuits and a named party in numerous governmental proceedings arising in the ordinary course of business. While the outcome of such lawsuits or other proceedings against the Company cannot be predicted with certainty, management does not expect these matters to have a materially adverse effect on the Company's financial condition.
ITEM 4.

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
During the fourth quarter of 1993, no matters were submitted to a vote of security holders.
PART II
ITEM 5.

ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
All outstanding common stock of EPG was owned by BR until March 1992. In March 1992, EPG completed the Offering. On June 30, 1992, BR distributed its 31.4 million shares of EPG common stock, which represented approximately 85 percent of EPG's outstanding common stock, to BR shareholders. As a result, BR no longer retains an ownership interest in EPG.
EPG's common stock is traded on the New York Stock Exchange. As of January 14, 1994 the approximate number of holders of record of common stock was 25,673. This does not include individual participants on whose behalf a clearing agency or its nominee holds EPG's common stock.
The following table reflects the high and low sales prices for and cash dividends declared on EPG's common stock based on the daily composite listing of stock transactions for the New York Stock Exchange.
On January 14, 1994, EPG's Board of Directors declared a quarterly dividend of $0.3025 per share on EPG's common stock, payable on April 4, 1994 to shareholders of record on March 11, 1994.
ITEM 6.

ITEM 6. SELECTED FINANCIAL DATA
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(a) Earnings per share of common stock is based on 37,212,192 weighted average shares of common stock outstanding for 1993, 36,049,135 weighted average shares of common stock outstanding for 1992 and 31,421,731 shares of common stock outstanding for the years 1989 through 1991.
(b) Represents dividends declared subsequent to the Offering.
(c) In May 1991, EPG declared and paid a dividend of $175 million to its then parent company, The El Paso Company ("TEPCO"). In September 1991, EPG declared a dividend of all its Oil and Gas Operations Segment to TEPCO. The total amount of that dividend was $925 million. In addition, EPG declared and paid dividends to BR totaling $55 million in 1991 and $274 million prior to the Offering in 1992.
(d) Excludes current maturities.
(e) MPC has been consolidated for the months of May 1993 through December 1993.
ITEM 7.

ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
FINANCIAL CONDITION AND LIQUIDITY
Cash provided by operating activities was $236 million for 1993 compared with $334 million for 1992. The decrease from the previous year was primarily due to proceeds received in 1992 from the sale of the direct bill portion of the take-or-pay receivables, lower take-or-pay collections in 1993, rate refund payments resulting from the settlement agreement and costs incurred to repair flood damaged pipelines (see Other of this section), partially offset by decreased tax payments in 1993.
Cash provided by continuing operating activities was $334 million for 1992 compared with $249 million for 1991. The increase was primarily due to proceeds from the sale of the direct bill portion of the take-or-pay receivables, the 1991 net cash payments made in connection with the August 14, 1991 FERC order (see Rates and Regulatory Matters of this section), the decrease in take-or-pay expenditures and a decrease in interest payments. The increase was partially offset by a reduction in volumetric take-or-pay receivable collections and a decrease in accruals for regulatory issues.
Acquisition
On June 1, 1993, the Company acquired from a wholly owned subsidiary of Enron Corp., that subsidiary's 50 percent interest in MPC, for approximately $40 million in cash, representing the approximate book value of the investment. The acquisition, which was funded by internally generated cash flow, gives the Company 100 percent ownership of MPC. The acquisition was accounted for using the purchase method.
In conjunction with the acquisition, the following liabilities were assumed:
The following MPC balances are included in the December 31, 1993 Consolidated Balance Sheet of the Company:
The operating results of MPC are included in the Company's consolidated results of operations for the months of May 1993 through December 1993. The Company's previously owned 50 percent equity interest in MPC is included in other-net in the accompanying Consolidated Statement of Income.
The following pro forma summary presents the consolidated results of operations of the Company as if the acquisition had occurred as of January 1, 1993 and January 1, 1992. These pro forma results have been prepared for comparative purposes only and do not purport to be indicative of what may have resulted had the acquisition occurred as of those dates or of results which may occur in the future.
Gathering and Production Area Facilities
On January 14, 1994, EPG filed an application with FERC seeking an order which would terminate, effective January 1, 1996, certificates applicable to certain gathering and production area facilities owned by EPG on the basis that such facilities are not subject to FERC jurisdiction.
EPG intends, effective January 1, 1996, to transfer all of its nonjurisdictional gathering and production area facilities to a wholly owned subsidiary of EPG. Such facilities are used for gathering and other nonjurisdictional functions and are an inherent part of EPG's current gathering operations. The facilities to be transferred consist of approximately 6,700 miles of various sized pipelines, compressors with horsepower of 40,600 and various treating and processing plants. These nonjurisdictional facilities, together with the facilities included in the January 14, 1994 FERC application, constitute all of EPG's gathering and production area facilities.
Rates and Regulatory Matters
On July 1, 1991, EPG filed for FERC approval of new system rates and placed the proposed new rates into effect on January 1, 1992, subject to refund. On July 31, 1992, EPG again filed for new system rates to recover increased costs and return on rate base associated with EPG's expansion and modernization projects. These rates became effective on February 1, 1993, subject to refund. In the July 1992 filing, EPG's rate base increased from $752 million to approximately $1.2 billion. EPG made its compliance filing on December 31, 1992 in accordance with the Restructuring Rules.
In January 1993, EPG, certain of its customers and FERC staff reached a settlement agreement which led to the resolution of the above mentioned rate and restructuring proceedings. The settlement agreement was filed in January 1993 to supersede EPG's December 31, 1992 compliance filing. As required by FERC order, EPG filed revised rates on September 14, 1993, which implemented the settlement agreement effective October 1, 1993. Under the settlement agreement, EPG refunded a total of approximately $56 million, inclusive of interest, in the fourth quarter of 1993. EPG had provided for these rate refunds as revenues were collected.
The settlement agreement provides for the accelerated recovery of a substantial portion of EPG's investment in its underground storage facility. This is being recovered by a demand charge mechanism over the period from October 1, 1993 through December 31, 1996. The amount to be recovered was approximately $56.7 million plus interest accruing beginning February 1, 1993 at the FERC allowed rate, which approximates the prime rate. The amount recovered through December 31, 1993 was $19 million. The outstanding balance at December 31, 1993 was $37 million, of which $12 million is included in other current assets and $25 million is included in other assets in the accompanying Consolidated Balance Sheet. The settlement agreement also established new depreciation rates for certain of EPG's facilities effective January 1, 1992.
On August 14, 1991, FERC approved an order resolving all of the issues in EPG's December 1987 rate case filing and certain other pending matters which became effective on September 1, 1991. The order provided for: (i) the establishment of revised rate levels for the period July 1, 1988 through the effective date of EPG's next rate change, which occurred on January 1, 1992; and (ii) payment of certain refunds for the
period July 1, 1988 through August 31, 1991. EPG disbursed to its customers $252 million in October 1991 in accordance with the order. The total refund obligation at September 1, 1991 was $369 million before certain offsets, including an unbilled portion of the $169 million of recoverable excess gas costs. The net refund obligation and the remaining balance of the recoverable excess gas costs, $25 million, were recorded against previously established accruals.
Pursuant to the Restructuring Rules, MPC filed its restructuring plan on November 3, 1992. On March 2, 1993, FERC issued an order essentially approving MPC's compliance filing, subject to changes, which were made in an amended restructuring plan on March 29, 1993. Several of MPC's customers filed protests and requests for rehearing of the March 2, 1993 FERC order. The rehearing requests were denied, and FERC approved the amended restructuring plan on July 9, 1993, with an effective date of August 1, 1993. On October 15, 1993, FERC issued an order which denied requests for rehearing of the July 9, 1993 order. Several of MPC's customers have filed petitions for review of the March 2, 1993, July 9, 1993 and October 15, 1993 orders with the United States Court of Appeals which are currently pending.
The primary issues on appeal pertain to FERC's requirement that MPC's rates for firm transportation service be based upon SFV rate design rather than MFV rate design. The application of SFV rates requires MPC's existing firm shippers to pay a higher proportion of their total transportation rate in the reservation component of the rate, and this increases aggregate transportation charges for low load factor shippers. Such shippers have contended that FERC's application of SFV rate design to MPC unlawfully abrogates the rate provisions of MPC's service agreements and constitutes an unlawful rate increase. MPC believes the United States Court of Appeals will uphold SFV rates as applied to MPC.
Take-or-Pay Settlements
Since 1987, EPG has made, or has committed to make, buy-out and buy-down payments totaling $1.5 billion to resolve past and future take-or-pay exposure, to terminate and reform gas purchase contracts, to amend pricing and take provisions of gas purchase contracts and to settle related litigation. In certain cases, EPG resolved claims by making recoupable prepayments. At December 31, 1993 and December 31, 1992, the recoupable prepayment balances were $9 million and $19 million, respectively. These payments resolved virtually all the outstanding producer claims asserted against EPG and terminated or prospectively reformed substantially all of EPG's remaining gas purchase contracts, with the result that EPG no longer has any material take-or-pay exposure.
EPG has filed to recover $1.1 billion of its buy-out and buy-down costs under FERC cost recovery procedures. The collection period for the direct bill portion of the take-or-pay buy-out and buy-down costs extends through May 1994. The collection period for the volumetric surcharge portion of such costs extends through March 1996. Through December 31, 1993, EPG had recovered approximately $1.0 billion; of that recovery, $361 million was collected by direct bill and $682 million by volumetric surcharge. EPG has established a reserve for that portion of the volumetric surcharge receivables balance which is unlikely to be collected over the period through March 1996, based on current throughput projections. The balance of this reserve was $19 million at December 31, 1993.
Under FERC procedures, take-or-pay cost recovery filings may be challenged by pipeline customers on prudence and certain other grounds. In October 1992, FERC approved an order, subject to rehearing, resolving all but one of the outstanding issues regarding EPG's take-or-pay proceedings. The remaining issue involves the claim by several customers that EPG has sought to recover an excessive amount for the value of certain production properties which were transferred to a producer as part of a 1989 take-or-pay settlement. On March 8, 1993, an initial decision from the presiding ALJ was rendered which, if adopted without changes by FERC, would require EPG to refund to or forgo collection from its customers of up to $30 million, plus interest. Exceptions to this initial decision were filed with FERC by both parties on April 7, 1993. On April 27, 1993, briefs opposing exceptions were filed by the same parties as well as by FERC staff. EPG has established adequate reserves for this issue and does not believe that the ultimate outcome will have a materially adverse effect on the Company's financial condition or results of operations.
On January 14, 1992, EPG completed a sale of substantially all of its remaining take-or-pay buy-out and buy-down receivables. The sale totaled $325 million, including $305 million of cash received at closing, which was used to repay $300 million of a payable to BR. The receivables sold in this transaction included $104 million which was recovered through direct bill and $221 million to be recovered through volumetric surcharge. The volumetric surcharge portion of the sale has been accounted for as a financing transaction because EPG is subject to certain recourse provisions related to such receivables. At December 31, 1993 and December 31, 1992, $87 million and $125 million, respectively, of the volumetric surcharge portion of the receivables sold remained outstanding. Amounts collected related to the take-or-pay receivables sold are remitted to the purchasers of the receivables.
Restructuring and Financing Transactions
In February 1992, EPG established a $300 million revolving credit facility with a group of banks which expires in March 1996. As of December 31, 1993, there were no borrowings outstanding under this facility. Approximately $1 million of commercial paper was outstanding as of December 31, 1993.
During 1992 and 1991, EPG completed several transactions in preparation for its separation from BR. Among these transactions was the transfer of the net assets of El Paso Production Company ("EPPC") and Meridian Oil Hydrocarbons Inc. ("Hydrocarbons"), collectively, the Company's Oil and Gas Operations Segment, which is reported as discontinued operations.
In December 1991, EPG declared and paid a dividend to BR of $55 million. In January and February 1992, EPG declared and paid dividends totaling $274 million to BR. These dividends were paid from the balance owed to EPG under an intercorporate cash management arrangement.
In March 1992, EPG completed the Offering. The proceeds from the Offering, net of related costs, totaled approximately $96 million. On June 30, 1992, BR distributed its 31.4 million shares of EPG's common stock to BR shareholders, which represented approximately 85 percent of EPG's outstanding common stock. As a result, BR no longer retains an ownership interest in EPG.
EPG had a Commitment Agreement with BR under which it could borrow up to $300 million and Loan Agreements for borrowings up to $500 million. At December 31, 1991, outstanding borrowings under the Commitment and Loan Agreements were $300 million and $325 million, respectively. In January 1992, additional borrowings of $109 million were made under the Loan Agreements to purchase the notes and debentures described below.
EPG also undertook certain transactions to establish an appropriate capital structure for its post-separation operations. In December 1991 and January 1992, EPG purchased notes and debentures totaling $253 million and $134 million, respectively. Funds were provided by proceeds from borrowings under the BR Loan Agreements. In addition, all of the outstanding 9 5/8% debentures were called for redemption at 106.84 percent of their principal amount. In January 1992, EPG received net proceeds of $569 million from the issuance of new debt securities. The proceeds were used for repayment of borrowings under the Loan Agreements with BR, redemption of debentures and payment of general corporate costs.
EPG repaid its outstanding commercial paper in December 1991 with borrowings under the Commitment Agreement with BR. The proceeds from the sale of the take-or-pay receivables, previously discussed herein, were used to repay the borrowings under the Commitment Agreement with BR.
The Commitment Agreement and the Loan Agreements with BR were terminated prior to the completion of the Offering.
Competition
Currently, EPG faces competition from other companies which transport natural gas to the California market. Competition generally occurs on the basis of price, quality and reliability of service.
The total present interstate pipeline capacity for delivering natural gas to the California border is approximately 6.9 Bcf/d. In addition to EPG, three other major interstate pipelines presently deliver natural
gas to California. Transwestern has the capacity to deliver approximately 1.1 Bcf/d from Permian, Anadarko and San Juan Basin supply sources; PGT has the capacity to deliver about 1.8 Bcf/d of Canadian gas; and Kern River has the capacity to deliver approximately 700 MMcf/d from Rocky Mountain supply sources. PGT completed a 755 MMcf/d expansion of its California capacity on November 1, 1993. In 1992, Kern River held an open season to determine interest in expanding capacity to California by 200 MMcf; however, no planned expansions have since been announced.
Demand for natural gas in the California market is projected to be less than capacity for some time to come. EPG maintains a strong competitive position in the market by virtue of the fact that its pipeline is, and expects to remain, the lowest-cost transporter of natural gas to California and the principal means of moving gas from the San Juan Basin to the California border. EPG's pipeline capacity to California is fully subscribed under long-term contracts which provide for the payment of fixed reservation charges.
EPG's largest single contract for interstate capacity to California is its 1,450 MMcf/d contract with SoCal, which has a primary term ending August 31, 2006. In 1992, SoCal relinquished 300 MMcf/d pursuant to this contract (out of an original contract demand quantity of 1,750 MMcf/d), all of which was subsequently subscribed by new firm shippers under long-term contracts. Pursuant to this contract, SoCal has the option to relinquish an additional 300 MMcf/d of capacity during the first quarter of 1996. PG&E has a contract for 1,140 MMcf/d of firm capacity rights on EPG's system. This contract has a primary term ending December 31, 1997. CPUC has directed PG&E to maintain 600 MMcf/d of capacity on EPG's system to service PG&E's core and core subscription service customers. EPG expects to offset potential future reductions in capacity commitments through new contracts with various natural gas users in California which are now served indirectly through SoCal and PG&E, as well as through the development of additional East-of-California and northern Mexico markets.
In general, natural gas faces varying degrees of competition from electricity, coal and oil. Competitive pressure from alternative fuels is less prevalent in EPG's market area due to strict environmental regulations in California.
Environmental
Accruals for environmental compliance costs are established when environmental assessments and/or remediation are probable, and when costs can be reasonably estimated. As of December 31, 1993, EPG had a reserve of $38 million for the following environmental contingencies with income statement impact:
1 -- EPG has been conducting remediation of PCB contamination at its facilities. The majority of the required PCB remediation has been completed. Future PCB remediation costs are estimated to range between $8 million and $11 million over the next five years.
2 -- EPG executed an Administrative Order on Consent with EPA on June 25, 1993 to conduct a RI/FS for a BI site located in Statesville, North Carolina, that has been identified for cleanup. BI and EPG have entered into an agreement to jointly fund the RI/FS for the site. EPG's share of the potential remediation costs is estimated to be between $17 million and $20 million over a 30 year period.
3 -- On November 2, 1993, in accordance with an EPA order, EPG and ARCO submitted work plans for remediation of the subsurface at the Prewitt Refinery in McKinley County, New Mexico. EPG and ARCO have a cost sharing agreement to each pay one-half of any remediation costs at this site. EPG's share of the remediation costs is estimated to be between $10 million and $20 million over a 30 year period.
4 -- EPG is involved in other environmental assessment and remediation activities which include two additional CERCLA sites (Fountain Inn, South Carolina and Odessa, Texas) and one state Superfund site (Etowah, Tennessee). The amount reserved as of December 31, 1993 will cover these and other small environmental assessments and other remediation projects.
EPG also has potential expenditures, of a capital nature, for the following environmental projects:
1 -- EPG has analyzed CAAA, and believes that these rules will impact the Company's operations primarily in the following areas: (i) potential required reductions in the emissions of NOx in non-attainment areas; (ii) the requirement for air emissions permitting of existing facilities; and (iii) enhanced monitoring of air emissions. The Company anticipates capitalizing the equipment costs associated with complying with CAAA and estimates that approximately $5 million to $27 million will be spent during the 1995 through 1997 time frame. However, EPA's proposed enhanced monitoring rules, when finalized, could potentially impose greater costs to the Company.
2 -- EPG has been conducting remediation of mercury contamination at certain facilities and is replacing mercury containing meters with dry flow devices. The remaining remediation costs are estimated to be between $8 million and $12 million, most of which will be incurred over the next two years. EPG will close and retire about 5,400 earthen siphon/dehydration pits in the San Juan Basin as recently required by certain environmental regulations. EPG estimates costs of approximately $17 million to $25 million to retire these pits over the next two years. The mercury remediation and pit closure costs, which are associated with the retirement of equipment, will be recorded as adjustments to accumulated depreciation, as required by regulatory accounting.
On December 21, 1993, EPA issued EPG a Notice of Liability for the CSMRI site in Golden, Colorado. Because EPA has not yet determined the volume of hazardous substances sent to the site by all parties, there is no way to estimate EPG's potential share of remediation costs. However, based on the volumes EPA presently lists as contributed by EPG and other potentially responsible parties, it appears that EPG is a minor contributor.
It is possible that new information or future developments could require the Company to reassess its potential exposure related to environmental matters. As such information or developments occur, contingency amounts will be adjusted accordingly.
Common Stock Transactions Subsequent to the Offering
For the year ended December 31, 1993, EPG paid approximately $40 million in dividends. On January 14, 1994, EPG's Board of Directors declared a quarterly dividend of $0.3025 per share on EPG's common stock, payable on April 4, 1994 to shareholders of record on March 11, 1994.
On October 22, 1992, EPG's Board of Directors authorized the repurchase of up to two million shares of EPG's outstanding common stock from time to time in the open market. Shares repurchased are held in EPG's treasury and are expected to be used in connection with employee stock option plans to minimize dilution to existing shareholders. During 1992, EPG acquired 812,773 shares of its common stock for an aggregate value of $24 million and in the fourth quarter reissued, in connection with employee stock option plans, 628,258 shares of common stock out of treasury stock for an aggregate value of $11 million. The 184,515 remaining shares were reissued through April 1993, in connection with employee stock option plans, for an aggregate value of $5 million.
During 1993, EPG acquired 509,095 shares of its common stock for an aggregate value of $18 million and subsequently reissued, in connection with employee stock option plans, 22,734 shares of its common stock out of treasury stock for an aggregate value of $0.5 million. As of December 31, 1993, EPG had 486,361 shares of treasury stock. In addition, from April 1993 through December 1993, EPG issued 43,394 shares of common stock in connection with employee stock option plans.
A total of 2,300 and 132,700 restricted shares of EPG's common stock were granted to certain employees for 1993 and 1992, respectively. The market value of such shares awarded was approximately $0.1 million and $2.8 million in 1993 and 1992, respectively.
Capital Expenditures
The Company's planned capital expenditures for 1994 of approximately $210 million are primarily for maintenance of business, system expansion and system enhancement. These expenditures are expected to be
financed through internally generated funds. Capital expenditures for 1993 were $164 million compared to $246 million for 1992. The decrease was due primarily to the 1992 completion of system expansion and enhancement projects.
On July 7, 1992, EPG filed an application with FERC, which was amended on November 27, 1992, to expand the delivery capacity of its system in the vicinity of Yuma, Arizona and, through an extension of its system south to San Luis Rio Colorado, Sonora, Mexico, to serve northern Mexican markets. The proposed expansion would provide shippers the opportunity to deliver natural gas to Mexican markets in northern Baja California via new pipeline capacity of 348 MMcf/d. This project is expected to cost approximately $71 million and will be financed through internally generated funds or through short-term borrowings. On November 29, 1993, FERC issued an order which approved the siting, construction and operation of facilities necessary for a border crossing facility in Yuma, Arizona which would connect the proposed extension with pipeline facilities in Mexico. The order also made a preliminary determination on environmental issues. FERC is deferring action on the remainder of the July 7, 1992 filing until EPG demonstrates that it has long-term executed contracts or binding precedent agreements for a substantial amount of the firm capacity of the proposed facilities.
EPG is a member of a five-company consortium that plans to build the proposed Samalayuca II Power Plant near Ciudad Juarez, Mexico. On December 17, 1992, an award for construction was granted to the consortium by the Comision Federal de Electricidad, the Mexican government-owned utility. On March 16, 1993, EPG filed an application with FERC to expand its system in order to provide natural gas service to the proposed Samalayuca II Power Plant and to an existing power plant in the same location. The proposed expansion would provide an additional 300 MMcf/d of capacity at a cost of approximately $57 million and will be financed through internally generated funds or through short-term borrowings. In the November 29, 1993 order, FERC also approved the proposed border crossing facility south of Clint, Texas which would connect EPG's facilities with facilities in Mexico. FERC is deferring action on the remainder of the March 16, 1993 filing until EPG demonstrates that it has long-term executed contracts or binding precedent agreements for a substantial amount of the firm capacity of the proposed facilities.
On December 29, 1993, PG&E, SoCal and the CPUC jointly filed a motion with FERC seeking clarification or rehearing of the November 29, 1993 FERC order for both the Yuma, Arizona and the Samalayuca II Power Plant projects discussed above.
On March 17, 1993, MPC filed an application, which was amended on November 8, 1993, for a certificate of public convenience and necessity to build and operate a 475 MMcf/d expansion of its existing system. The proposed expansion will extend from MPC's existing east lateral located near Bakersfield, California approximately 352 miles northward to the vicinity of Sacramento and the East Bay area near San Francisco. The expansion will also include 56 miles of looping of the existing pipeline along with 207 miles of laterals. The estimated cost of the entire system is $467 million which is expected to be funded primarily through project financing. MPC expects to receive its FERC certificate in early 1994 and put the expansion into service in January 1996.
On December 16, 1993, FERC held a public conference to examine a jurisdictional question raised by CPUC and PG&E regarding MPC's system expansion. The primary issue is whether FERC or CPUC should have jurisdiction over the proposed expansion. Written comments were filed by interested parties on January 10, 1994, with a final decision by FERC expected in early 1994.
Other
In January 1993, EPG experienced flood damage to its pipeline system in the Gila, Arizona area due to heavy rain. Since that time, EPG has been incurring costs for repairs and expects to be reimbursed through its property insurance policies once all repairs have been completed.
RESULTS OF OPERATIONS
Year Ended December 31, 1993 Compared to Year Ended December 31, 1992
Operating revenues for the year ended December 31, 1993 were $106 million higher than for the same period of 1992. New system rates and a new rate design placed into effect February 1, 1993, resulted in a $41 million increase in revenues which was comprised of an increase in reservation revenues of $111 million
offset by a decrease in transportation revenues of $70 million. The consolidation of MPC contributed $27 million to the increase. Higher production area rates and volumes increased revenues by $3 million and $7 million, respectively. Higher sales rates increased revenues by $34 million; however, lower sales volumes offset that increase by $5 million. In addition, the sale of gas in storage contributed $18 million to the increase in revenues; this increase is offset in operating charges. Offsetting the increase in operating revenues was a decrease of $13 million due to lower transportation volumes, a decrease in return on take-or-pay receivables of $4 million and a decrease in liquid revenues of $2 million.
Operating charges were $62 million higher for the year ended December 31, 1993 compared to the same period for 1992. Higher average cost of gas contributed $39 million to the increase. In addition, the sale of gas in storage contributed $18 million to the increase in operating charges; this increase is offset in operating revenues. Higher operation and maintenance costs of $26 million were due primarily to an accrual for estimated take-or-pay undercollections, the consolidation of MPC and increases in employee benefit costs and outside contractors fees, primarily related to environmental clean-up. This increase is partially offset by lower stock related benefit costs. An increase of $3 million in other taxes is primarily due to the consolidation of MPC and an increase in ad valorem taxes. The increase in operating charges was partially offset by lower depreciation rates after giving effect to the rate settlement. Additionally, lower gas sales volumes resulted in a decrease in operating charges of $4 million.
EPG's throughput for 1993 was 1,306 Bcf compared to 1,357 Bcf in 1992. This decrease is due to lower deliveries to the utility electric generation market resulting from the availability of excess hydroelectric power in the California markets. The lower deliveries to California were partially offset by higher throughput to off-system markets.
Interest and debt expense for the year ended December 31, 1993 was $7 million higher than for the same period of 1992 due primarily to the consolidation of MPC.
Allowance for funds used during construction ("AFUDC") was $2 million lower for the year ended December 31, 1993 than for the same period in 1992 due to a decrease in expansion project expenditures during 1993.
Other-net was $6 million higher for the year ended December 31, 1993 compared to the same period for 1992. Contributing to the higher expense was a $6 million increase related to environmental accruals; a $4 million reduction in direct bill interest income; and a $4 million reduction in partnership earnings due to the consolidation of MPC. The increase was offset by lower interest expense of $4 million on tax adjustments and $3 million of interest income related to the recovery of EPG's investment in its underground storage facility.
Year Ended December 31, 1992 Compared to Year Ended December 31, 1991
Operating revenues for 1992 were $68 million higher than 1991. The overall increase in revenues was due primarily to new rates placed into effect on January 1, 1992. The new rates resulted in a $156 million increase in reservation revenues, which reflects the shift from firm sales service to firm transportation service. By unbundling its sales service, the Company's sales occur at the mainline receipt point as opposed to the delivery point. Lower accruals for regulatory issues resulted in an increase in revenues of $42 million. Higher sales volumes resulted in increased revenues of $88 million; however, lower sales rates offset that increase by $23 million. Also offsetting the increases were lower transportation rates which resulted in decreased revenues of $113 million. Other decreases affecting the improved 1992 results were a $30 million decrease in production area revenues resulting from the sale of certain gathering and processing facilities and lower rates, a $28 million decrease in return on take-or-pay receivables, an $11 million decrease in liquid revenues and a $6 million decrease in interest on receivables from customers.
Operating charges were $68 million higher for 1992 compared to 1991. The increase was primarily due to higher purchased gas costs. Higher sales volumes resulted in a $72 million increase in purchased gas costs; however, this increase was partially offset by a $15 million decrease due to lower gas purchase prices. A $12 million increase in depreciation and a $7 million increase in taxes, other than income taxes, both resulting from system expansions, also contributed to the increase in operating charges. An $8 million decrease in operation and maintenance costs was principally due to reductions in fees paid to outside operators and
contractors, partially offset by additional costs allocated to the Company from BR resulting from the separation of the two companies.
Throughput for 1992 was 1,357 Bcf compared to 1,409 Bcf in 1991. The decrease in throughput was principally due to increased competition in the California markets. Lower deliveries to California were partially offset by higher throughput to the East-of-California and off-system markets.
Interest and debt expense was $68 million for 1992 compared with $98 million for 1991. The decrease was primarily due to a $18 million reduction in interest on commercial paper, which balance was repaid in December 1991, and a $17 million reduction in interest on rate refund, which refund was made in October 1991. These decreases were partially offset by an $8 million increase resulting from the cost of the take-or-pay receivables sale.
Interest income from BR was $2 million for 1992 compared with $38 million for 1991. This decrease was due to the dividends declared and paid to BR in December 1991 and in January and February 1992, from the balance owed by BR to EPG under the intercorporate cash management arrangement.
Reported as other-net was $2 million expense for 1992 compared with $12 million income for 1991. Contributing to lower income in 1992 was a $5 million decrease in net gains on dispositions of facilities; a $7 million reduction in MPC partnership earnings resulting from a non-recurring income adjustment in 1991; and a $6 million increase in other interest. A $6 million increase in income from temporary investments and other interest income partially offset the lower income.
OTHER
The Financial Accounting Standards Board issued Statement of Financial Accounting Standards No. 106 ("SFAS 106") requiring companies to account for other post-retirement employee benefits ("OPEBs") (principally retiree medical costs) on an accrual basis versus the pay-as-you-go basis traditionally followed by most United States companies. The Company adopted SFAS 106 effective January 1, 1993.
The Company provides a non-contributory defined benefit postretirement medical plan that covers employees who retired on or before March 1, 1986 and limited postretirement life insurance for employees who retire after January 1, 1985. As such, the Company's obligation to accrue for OPEBs is primarily limited to the fixed population of retirees who retired on or before March 1, 1986. The medical plan is funded to the extent employer contributions are recoverable through rates.
EPG began recovering through its rates the OPEB costs included in the settlement agreement. To the extent actual OPEB costs exceed the amounts reflected in the settlement agreement, a regulatory asset has been recorded. Management expects such amounts to be fully recovered through its rates.
The Financial Accounting Standards Board issued Statement of Financial Accounting Standards No. 112 ("SFAS 112") which requires companies to account for benefits to former or inactive employees after employment but before retirement (referred to in SFAS 112 as "postemployment benefits"). SFAS 112 is effective for the fiscal years beginning after December 15, 1993. Postemployment benefits include every form of benefit provided to former or inactive employees, their beneficiaries and covered dependents. Benefits include, but are not limited to salary continuation, supplemental unemployment benefits, severance benefits, disability-related benefits (including workers' compensation), job training and counseling and continuation of benefits such as health care benefits and life insurance coverage. The cumulative effect at January 1, 1994 of adopting SFAS 112 is estimated to be approximately $8 million. Management expects to fully recover its postemployment benefit costs through rates.
The Revenue Reconciliation Act of 1993, enacted in August 1993, changed the corporate income tax rate from 34 to 35 percent effective January 1, 1993. As a result, the Company's current year provision for income tax expense was adjusted in the third quarter of 1993 by approximately $1 million, of which $0.5 million is related to the balance of deferred income taxes at December 31, 1992. In addition, the balance of accumulated deferred income taxes at January 1, 1993 was increased $5 million in accordance with Statement of Financial Accounting Standards No. 109 ("SFAS 109"), and a corresponding regulatory asset was recorded. Management expects such amounts to be fully recovered through its rates.
Deferred credits, in the accompanying Consolidated Balance Sheet, include excess deferrals resulting from the reduction of the statutory federal tax rate from 46 to 34 percent on July 1, 1987.
ITEM 8.


ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
EL PASO NATURAL GAS COMPANY
CONSOLIDATED STATEMENT OF INCOME (IN THOUSANDS, EXCEPT PER COMMON SHARE AMOUNTS)
See accompanying Accounting Policies and Notes to Consolidated Financial Statements.
EL PASO NATURAL GAS COMPANY
CONSOLIDATED BALANCE SHEET (IN THOUSANDS, EXCEPT PER SHARE AMOUNT)
ASSETS
See accompanying Accounting Policies and Notes to Consolidated Financial Statements.
EL PASO NATURAL GAS COMPANY
CONSOLIDATED STATEMENT OF CASH FLOWS (IN THOUSANDS)
See accompanying Accounting Policies and Notes to Consolidated Financial Statements.
EL PASO NATURAL GAS COMPANY
CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY (DOLLARS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
See accompanying Accounting Policies and Notes to Consolidated Financial Statements.
EL PASO NATURAL GAS COMPANY
ACCOUNTING POLICIES
PRESENTATION AND PRINCIPLES OF CONSOLIDATION
The consolidated financial statements include the accounts of the Company. All significant intercompany transactions of continuing operations are accounted for at market prices and have been eliminated in consolidation. The financial statements for previous periods include certain reclassifications that were made to conform to the current presentation. Such reclassifications have no impact on reported income or stockholders' equity.
On June 1, 1993, the Company acquired from a wholly owned subsidiary of Enron Corp., that subsidiary's 50 percent interest in MPC, a general partnership. This acquisition gives the Company 100 percent ownership of MPC. The operating results of MPC are included in the Company's consolidated results of operations for the months of May 1993 through December 1993. The Company's previously owned 50 percent equity interest in MPC is included in other-net in the accompanying Consolidated Statement of Income.
In September 1991, a dividend of the common stock of EPG's Oil and Gas Operations Segment was made by EPG to its then parent company, TEPCO. The accompanying financial statements and notes reflect the discontinuance of the Oil and Gas Operations Segment.
CASH AND TEMPORARY CASH INVESTMENTS
Short-term investments purchased with an original maturity of three months or less are considered cash equivalents. Through December 31, 1991, cash and temporary cash investments also included excess cash advanced by the Company to its then parent company, BR, under an intercorporate cash management arrangement.
ACCUMULATED PROVISION FOR UNCOLLECTIBLE ACCOUNTS RECEIVABLE
The Company has established a provision for losses on trade accounts receivable which may become uncollectible. Collectibility of trade receivables is reviewed regularly, and the allowance for bad debts is adjusted as necessary under the specific identification method. The balance of this provision at December 31, 1993 and 1992 was $3.9 million and $5.1 million, respectively.
ACCOUNTING FOR REGULATED OPERATIONS
EPG and MPC are subject to the regulations and accounting procedures of FERC and therefore, continue to follow the reporting and accounting requirements of Statement of Financial Accounting Standards No. 71 ("SFAS 71"). Accounting methods for companies subject to cost-of-service regulation may differ from those used by non-regulated companies. However, when the accounting method prescribed by the regulatory authority is used for rate-making, such accounting conforms to the generally accepted accounting principle of matching costs against the revenues to which they apply.
Transactions which have been recorded differently than a non-regulated entity include the following: (i) take-or-pay payments recoverable from customers, based upon transportation volumes, have been recorded as an asset, net of allowance; (ii) losses on reacquired debt have been recorded in other assets and are being amortized over the life of the original or replacement debt; (iii) revenue related to the implementation of SFAS 109 has been recorded as a deferred credit and is being amortized into income; (iv) adjustment to reflect the increase in the federal income tax rate has been recorded in other regulatory assets to be recovered in future rates; (v) excess amounts of OPEB costs have been recorded in other regulatory assets to be recovered in future rates; (vi) a portion of EPG's investment in its underground storage facility has been recorded as an asset and is being recovered in accordance with the settlement agreement; (vii) the cost of equity funds used during construction has been capitalized; (viii) MPC's excess amounts due to straight-line depreciation rates versus approved depreciation rates have been recorded as other regulatory assets to be
EL PASO NATURAL GAS COMPANY
ACCOUNTING POLICIES (CONTINUED)
recovered in future rates and (ix) MPC's deferred taxes on the equity portion of AFUDC have been recorded in other regulatory assets to be recovered in future rates.
ACCOUNTING FOR GAS IMBALANCES
EPG currently accounts for gas imbalances due to or due from shippers and operators. Gas imbalance payables and receivables are maintained at a net legal entity basis in accordance with Statement of Financial Accounting Standards No. 105. Gas imbalances prior to October 1, 1993 are valued at the 1992 average El Paso System index price as prescribed in EPG's tariff. Gas imbalances subsequent to October 1, 1993 are valued at the current quarterly average El Paso System index price.
The Company has established a provision for gas imbalances which may become uncollectible. Collectibility of gas imbalances is reviewed regularly and the provision is adjusted as necessary under the specific identification method. The balance of the provision at December 31, 1993 and 1992 was $5.6 million and $12.1 million, respectively.
INCOME TAXES
Income taxes are based on income reported for tax return purposes and a provision for deferred income taxes. Deferred income taxes are provided to reflect the tax consequences in future years of differences between the financial statement and tax bases of assets and liabilities at each year end. Tax credits are accounted for under the flow-through method, which reduces the provision for income taxes in the year the tax credits first become available.
Pursuant to a tax sharing agreement between EPG and BR covering periods prior to July 1992, EPG is responsible for its tax liabilities and those of its subsidiaries. EPG is required to pay BR its allocable portion of the consolidated federal tax liability and combined state income tax liability.
PROPERTY, PLANT AND EQUIPMENT
Included in the Company's property, plant and equipment is construction work in progress of approximately $53 million and $93 million at December 31, 1993 and 1992, respectively. An allowance for both debt and equity funds used during construction is included in the cost of the Company's property, plant and equipment.
EPG's properties are depreciated using the composite method. Straight-line depreciation rates for 1993 and 1991 were 1.6 percent for transmission facilities. For 1992, the depreciation rate for transmission facilities was 2.67 percent adjusted to 1.6 percent in accordance with the settlement agreement. The depreciation rate for gathering facilities was 3.5 percent for 1993, 1992 and 1991.
MPC's depreciation rates reflect a levelized cost-of-service approach and a 25-year depreciation life. MPC's depreciation rate for its plant during the first 15 years increases gradually from 1.48 percent in 1992 to 8.76 percent in 2007. The depreciation rates are designed to recover approximately 80 percent of MPC's plant balance by March 1, 2007. The depreciation rate related to years 16 through 25 will be determined in future rate proceedings. (See "Accounting for Regulated Operations" of Accounting Policies.)
Additional acquisition cost assigned to utility plant represents EPG's portion of the excess of allocated acquisition cost over historical cost that resulted from the 1983 acquisition of EPG's former parent, TEPCO, by BR's former parent, BNI. These costs are being amortized on a straight-line basis over the estimated remaining life of the properties.
EL PASO NATURAL GAS COMPANY
ACCOUNTING POLICIES (CONTINUED)
Costs of properties that are not operating units, as defined by FERC, which are retired, sold or abandoned are charged or credited, net of salvage, to accumulated depreciation and amortization. Gains or losses on sales of operating units are credited or charged to income.
INVENTORIES
Inventories are carried on either the first-in first-out or average cost method at the lower of cost or market. Gas in storage inventories at December 31, 1992 were carried at cost determined on a last-in first-out basis. During 1993, EPG sold its gas in storage inventory in accordance with the settlement agreement with EPG's customers and FERC staff. Inventories at December 31, 1993 and 1992 consist of the following components:
RECOVERABLE EXCESS GAS COSTS
The cash flow statement for 1991 shows recoveries of recoverable excess gas costs. These costs represent the cumulative excess of actual purchased gas costs over the average of these costs included in EPG's gas sales rates. FERC's August 14, 1991 order provided for a portion of the September 1, 1991 recoverable excess gas costs balance to be offset against refund obligations. The remainder of the costs, $25 million, was recorded against previously established accruals. Effective with the implementation of the 1991 order, EPG no longer records recoverable excess gas costs.
TAKE-OR-PAY SETTLEMENTS
Assets resulting from the resolution of take-or-pay obligations include recoupable take-or-pay prepayments and take-or-pay buy-out and buy-down receivables. Recoupable prepayments result when EPG pays for, but does not physically receive, gas and retains the right to take such gas in the future, generally over five years. Take-or-pay buy-outs and buy-downs represent costs paid to natural gas producers for the termination or modification of gas purchase contracts. In exchange for EPG's agreement to absorb 25 percent of its take-or-pay buy-out and buy-down costs, FERC regulations provide for the direct billing of 25 percent of such costs to EPG's customers. In addition, such regulations allow EPG to recover the remaining 50 percent of its buy-out and buy-down costs through a surcharge added to its transportation rates.
EARNINGS PER SHARE
Earnings per share of common stock is based on the weighted average number of shares of common stock outstanding during the year. The weighted average number of shares of common stock outstanding for 1993, 1992 and 1991 were 37,212,192, 36,049,135 and 31,421,731, respectively. Stock options are the only common stock equivalents and are currently not dilutive.
EL PASO NATURAL GAS COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. RATES AND REGULATORY MATTERS
General Rate Filings and Other
On July 1, 1991, EPG filed for FERC approval of new system rates and placed the proposed new rates into effect on January 1, 1992, subject to refund. On July 31, 1992, EPG again filed for new rates to recover increased costs and return on rate base associated with EPG's expansion and modernization projects. These rates were effective on February 1, 1993, subject to refund. In the July 1992 filing, EPG's rate base increased from $752 million to approximately $1.2 billion. EPG made its compliance filing on December 31, 1992, in accordance with the Restructuring Rules.
In January 1993, EPG, certain of its customers and FERC staff reached a settlement agreement which led to the resolution of the above mentioned rate and restructuring proceedings. The settlement agreement was filed in January 1993 to supersede EPG's December 31, 1992 compliance filing. As required by FERC order, EPG filed revised rates on September 14, 1993, which implemented the settlement agreement effective October 1, 1993. Under the settlement agreement, EPG refunded a total of approximately $56 million, inclusive of interest, in the fourth quarter of 1993. EPG had provided for these rate refunds as revenues were collected.
The settlement agreement provides for the accelerated recovery of a substantial portion of EPG's investment in its underground storage facility. This is being recovered by a demand charge mechanism over the period from October 1, 1993 through December 31, 1996. The amount to be recovered was approximately $56.7 million plus interest accruing beginning February 1, 1993 at the FERC allowed rate, which approximates the prime rate. The amount recovered through December 31, 1993 was $19 million. The outstanding balance at December 31, 1993 was $37 million, of which $12 million is included in other current assets and $25 million is included in other assets in the accompanying Consolidated Balance Sheet. The settlement agreement also established new depreciation rates for certain of EPG's facilities effective January 1, 1992.
On August 14, 1991, FERC approved an order resolving all of the issues in EPG's December 1987 rate case filing and certain other pending matters which became effective on September 1, 1991. The order provided for: (i) the establishment of revised rate levels for the period July 1, 1988 through the effective date of EPG's next rate change, which occurred on January 1, 1992; and (ii) payment of certain refunds for the period July 1, 1988 through August 31, 1991. EPG disbursed to its customers $252 million in October 1991 in accordance with the order. The total refund obligation at September 1, 1991 was $369 million before certain offsets, including an unbilled portion of the $169 million of recoverable excess gas costs. The net refund obligation and the remaining balance of the recoverable excess gas costs, $25 million, were recorded against previously established accruals.
Pursuant to the Restructuring Rules, MPC filed its restructuring plan on November 3, 1992. On March 2, 1993, FERC issued an order essentially approving MPC's compliance filing, subject to changes, which were made in an amended restructuring plan on March 29, 1993. Several of MPC's customers filed protests and requests for rehearing of the March 2, 1993 FERC order. The rehearing requests were denied, and FERC approved the amended restructuring plan on July 9, 1993, with an effective date of August 1, 1993. On October 15, 1993, FERC issued an order which denied requests for rehearing of the July 9, 1993 order. Several of MPC's customers have filed petitions for review of the March 2, 1993, July 9, 1993, and October 15, 1993 orders with the United States Court of Appeals which are currently pending.
The primary issues on appeal pertain to FERC's requirement that MPC's rates for firm transportation service be based upon SFV rate design rather than MFV rate design. The application of SFV rates requires MPC's existing firm shippers to pay a higher proportion of their total transportation rate in the reservation component of the rate, and this increases aggregate transportation charges for low load factor shippers. Such
EL PASO NATURAL GAS COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
shippers have contended that FERC's application of SFV rate design to MPC unlawfully abrogates the rate provisions of MPC's service agreements and constitutes an unlawful rate increase. MPC believes the United States Court of Appeals will uphold SFV rates as applied to MPC.
Take-or-Pay Settlements
Since 1987, EPG has made, or has committed to make, buy-out and buy-down payments totaling $1.5 billion to resolve past and future take-or-pay exposure, to terminate and reform gas purchase contracts, to amend pricing and take provisions of gas purchase contracts and to settle related litigation. In certain cases, EPG resolved claims by making recoupable prepayments. At December 31, 1993 and December 31, 1992, the recoupable prepayment balances were $9 million and $19 million, respectively. These payments resolved virtually all the outstanding producer claims asserted against EPG and terminated or prospectively reformed substantially all of EPG's remaining gas purchase contracts, with the result that EPG no longer has any material take-or-pay exposure.
EPG has filed to recover $1.1 billion of its buy-out and buy-down costs under FERC cost recovery procedures. The collection period for the direct bill portion of the take-or-pay buy-out and buy-down costs extends through May 1994. The collection period for the volumetric surcharge portion of such costs extends through March 1996. Through December 31, 1993, EPG had recovered approximately $1.0 billion; of that recovery, $361 million was collected by direct bill and $682 million by volumetric surcharge. EPG has established a reserve for that portion of the volumetric surcharge receivables balance which is unlikely to be collected over the period through March 1996, based on current throughput projections. The balance of this reserve was $19 million at December 31, 1993.
Under FERC procedures, take-or-pay cost recovery filings may be challenged by pipeline customers on prudence and certain other grounds. In October 1992, FERC approved an order, subject to rehearing, resolving all but one of the outstanding issues regarding EPG's take-or-pay proceedings. The remaining issue involves the claim by several customers that EPG has sought to recover an excessive amount for the value of certain production properties which were transferred to a producer as part of a 1989 take-or-pay settlement. On March 8, 1993, an initial decision from the presiding ALJ was rendered which, if adopted without changes by FERC, would require EPG to refund to or forgo collection from its customers of up to $30 million, plus interest. Exceptions to this initial decision were filed with FERC by both parties on April 7, 1993. On April 27, 1993, briefs opposing exceptions were filed by the same parties as well as by FERC staff. EPG has established adequate reserves for this issue and does not believe that the ultimate outcome will have a materially adverse effect on the Company's financial condition or results of operations.
On January 14, 1992, EPG completed a sale of substantially all of its remaining take-or-pay buy-out and buy-down receivables. The sale totaled $325 million, including $305 million of cash received at closing, which was used to repay $300 million of a payable to BR. The receivables sold in this transaction included $104 million which was recovered through direct bill and $221 million to be recovered through volumetric surcharge. The volumetric surcharge portion of the sale has been accounted for as a financing transaction because EPG is subject to certain recourse provisions related to such receivables. At December 31, 1993 and December 31, 1992, $87 million and $125 million, respectively, of the volumetric surcharge portion of the receivables sold remained outstanding. Amounts collected related to the take-or-pay receivables sold are remitted to the purchasers of the receivables.
2. ACQUISITION
On June 1, 1993, the Company acquired from a wholly owned subsidiary of Enron Corp., that subsidiary's 50 percent interest in MPC for approximately $40 million in cash, representing the approximate book value of
EL PASO NATURAL GAS COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
the investment. The acquisition, which was funded by internally generated cash flow, gives the Company 100 percent ownership of MPC. The acquisition was accounted for using the purchase method.
In conjunction with the acquisition, the following liabilities were assumed:
The following MPC balances are included in the December 31, 1993 Consolidated Balance Sheet of the Company:
The operating results of MPC are included in the Company's consolidated results of operations for the months of May 1993 through December 1993. The Company's previously owned 50 percent equity interest in MPC is included in other-net in the accompanying Consolidated Statement of Income.
The following pro forma summary presents the consolidated results of operations of the Company as if the acquisition had occurred as of January 1, 1993 or January 1, 1992. These pro forma results have been prepared for comparative purposes only and do not purport to be indicative of what may have resulted had the acquisition occurred as of those dates or of results which may occur in the future.
EL PASO NATURAL GAS COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
3. LONG-TERM DEBT
Long-term debt outstanding is as follows:
The following are aggregate maturities of long-term debt for the next five years and in total thereafter:
On December 5, 1991, EPG commenced a tender offer with respect to the 9.45% Notes and 8 5/8% Debentures. Pursuant to the tender offer, in December 1991, EPG purchased $207 million aggregate principal amount of the 9.45% Notes for $228 million and $93 million aggregate principal amount of 8 5/8% Debentures for $93 million. In January 1992, EPG purchased an additional $46 million and $41 million of aggregate principal amounts of the 9.45% Notes and 8 5/8% Debentures, respectively. Funds for these purchases were provided by proceeds from borrowings under the BR Loan Agreements described below. In addition, on December 19, 1991, EPG called for redemption, on January 23, 1992, of all the outstanding 9 5/8% Debentures ($100 million aggregate principal amount) at a price equal to 106.84 percent of their principal amount.
EPG had a Commitment Agreement with BR under which it could borrow up to $300 million. EPG also maintained Loan Agreements with BR under which it could borrow up to $500 million. As of December 31, 1991, $300 million was outstanding under the Commitment Agreement and $325 million was outstanding under the Loan Agreements. In January 1992, EPG borrowed an additional $109 million under the Loan Agreements. Borrowings under the Loan Agreements were used to pay for the purchase of the 9.45% Notes and the 8 5/8% Debentures in December 1991 and January 1992 and the payment of related transaction costs.
In January 1992, EPG issued $575 million principal amount of new debt securities consisting of $100 million of 6.90% Notes due 1997, $215 million of 7 3/4% Notes due 2002 and $260 million of 8 5/8% Debentures
EL PASO NATURAL GAS COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
due 2022. The net proceeds of $569 million received from such issuance were used to repay $434 million of borrowings under the Loan Agreements with BR, to redeem $107 million of 9 5/8% Debentures and for general corporate purposes ($28 million) including costs related to the transactions discussed above.
EPG repaid its outstanding commercial paper in December 1991 with borrowings under the Commitment Agreement with BR. The proceeds from the sale of the take-or-pay receivables were used to repay the borrowings under the Commitment Agreement with BR.
The Commitment Agreement and the Loan Agreements with BR were terminated prior to the completion of the Offering. In February 1992, EPG established a $300 million revolving credit facility with a group of banks which facility expires in March 1996. As of December 31, 1993, there were no borrowings outstanding under this facility. Approximately $1 million of commercial paper was outstanding as of December 31, 1993.
EPG must comply with various restrictive covenants contained in its debt agreements which include, among others, maintaining consolidated tangible net worth (as defined in the agreements) of at least $400 million. Also, EPG's consolidated debt and guaranties to capitalization ratio cannot exceed 70 percent. Furthermore, certain EPG subsidiaries (other than any project financing subsidiary, as defined in the agreements) may not incur debt obligations which would exceed $75 million in the aggregate. As of December 31, 1993, EPG's consolidated tangible net worth exceeded the minimum restrictive covenant requirement by $298 million, its consolidated debt and guaranties to capitalization ratio was 47 percent and there were no subsidiary debt obligations of those subsidiaries limited by the debt agreements.
On September 30, 1991, MPC entered into a credit agreement ("Credit Agreement") with a group of banks which provided a 15 year project financing loan to MPC of up to $180 million. Total outstanding loan balances under the Credit Agreement were $165 million and $170 million at December 31, 1993 and 1992, respectively. The loan is repayable in semiannual installments over the period to March 31, 2007. Interest on the loan is payable quarterly.
MPC has entered into interest rate swap agreements which effectively convert $114.3 million of the current loan balance from floating-rate debt to fixed-rate debt. MPC makes payments to counterparties at fixed rates and in return receives payments at floating rates. Substantially all of the remaining $50.5 million of loan principal had interest rates ranging from 3.9 percent to 4.3 percent during 1993. With the impact of the interest rate swap agreements, the overall effective rate on the loan was approximately 7.6 percent during 1993 and 1992.
Borrowings under the Credit Agreement are collateralized by a priority interest in the Company's partnership interests and certain other distributed and undistributed partnership property. The Credit Agreement also contains covenants relating to, among other things, partnership distributions and additional indebtedness.
EL PASO NATURAL GAS COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
4. ENVIRONMENTAL
Accruals for environmental compliance costs are established when environmental assessments and/or remediation are probable, and when costs can be reasonably estimated. As of December 31, 1993, EPG had a reserve of $38 million for the following environmental contingencies with income statement impact:
1 -- EPG has been conducting remediation of PCB contamination at its facilities. The majority of the required PCB remediation has been completed. Future PCB remediation costs are estimated to range between $8 million and $11 million over the next five years.
2 -- EPG executed an Administrative Order on Consent with EPA on June 25, 1993 to conduct a RI/FS for a BI site located in Statesville, North Carolina, that has been identified for cleanup. BI and EPG have entered into an agreement to jointly fund the RI/FS for the site. EPG's share of the potential remediation costs is estimated to be between $17 million and $20 million over a 30 year period.
3 -- On November 2, 1993, in accordance with an EPA order, EPG and ARCO submitted work plans for remediation of the subsurface at the Prewitt Refinery in McKinley County, New Mexico. EPG and ARCO have a cost sharing agreement to each pay one-half of any remediation costs at this site. EPG's share of the remediation costs is estimated to be between $10 million and $20 million over a 30 year period.
4 -- EPG is involved in other environmental assessment and remediation activities which include two additional CERCLA sites (Fountain Inn, South Carolina and Odessa, Texas) and one state Superfund site (Etowah, Tennessee). The amount reserved as of December 31, 1993 will cover these and other small environmental assessments and other remediation projects.
EPG also has potential expenditures, of a capital nature, for the following environmental projects:
1 -- EPG has analyzed CAAA, and believes that these rules will impact the Company's operations primarily in the following areas: (i) potential required reductions in the emissions of NOx in non-attainment areas; (ii) the requirement for air emissions permitting of existing facilities; and (iii) enhanced monitoring of air emissions. The Company anticipates capitalizing the equipment costs associated with complying with CAAA and estimates that approximately $5 million to $27 million will be spent during the 1995 through 1997 time frame. However, EPA's proposed enhanced monitoring rules, when finalized, could potentially impose greater costs to the Company.
2 -- EPG has been conducting remediation of mercury contamination at certain facilities and is replacing mercury containing meters with dry flow devices. The remaining remediation costs are estimated to be between $8 million and $12 million, most of which will be incurred over the next two years. EPG will close and retire about 5,400 earthen siphon/dehydration pits in the San Juan Basin as recently required by certain environmental regulations. EPG estimates costs of approximately $17 million to $25 million to retire these pits over the next two years. The mercury remediation and pit closure costs, which are associated with the retirement of equipment, will be recorded as adjustments to accumulated depreciation, as required by regulatory accounting.
On December 21, 1993, EPA issued EPG a Notice of Liability for the CSMRI site in Golden, Colorado. Because EPA has not yet determined the volume of hazardous substances sent to the site by all parties, there is no way to estimate EPG's potential share of remediation costs. However, based on the volumes EPA presently lists as contributed by EPG and other potentially responsible parties, it appears that EPG is a minor contributor.
It is possible that new information or future developments could require the Company to reassess its potential exposure related to environmental matters. As such information or developments occur, contingency amounts will be adjusted accordingly.
EL PASO NATURAL GAS COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
5. CORPORATE REORGANIZATION
During 1992 and 1991, EPG completed several transactions in preparation for its separation from BR. Among these transactions was the transfer of the net assets of the Company's Oil and Gas Operations Segment to TEPCO, which is reported as discontinued operations.
In May 1991, EPG declared and paid a dividend of $175 million to TEPCO. Effective August 31, 1991, EPG contributed its oil and gas cost-of-service production properties to EPPC. In September 1991, EPG declared a dividend of all its Oil and Gas Operations Segment to TEPCO. The total amount of that dividend was $925 million, $500 million of which was a return of capital and, accordingly, reduced additional paid-in-capital. TEPCO declared a dividend of 100 percent of the common stock of EPG to BR, TEPCO's parent company, effective September 2, 1991.
In December 1991, EPG declared and paid a dividend to BR of $55 million. In January and February 1992, EPG declared and paid dividends totaling $274 million to BR. These dividends were paid from the balance owed to EPG under an intercorporate cash management arrangement.
In March 1992, EPG completed the Offering. The proceeds from the Offering, net of related costs, totaled approximately $96 million. On June 30, 1992, BR distributed its 31.4 million shares of EPG's common stock, which represented approximately 85 percent of EPG's outstanding common stock, to BR shareholders. As a result, BR no longer retains an ownership interest in EPG.
Discontinued Operations
The following results of operations of the Oil and Gas Operations Segment are presented as income from discontinued operations, net of income taxes, in the accompanying Consolidated Statement of Income:
The operations of EPG's cost-of-service production properties that were contributed to EPPC on August 31, 1991, were reflected in the Company's Natural Gas Operations Segment and are therefore not included in income from discontinued operations. The net book value of the production properties was $197 million on August 31, 1991. The earnings related to the cost-of-service production properties are included in income from continuing operations and are not material.
6. CAPITAL STOCK
Under EPG's employee stock option plans, options may be granted to officers and key employees at fair market value on the date of grant, exercisable in whole or part by the optionee after completion of one to three years of continuous employment from the grant date. Options are also granted to Directors at fair market value on the date of grant and are exercisable immediately. Under the terms of these plans, EPG may grant stock appreciation rights ("SARs") to certain holders of stock options. SARs are subject to the same terms and conditions as the related stock options. The stock option holder who has been granted tandem SARs can elect to exercise either an option or a SAR. SARs entitle an option holder to receive a payment equal to the difference between the option price and the fair market value of the common stock of EPG at the date of
EL PASO NATURAL GAS COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
exercise of the SAR. To the extent a SAR is exercised, the related option is cancelled, and to the extent an option is exercised, the related SAR is cancelled.
On January 15, 1992, the Board of Directors of EPG granted options exercisable for 722,300 shares of common stock effective upon the closing of the Offering. One-third of the options became exercisable on December 19, 1992; one-third became exercisable on January 15, 1994; and one-third will become exercisable on January 15, 1995. On January 12, 1993, EPG's Board of Directors granted stock options exercisable for 554,000 shares of common stock at $30.81 per share. The stock options vested on January 12, 1994. On March 18, 1993, 3,000 stock options were granted at $36.19 per share and became exercisable immediately. On May 1, 1993, 3,000 stock options were granted at $38.19 per share and became exercisable immediately. On July 22, 1993, 15,000 stock options were granted at $37.25 per share and vested on January 22, 1994. On January 14, 1994, EPG's Board of Directors granted stock options exercisable for 655,100 shares of common stock at $36.875 per share which will vest on January 14, 1995. In addition, stock options were granted for 3,000 shares of common stock at $36.875 per share, which became exercisable immediately.
After the Offering, 597,838 BR stock options and 100,730 BR SARs, at prices ranging from $25.50 to $44.75 per share, were converted to EPG stock options and SARs at prices ranging from $13.51 to $22.91 per share.
Activity in EPG's stock option plans for 1992 and 1993 was as follows:
At December 31, 1993, 321,286 stock options and 70,154 SARs were exercisable at prices ranging from $13.51 to $38.19 per share. At December 31, 1992, 568,422 stock options and 105,203 SARs were exercisable at prices ranging from $13.51 to $25.69 per share.
SARs shown as cancelled in the table above were cancelled when the underlying stock options were exercised. Stock options shown as cancelled in the table above may be a result of the tandem SAR being exercised.
The maximum number of shares for which stock options may be granted under EPG's stock option plans are approximately seven million shares of common stock, to be issued from shares held in EPG's treasury or out of authorized but unissued shares of EPG's common stock, or partly out of each, as shall be determined by EPG's Board of Directors.
On October 22, 1992, EPG's Board of Directors authorized the repurchase of up to two million shares of EPG's outstanding shares of common stock from time to time in the open market. Shares repurchased are held in EPG's treasury and are expected to be used in connection with EPG employee stock option plans to minimize dilution to existing shareholders. During 1992, EPG acquired 812,773 shares of its common stock
EL PASO NATURAL GAS COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
for an aggregate value of $24 million and in the fourth quarter reissued, in connection with EPG's employee stock option plans, 628,258 shares of common stock out of treasury stock for an aggregate value of $11 million. The 184,515 remaining shares were reissued through April 1993, in connection with employee stock option plans, for an aggregate value of $5 million.
During 1993, EPG acquired 509,095 shares of its common stock for an aggregate value of $18 million and subsequently reissued, in connection with employee stock option plans, 22,734 shares of its common stock out of treasury stock for an aggregate value of $0.5 million. As of December 31, 1993, EPG had 486,361 shares of treasury stock. In addition, from April 1993 through December 1993, EPG issued 43,394 shares of common stock in connection with EPG's employee stock option plans.
A total of 2,300 and 132,700 restricted shares of EPG's common stock were granted to certain employees for 1993 and 1992 respectively. The market value of such shares awarded was approximately $0.1 million and $2.8 million in 1993 and 1992, respectively.
EPG has 25,000,000 shares of authorized preferred stock, par value $0.01 per share, none of which have been issued.
For the year ended December 31, 1993, primary earnings per share of common stock was $2.46 per share. If stock options exercised in 1993 had been exercised on January 1, 1993, earnings per share would have remained at the same level. For the year ended December 31, 1992, primary earnings per share of common stock was $2.12 per share. If stock options exercised in December 1992 had been exercised on January 1, 1992, earnings per share of common stock for 1992 would have been $2.08.
7. PROPERTY, PLANT AND EQUIPMENT
Property, plant and equipment consists of the following:
The December 31, 1993 balance of property, plant and equipment, net includes $224 million for MPC.
EL PASO NATURAL GAS COMPANY NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
8. INCOME TAXES
The following table reflects the components of income tax expense.
Investment tax credit as shown above is net of estimated recapture, if any, provided for during each year.
The following table reflects the components of deferred tax expense (benefit):
The following table reflects the components of the net deferred tax liability:
EL PASO NATURAL GAS COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
Tax expense of the Company differs from the amount computed by applying the statutory federal income tax rate to income from continuing operations before income taxes. The reasons for this difference are as follows:
The Revenue Reconciliation Act of 1993, enacted in August 1993, changed the corporate income tax rate from 34 to 35 percent effective January 1, 1993. As a result, the Company's current year provision for income tax expense was adjusted in the third quarter of 1993 by approximately $1 million, of which $0.5 million is related to the balance of deferred income taxes at December 31, 1992. In addition, the balance of accumulated deferred income taxes at January 1, 1993 was increased $5 million in accordance with SFAS 109, and a corresponding regulatory asset was recorded. Management expects such amounts to be fully recovered through its rates.
Deferred credits, in the accompanying Consolidated Balance Sheet, include excess deferrals resulting from the reduction of the statutory federal tax rate from 46 to 34 percent on July 1, 1987.
9. PENSION PLANS
The Company previously participated in BR's pension plans, which were non-contributory defined benefit plans covering substantially all employees. The benefits were based on the number of years of credited service and the highest five-year average compensation levels. Contributions to the plans were determined by BR and were limited to amounts that were deductible for tax purposes.
In January 1992, the Company established its own pension plans with provisions similar to those of the BR plans. Upon separation from BR, the Company's qualified pension plan received assets equal to the accumulated benefit obligation relating to the Company's employees.
EL PASO NATURAL GAS COMPANY NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
The following table sets forth the qualified plan's funded status and amounts recognized in the Company's Consolidated Balance Sheet at December 31, 1993 and December 31, 1992:
The following table reflects the components of net periodic pension cost:
The 1993 weighted average discount rate and rate of increase in future compensation levels used in determining the actuarial present value of the projected benefit obligation were 7.5 percent and 5.0 percent, respectively. The 1993 weighted average expected long-term rate of return on plan assets was 9.0 percent. The 1992 weighted average discount rate and rate of increase in future compensation levels used in determining the actuarial present value of the projected benefit obligation were 8.5 percent and 5.0 percent, respectively. The 1992 weighted average expected long-term rate of return on plan assets was 9.0 percent. Contributions to the plans are limited to amounts currently deductible for tax purposes. The accumulated vested benefit obligation is the actuarial present value of the vested benefits to which the employee is currently entitled, but it is based on the employee's expected date of termination.
10. POSTRETIREMENT AND POSTEMPLOYMENT BENEFITS OTHER THAN PENSIONS
The Financial Accounting Standards Board issued SFAS 106 requiring companies to account for OPEBs, (principally retiree medical costs) on an accrual basis versus the pay-as-you-go basis traditionally followed by most United States companies. The Company adopted SFAS 106 effective January 1, 1993.
The Company provides a non-contributory defined benefit postretirement medical plan that covers employees who retired on or before March 1, 1986 and limited postretirement life insurance for employees who retire after January 1, 1985. As such, the Company's obligation to accrue for OPEBs is primarily limited to the fixed population of retirees who retired on or before March 1, 1986. The medical plan is funded to the extent employer contributions are recoverable through rates.
EL PASO NATURAL GAS COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
EPG began recovering through its rates the OPEB costs included in the settlement agreement. To the extent actual OPEB costs exceed the amounts reflected in the settlement agreement, a regulatory asset has been recorded. Management expects such amounts to be fully recovered through its rates.
The following table sets forth the plan's funded status and amounts recognized in the Company's Consolidated Balance Sheet at December 31, 1993:
The following table reflects the components of net periodic postretirement benefit cost for the twelve months ended December 31, 1993:
A 13.5 percent annual rate of increase in the per capita costs of covered health care benefits was assumed for 1994, gradually decreasing to 6 percent by the year 2002. Increasing the assumed health care cost trend rates by one percentage point in each year would increase the accumulated postretirement benefit obligation as of December 31, 1993 by approximately $13.9 million and increase the interest cost components of net periodic postretirement benefit cost for 1993 by approximately $1 million. A discount rate of 7.5 percent was used to determine the accumulated postretirement benefit obligation.
The Financial Accounting Standards Board issued SFAS 112 which requires companies to account for benefits to former or inactive employees after employment but before retirement (referred to in SFAS 112 as "postemployment benefits"). SFAS 112 is effective for the fiscal years beginning after December 15, 1993. Postemployment benefits include every form of benefit provided to former or inactive employees, their beneficiaries and covered dependents. Benefits include, but are not limited to salary continuation, supplemental unemployment benefits, severance benefits, disability-related benefits (including workers' compensation), job training and counseling, and continuation of benefits such as health care benefits and life insurance coverage. The cumulative effect at January 1, 1994 of adopting SFAS 112 is estimated to be approximately $8 million. Management expects to fully recover its postemployment benefits costs through rates.
11. COMMITMENTS AND CONTINGENT LIABILITIES
See Note 1 and 4 of Notes to Consolidated Financial Statements, Item 1 and 2 -- Business and Properties, El Paso Natural Gas Company, Master Separation Agreement and Item 3 -- Legal Proceedings for discussions of litigation and other contingencies.
EL PASO NATURAL GAS COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
Minimum annual rental commitments at December 31, 1993, are as follows:
Rental expense for operating leases was $8 million in 1993 and 1992, and $7 million in 1991.
EPG has a lease agreement for approximately 391,207 square feet of space which is currently used as the Company headquarters and its gas control center. The lease expires on May 31, 2007, and grants EPG two ten year options to extend the term of the lease.
Management is not aware of other commitments or contingent liabilities which would have a materially adverse effect on the Company's financial condition or results of operations.
12. SIGNIFICANT CUSTOMERS
The Company had gross revenues equal to or in excess of 10 percent of consolidated operating revenues from the following customers:
13. SUPPLEMENTAL CASH FLOW INFORMATION
The following provides additional information concerning supplemental disclosures of cash flow activities:
14. RELATED PARTY TRANSACTIONS
In 1991 and for the first six months of 1992, BR and Meridian were considered related parties of EPG. Through February 1992, EPG participated in an intercorporate cash management arrangement with BR, pursuant to which excess cash balances from each of BR's operating subsidiaries were advanced to BR on a daily basis and cash requirements of BR's operating subsidiaries were funded daily through advances from BR. Balances under the arrangement accrued interest at rates approximating short-term market rates. In January and February 1992, EPG declared and paid dividends totaling $274 million to BR from the balance owed to EPG under the intercorporate cash management arrangement.
On April 8, 1992, EPG's Board of Directors declared a quarterly dividend on common stock of $0.25 per share to the June 1, 1992 stockholders of record. EPG paid the dividend on June 19, 1992, in the amount of $9.3 million, $8 million of which was paid to BR.
EL PASO NATURAL GAS COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
Revenues associated with the transportation of gas for Meridian by EPG were $15 million for the six months ended June 30, 1992, and $47 million for the year ended December 31, 1991.
Operating revenues include $26 million related to transactions with the discontinued Oil and Gas Operations Segment in 1991. Operating charges related to transactions with the discontinued segment were less than $1 million in 1991. In May 1991, EPG declared and paid a dividend to TEPCO of $175 million and in December 1991 declared and paid a $55 million dividend to BR.
Certain BR corporate overhead expenses were allocated to EPG. The allocated amounts were not material and management believes the allocation methodology was appropriate.
15. FINANCIAL INSTRUMENTS
Fair Value
The following disclosure of the estimated fair value of financial instruments was made in accordance with the requirements of Statement of Financial Accounting Standards No. 107 ("SFAS 107"). The estimated fair value amounts have been determined by the Company using available market information and valuation methodologies.
As of December 31, 1993, the carrying amounts of the various financial instruments employed by the Company, including cash, cash equivalents, short-term borrowings, and trade receivables and payables are representative of fair value because of the short maturity of these instruments. The carrying amounts and estimated fair values of the Company's other financial instruments at December 31, 1993 are as follows:
The fair value of the Company's long-term debt has been estimated based on quoted market prices for the same or similar issues. The fair value of interest rate swap agreements is the amount at which they could be settled, based on estimates obtained from dealers.
Off-Balance Sheet Risk
During 1993, EPG and EPGM entered into certain price swap agreements to, in effect, hedge the market risk caused by fluctuations in the price of natural gas. The agreements call for EPG and EPGM to make payments to or receive payments from the other parties based upon the differential between a fixed and a variable price for natural gas as specified by the contract. The current price swap agreements run for periods of up to five years and had a notional contract amount of approximately $30 million at December 31, 1993. While EPG and EPGM's notional contract amounts are used to express the magnitude of price swap agreements, the amounts potentially subject to credit risk, in the event of non-performance by the other parties, are substantially smaller. EPG and EPGM do not anticipate non-performance by the other parties.
MPC has entered into interest rate swap agreements which effectively convert $114.3 million of floating-rate debt to fixed-rate debt. MPC makes payments to counterparties at fixed rates and in return receives payments at floating rates.
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors and Stockholders El Paso Natural Gas Company
We have audited the consolidated financial statements and the financial statement schedules of El Paso Natural Gas Company listed in Item 14(a) of this Form 10-K. These financial statements and financial statement schedules are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements and financial statement schedules 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 financial statements referred to above present fairly, in all material respects, the consolidated financial position of El Paso Natural Gas Company as of December 31, 1993 and 1992, and the consolidated results of its operations and its cash flows for each of the three years in the period ended December 31, 1993, in conformity with generally accepted accounting principles. In addition, in our opinion, the financial statement schedules referred to above, when considered in relation to the basic financial statements taken as a whole, present fairly, in all material respects, the information required to be included therein.
COOPERS & LYBRAND
El Paso, Texas January 21, 1994
EL PASO NATURAL GAS COMPANY
CONSOLIDATED QUARTERLY INFORMATION
YEARS ENDED DECEMBER 31, 1993 AND 1992 (IN THOUSANDS, EXCEPT PER SHARE AMOUNTS) (UNAUDITED)
SCHEDULE IV
EL PASO NATURAL GAS COMPANY
INDEBTEDNESS OF AND TO RELATED PARTIES -- NOT CURRENT
YEARS ENDED DECEMBER 31, 1993, 1992 AND 1991 (IN THOUSANDS)
SCHEDULE V
EL PASO NATURAL GAS COMPANY
PROPERTY, PLANT AND EQUIPMENT
YEARS ENDED DECEMBER 31, 1993, 1992 AND 1991 (IN THOUSANDS)
For depreciation rates and methods, see Accounting Policies.
(a) Primarily from system enhancement and maintenance projects.
(b) Primarily the consolidation of MPC's $242 million of property, plant and equipment and reclassification of $46 million of underground storage facility.
(c) Primarily from major system expansion and enhancement projects.
(d) Primarily reclassification of $31 million of gas in storage inventory consistent with the August 14, 1991 FERC order.
SCHEDULE VI
EL PASO NATURAL GAS COMPANY
ACCUMULATED DEPRECIATION, DEPLETION AND AMORTIZATION OF PROPERTY, PLANT AND EQUIPMENT
YEARS ENDED DECEMBER 31, 1993, 1992 AND 1991 (IN THOUSANDS)
SCHEDULE VIII
EL PASO NATURAL GAS COMPANY
VALUATION AND QUALIFYING ACCOUNTS
YEARS ENDED DECEMBER 31, 1993, 1992 AND 1991 (IN THOUSANDS)
- ---------------
(a) Presentation of prior years has been changed to conform to current year presentation.
(b) Primarily accounts charged off.
(c) Primarily accounts recovered.
SCHEDULE X
EL PASO NATURAL GAS COMPANY
SUPPLEMENTARY INCOME STATEMENT INFORMATION
YEARS ENDED DECEMBER 31, 1993, 1992 AND 1991 (IN THOUSANDS)
- ------------
Note -- Items omitted are either less than 1 percent of consolidated revenues or are disclosed elsewhere in the consolidated financial statements or notes thereto.
ITEM 9.

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



ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
The information appearing under the caption "Proposal No. 1 -- Election of Directors" in the Company's proxy statement for the 1994 Annual Meeting of Stockholders (the "Proxy Statement") is incorporated herein by reference. Information regarding executive officers of the Company is presented in Items 1 and 2 of this Form 10-K under the caption "Executive Officers of the Registrant."
ITEM 11.

ITEM 11. EXECUTIVE COMPENSATION
Information appearing under the caption "Executive Compensation" in the Proxy Statement is incorporated herein by reference.
ITEM 12.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
Information appearing under the caption "Security Ownership of a Certain Beneficial Owner and Management" in the Proxy Statement is incorporated herein by reference.
ITEM 13.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
None.
PART IV
ITEM 14.

ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K
(A) THE FOLLOWING DOCUMENTS ARE FILED AS A PART OF THIS REPORT:
1. Financial statements.
The following consolidated financial statements of the Company are included in Part II, Item 8 of this report:
2. Financial statement schedules and supplementary information required to be submitted.
(B) REPORTS ON FORM 8-K:
No reports on Form 8-K were filed by the Registrant during the quarter ended December 31, 1993.
EL PASO NATURAL GAS COMPANY
EXHIBIT LIST DECEMBER 31, 1993
Each exhibit identified on this Exhibit List is filed as a part of this report. Exhibits not incorporated by reference to a prior filing are designated by an asterisk; all exhibits not so designated are incorporated herein by reference to a prior filing as indicated.
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, El Paso Natural Gas Company has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
EL PASO NATURAL GAS COMPANY Registrant
By /s/ WILLIAM A. WISE William A. Wise Chairman of the Board, President and Chief Executive Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of El Paso Natural Gas Company and in the capacities and on the date indicated:
INDEX TO EXHIBITS
Each exhibit set forth below is filed as part of this report.