-----BEGIN PRIVACY-ENHANCED MESSAGE----- Proc-Type: 2001,MIC-CLEAR Originator-Name: webmaster@www.sec.gov Originator-Key-Asymmetric: MFgwCgYEVQgBAQICAf8DSgAwRwJAW2sNKK9AVtBzYZmr6aGjlWyK3XmZv3dTINen TWSM7vrzLADbmYQaionwg5sDW3P6oaM5D3tdezXMm7z1T+B+twIDAQAB MIC-Info: RSA-MD5,RSA, FyRNhSsTRI094c7EPK17JRBqKwAfCQzHWWqaPtoyDdYfo7e0wYcB7wWPBAcGc3i/ JjLibdkjZ/9Uyi8NiHg07w== 0000950134-96-000925.txt : 19960328 0000950134-96-000925.hdr.sgml : 19960328 ACCESSION NUMBER: 0000950134-96-000925 CONFORMED SUBMISSION TYPE: 10-K PUBLIC DOCUMENT COUNT: 3 CONFORMED PERIOD OF REPORT: 19951231 FILED AS OF DATE: 19960327 SROS: NYSE FILER: COMPANY DATA: COMPANY CONFORMED NAME: NORTHWEST PIPELINE CORP CENTRAL INDEX KEY: 0000110019 STANDARD INDUSTRIAL CLASSIFICATION: NATURAL GAS TRANSMISSION [4922] IRS NUMBER: 870269236 STATE OF INCORPORATION: DE FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-K SEC ACT: 1934 Act SEC FILE NUMBER: 001-07414 FILM NUMBER: 96539098 BUSINESS ADDRESS: STREET 1: 295 CHIPETA WAY CITY: SALT LAKE CITY STATE: UT ZIP: 84158-0900 BUSINESS PHONE: 8015838800 MAIL ADDRESS: STREET 1: 295 CHIPETA WAY CITY: SALT LAKE STATE: UT ZIP: 84158 10-K 1 FORM 10-K FOR YEAR ENDED DECEMBER 31, 1995 1 UNITED STATES SECURITIES AND EXCHANGE COMMISSION WASHINGTON, D. C. 20549 FORM 10-K _________________ [X] Annual Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 (Fee Required) For the fiscal year ended December 31, 1995 or [ ] Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 (No Fee Required) For the Transition Period from __________________ to _______________________ Commission File Number 1-7414 NORTHWEST PIPELINE CORPORATION (Exact name of registrant as specified in its charter) DELAWARE 87-0269236 (State or other jurisdiction of (I.R.S. Employer incorporation or organization) Identification No.) 295 Chipeta Way, Salt Lake City, Utah 84108 (Address of principal executive offices) (Zip Code) (801) 583-8800 (Registrant's telephone number, including area code) Securities Registered Pursuant to Section 12(b) of the Act: Name of Each Exchange Title of Each Class On Which Registered -------------------------- ---------------------------- 10.65% Debentures due 2018 New York Stock Exchange 9% Debentures due 2022 New York Stock Exchange 7.125% Debentures due 2025 New York Stock Exchange Securities Registered Pursuant to Section 12(g) of the Act: None Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes [X] No[ ] Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this form 10-K. [X] State the aggregate market value of the voting stock held by non-affiliates of the registrant. No voting stock of registrant is held by non-affiliates. Indicate the number of shares outstanding of each of the registrant's classes of common stock, as of the latest practicable date. Class Outstanding at March 27, 1996 - --------------------------- ----------------------------- Common stock, $1 par value 1,000 shares Documents Incorporated by References: None The registrant meets the conditions set forth in General Instruction (J)(1)(a) and (b) of Form 10-K and is therefore filing this form 10-K with the reduced disclosure format. 2 TABLE OF CONTENTS PART I
Heading Page - ------- ---- Items 1. and 2. BUSINESS AND PROPERTIES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 Item 3. LEGAL PROCEEDINGS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 Item 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS (Omitted) . . . . . . . . . . . . . . 4 PART II Item 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCK- HOLDER MATTERS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 Item 6. SELECTED FINANCIAL DATA (Omitted) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA . . . . . . . . . . . . . . . . . . . . . . 8 Item 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25 PART III Item 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT (Omitted) . . . . . . . . . . . . . . 26 Item 11. EXECUTIVE COMPENSATION (Omitted) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 Item 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT (Omitted) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 Item 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS (Omitted) . . . . . . . . . . . . . . . . 26 PART IV Item 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26
3 NORTHWEST PIPELINE CORPORATION FORM 10-K PART I ITEMS 1 AND 2. BUSINESS AND PROPERTIES BUSINESS ENVIRONMENT Northwest Pipeline Corporation ("Pipeline") is wholly owned by The Williams Companies, Inc. ("Williams"). Pipeline owns and operates an interstate natural gas pipeline system, including facilities for mainline transmission and gas storage. Pipeline's transmission and storage activities are subject to regulation by the Federal Energy Regulatory Commission ("FERC") under the Natural Gas Act of 1938 ("Natural Gas Act") and under the Natural Gas Policy Act of 1978 ("NGPA"), and, as such, its rates and charges for the transportation of natural gas in interstate commerce, the extension, enlargement or abandonment of its jurisdictional facilities, and its accounting, among other things, are subject to regulation. Pipeline has significant future opportunities to provide service to meet the demands of growing gas markets. Pipeline's geographical position allows access to the incremental sources of supply required for these markets. TRANSMISSION Pipeline owns and operates a pipeline system for the mainline transmission of natural gas. This system extends from the San Juan Basin in northwestern New Mexico and southwestern Colorado through Colorado, Utah, Wyoming, Idaho, Oregon and Washington to a point on the Canadian border near Sumas, Washington. At December 31, 1995, Pipeline's system, having an aggregate mainline deliverability of approximately 2.6 Bcf* of gas per day, was composed of approximately 3,900 miles of mainline and branch transmission pipelines, and 43 mainline compressor stations with a combined capacity of approximately 306,000 horsepower. Pipeline operates under an open-access transportation certificate wherein gas is transported for third party shippers. Pipeline's transportation services (firm and interruptible) represented 100% of its total throughput in 1995 and 1994, reflecting the implementation of FERC's Order No. 636 during 1993. In 1995, Pipeline transported natural gas for a total of 127 customers. Pipeline provides services for markets in California, New Mexico, Colorado, Utah, Nevada, Wyoming, Idaho, Oregon and Washington. Transportation customers include distribution companies, municipalities, interstate and intrastate pipelines, gas marketers and direct industrial users. The two largest transportation customers of Pipeline in 1995 accounted for approximately 11.6% and 10.1%, respectively, of total transportation volumes. No other customer accounted for more than 10% of total volumes moved on Pipeline's mainline system. Pipeline's firm transportation agreements are generally long-term agreements with various expiration dates and account for the major portion of Pipeline's business. Additionally, Pipeline offers interruptible transportation service under agreements that are generally short term. No other interstate natural gas pipeline company presently provides significant service to Pipeline's primary gas consumer market area. However, competition with other interstate carriers exists for expansion markets. Competition also exists with alternate fuels. Electricity and distillate fuel oil are the primary alternate energy sources in the residential and commercial markets. In the industrial markets, high sulfur residual fuel oil is the main alternate fuel source. - --------------------- * The term "Mcf" means thousand cubic feet, "MMcf" means million cubic feet and "Bcf" means billion cubic feet. All volumes of natural gas are stated at a pressure base of 14.73 pounds per square inch absolute at 60 degrees Fahrenheit. The term "MMBtu" means one million British Thermal Units and "TBtu" means one trillion British Thermal Units. -1- 4 Northwest Pipeline completed mainline expansion projects that were placed into service on December 1, 1995. These expansion projects increased system capacity by an additional 144 MMcf of gas per day and added 14,820 horsepower of new compression and 44 miles of pipeline loop line to Northwest Pipeline's system. Pipeline believes that strong economies in the Pacific Northwest and the growing preference for natural gas in response to environmental concerns support future expansions of its mainline capacity, although no significant expansions are in the development stage at the present time. CONTRACT REFORMATION Pursuant to FERC policy, Pipeline filed and received approval to recover a portion of contract reformation costs through direct bills to former sales customers and through surcharges to transportation as well as sales commodity rates. Recovery of these amounts was completed in 1994. The FERC initially approved a method for Pipeline to direct bill its contract reformation costs, but when challenged on appeal, sought a remand to reassess such method. Pipeline received an order from the FERC that required a different allocation of such costs and rebilled its customers accordingly. This reallocation has had no significant financial impact. GAS STORAGE Underground gas storage facilities enable Pipeline to balance daily receipts and deliveries and provide storage services to certain major customers. Pipeline has a contract with a third party, under which gas storage services are provided to Pipeline in an underground storage reservoir in the Clay Basin Field located in Daggett County, Utah. Pipeline injects its own gas into the storage reservoir and is authorized to utilize the Clay Basin Field at a seasonal storage level of 6.1 Bcf of working gas, with a firm delivery capability of 51 MMcf of gas per day. Pipeline owns a one-third interest in the Jackson Prairie underground storage facility located near Chehalis, Washington, with the remaining interests owned by two of Pipeline's distribution customers. The authorized seasonal storage capacity of the facility is 15.1 Bcf of working gas. The facility provides peak day deliveries to Pipeline of up to 550 MMcf per day on a firm basis and up to an additional 72 MMcf per day on a best-efforts basis. Certain of Pipeline's major customers own the working gas stored at the facility. Pipeline also owns and operates a liquefied natural gas ("LNG") storage facility located near Plymouth, Washington, which provides standby service for Pipeline's customers during extreme peaks in demand. The facility has a total LNG storage capacity equivalent to 2.4 Bcf of gas, liquefaction capability of 12 MMcf per day and regasification capability of 300 MMcf per day. Certain of Pipeline's major customers own the gas stored at the LNG plant. OPERATING STATISTICS The following table summarizes volumes and average rates for the periods indicated:
Year Ended December 31, --------------------------------- 1995 1994 1993 ------ ----- ----- Gas Volumes (TBtu): Gas sales . . . . . . . . . . . . . . . . . . . . . - - 18 Transportation . . . . . . . . . . . . . . . . . . 826 679 606 ------ ----- ----- Total throughput . . . . . . . . . . . . . . . . 826 679 624 ====== ===== ===== Average Daily Transportation Volumes (TBtu) . . . . . . 2.3 1.9 1.7 Average Daily Firm Reserve Capacity (TBtu) . . . . . . 2.4 2.4 **
** Not applicable -2- 5 OTHER REGULATORY MATTERS Pipeline's transportation of natural gas in interstate commerce is subject to regulation by FERC under the Natural Gas Act and the NGPA. Pipeline holds certificates of public convenience and necessity issued by FERC authorizing it to own and operate all pipelines, facilities and properties considered jurisdictional for which certificates are required under the Natural Gas Act. Pipeline is subject to the Natural Gas Pipeline Safety Act of 1968, as amended by Title I of the Pipeline Safety Act of 1979, which regulates safety requirements in the design, construction, operation and maintenance of interstate gas transmission facilities. On April 1, 1993, Pipeline began collecting new rates, subject to refund, under the provisions of its rate case filed October 1, 1992. On May 31, 1995, Pipeline received a favorable order from the FERC on this rate case. A number of parties have sought rehearing on the rate of return on equity and various other issues. Pipeline has adjusted its reserve accruals in the accompanying financial statements to reflect the favorable order from the FERC. On November 1, 1994, Pipeline began collecting new rates, subject to refund, under the provisions of its rate case filed April 29, 1994. This filing seeks a revenue increase for a projected deficiency caused by increased costs and the impact of a transportation contract terminated subsequent to the rate case filed on October 1, 1992. On November 14, 1995, Pipeline filed an uncontested settlement proposal with the FERC. The settlement resolves substantially all the issues in this rate case. The FERC's final order on this settlement was received on February 16, 1996. No requests for rehearing were filed. Pipeline has not adjusted its reserve accruals in the accompanying financial statements to reflect the favorable settlement. On February 1, 1996, Pipeline began collecting new rates, subject to refund, under the provisions of its rate case filed August 1, 1995. This rate case is set for hearing in the fall of 1996. The filing seeks a revenue increase for increases in rate base related primarily to the mainline expansion facilities placed into service December 1, 1995, increased operating costs primarily associated with an increase in headquarters office rent and increased depreciation expense. OWNERSHIP OF PROPERTY Pipeline's system is owned in fee. However, a substantial portion of Pipeline's system is constructed and maintained pursuant to rights-of-way, easements, permits, licenses or consents on and across properties owned by others. The compressor stations of Pipeline, with appurtenant facilities, are located in whole or in part upon lands owned by Pipeline and upon sites held under leases or permits issued or approved by public authorities. The LNG plant is located on lands owned in fee by Pipeline. Pipeline's debt indentures restrict the sale or disposal of a major portion of its pipeline system. EMPLOYEES At December 31, 1995, Pipeline employed 577 persons, none of whom are represented under collective bargaining agreements. No strike or work stoppage in any of Pipeline's operations has occurred in the past and relations with employees are good. ENVIRONMENTAL MATTERS Pipeline is subject to the National Environmental Policy Act and other federal and state legislation regulating the environmental aspects of its business. Management believes that Pipeline is in substantial compliance with existing environmental requirements. Pipeline believes that, with respect to any capital expenditures required to meet applicable standards and regulations, FERC would grant the requisite rate relief so that, for the most part, such expenditures and a return thereon would be permitted to be recovered. Pipeline believes that compliance with applicable environmental requirements is not likely to have a material effect upon Pipeline's earnings or competitive position. Refer to Note 1 of Notes to Financial Statements for a summary of accounting policy on environmental matters. -3- 6 ITEM 3. LEGAL PROCEEDINGS Other than as described in Note 9 of Notes to Financial Statements and above under Items 1 and 2 - Business and Properties, there are no material pending legal proceedings. Pipeline is subject to ordinary routine litigation incidental to its business. ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS Since Pipeline meets the conditions set forth in General Instruction (J)(1)(a) and (b) of Form 10-K, this information is omitted. PART II ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS Pipeline is wholly owned by Williams. The payment of dividends by Pipeline on its common stock is restricted under various debt agreements. Under the most restrictive provisions, the amount of Pipeline's retained earnings available for dividends on its common stock as of December 31, 1995, was approximately $182.9 million. In 1995 and 1994, Pipeline paid cash dividends on common stock of $20 million and $30 million, respectively. ITEM 6. SELECTED FINANCIAL DATA Since Pipeline meets the conditions set forth in General Instruction (J)(1)(a) and (b) of Form 10-K, this information is omitted. ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS This analysis discusses financial results of Pipeline's operations for the years 1993 through 1995. RESULTS OF OPERATIONS Year Ended December 31, 1995 vs. Year Ended December 31, 1994 Operating revenues increased $16.7 million, or 7%, due primarily to the reversal of a portion of certain accrued liability reserves of approximately $16 million associated with estimated rate refunds, increased transportation rates put into effect in November 1994 and the early in-service of mainline expansion facilities in December 1995, partially offset by the completion in 1994 of billing contract reformation surcharges. The reserve reversals included approximately $8.4 million related to 1993 and $8.7 million related to 1994. Variances due to changes in price and volume no longer have a significant impact on revenues, because under its straight-fixed-variable rate design methodology, the majority of Pipeline's overall cost of service is recovered through fixed demand charges in its transportation rates. Pipeline's transportation service accounted for 93% and 94% of operating revenues for 1995 and 1994, respectively. Of those amounts, Pipeline's firm transportation service accounted for 99% each year. The remaining 1% represented interruptible transportation service. Additionally, 4% and 5% of operating revenues represented gas storage service for 1995 and 1994, respectively. -4- 7 Operating expenses decreased $.8 million due primarily to the absence of amortization of contract reformation costs. This was partially offset by higher operation and maintenance expenses aggregating $2.4 million and increased depreciation of $1.1 million resulting from previous capital additions. Operating income increased $17.5 million, or nearly 17%, primarily due to the reversal of reserve accruals, increased rates put into effect November 1, 1994, the early in-service of mainline expansion facilities in December and the absence of contract reformation amortization expense, partially offset by higher operation and maintenance expenses and increased depreciation expenses. Other expenses increased $1.8 million primarily due to a reserve accrual of $6.4 million related to the initial October 1995 judge's order in a non-jury trial involving claims arising from a transportation agreement of a former customer, partially offset by increases of $2.5 million in investing and other income and the reversal of a $1.5 million reserve accrual. Interest on long-term debt decreased $.5 million, or nearly 2%, due to scheduled debt repayments and certain optional prepayments, partially offset by the issuance of $85 million in new debt during December 1995. Other interest expense decreased $2.2 million, or 34%, primarily due to the absence of deferred carrying costs on contract reformation and the reversal of interest on revenues subject to refund which were previously reserved. The allowance for borrowed funds used during construction increased $2.2 million reflecting construction of the mainline expansion project that was placed into service December 1, 1995. In summary, a review by Pipeline of the rehearing requests in the FERC proceedings described above and other issues impacting reserve estimates resulted in a net reversal to income in the third quarter 1995 of a portion of these accruals, including amounts previously accrued for estimated rate refunds, based on management's assessment of the possible outcome of such issues. Reserve additions, including the significant litigation discussed above, amounted to $8.2 million and reserve reversals amounted to $18.6 million for a net increase to income before income taxes of $10.4 million. If the reserves had not been recorded in prior years, income before income taxes would have been higher by $8.4 million and $10.2 million for 1993 and 1994, respectively. Year Ended December 31, 1994 vs. Year Ended December 31, 1993 Operating revenues decreased $38.1 million, or 14% due primarily to the absence of natural gas sales and completion of contract reformation surcharge billings early in 1994, partially offset by expanded firm transportation service. Natural gas sales were eliminated following the implementation, during the fourth quarter of 1993, of FERC Order No. 636 which converted remaining sales customers to firm transportation service. Operating expenses decreased $44.5 million, or 25%, primarily due to the absence of gas purchase volumes as a result of implementation of FERC Order No. 636, the completion of contract reformation and lower maintenance expenses, partially offset by higher operation expenses, depreciation and amortization, and taxes other than income taxes. Operating income increased $6.5 million, or 7%, primarily due to higher revenues from expanded firm transportation service and lower maintenance expenses partially offset by higher operation expenses, depreciation and amortization, and taxes other than income taxes. Other income decreased $6.9 million, or 86%, primarily due to a decrease in the allowance for equity funds used during construction associated with Pipeline's mainline expansion completed and placed into service April 1, 1993, a decrease in interest income from short-term investing and a reserve related to rate issues. Interest on long-term debt decreased $1.8 million as the result of retiring certain sinking fund debt obligations in 1994. Other interest expense decreased $1.8 million primarily due to the absence of deferred carrying charges on contract reformation costs. -5- 8 FINANCIAL CONDITION AND LIQUIDITY Capital Expenditures and Financing Pipeline's expenditures for property, plant and equipment additions amounted to $130.5 million, $62.6 million and $175.7 million for 1995, 1994 and 1993, respectively. Funds necessary to complete capital projects are expected to come from several sources, including Pipeline's operations and available cash. In addition, Pipeline expects to be able to obtain financing, when necessary, on reasonable terms. To allow flexibility in the timing of issuance of long-term securities, financing may be provided on an interim basis with bank debt and from sources discussed below. Pipeline believes that strong economies in the Pacific Northwest and the growing preference for natural gas in response to environmental concerns support future expansions of its mainline capacity. Pipeline shares in an $800 million Revolving Credit Agreement with Williams and four affiliated companies. Pipeline's maximum borrowing availability, subject to prior borrowing by other affiliated companies, is $400 million, none of which was used by Pipeline at December 31, 1995. Interest rates vary with current market conditions. The agreement contains restrictions which limit, under certain circumstances, the issuance of additional debt, the attachment of liens on any assets and any change of ownership of Pipeline. Any borrowings by Pipeline using this agreement are not guaranteed by Williams and are based on Pipeline's financial need and credit worthiness. Pipeline has also arranged various uncommitted lines-of-credit at market interest rates. These credit facilities are also subject to Pipeline's continued credit worthiness. OTHER Pipeline owns and operates an interstate natural gas pipeline system including facilities for mainline transmission and gas storage. Pipeline's transmission and storage activities are subject to regulation by the FERC under the Natural Gas Act and under the NGPA, and, as such, its rates and charges for the transportation, the extension, enlargement or abandonment of its jurisdictional facilities, and its accounting, among other things, are subject to regulation. Pipeline is also subject to the National Environmental Policy Act and other Federal and state legislation regulating the environmental aspects of its business. Management believes that Pipeline is in substantial compliance with existing environmental requirements. Pipeline believes that, with respect to any capital expenditures required to meet applicable standards and regulations, FERC would grant the requisite rate relief so that, for the most part, such expenditures and a return thereon would be permitted to be recovered. Pipeline believes that compliance with applicable environmental requirements is not likely to have a material effect upon Pipeline's earnings or competitive position. On April 1, 1993, Pipeline began collecting new rates, subject to refund, under the provisions of its rate case filed October 1, 1992. On May 31, 1995, Pipeline received a favorable order from the FERC on this rate case. A number of parties have sought rehearing on the rate of return on equity and various other issues. Pipeline has adjusted its reserve accruals in the accompanying financial statements to reflect the favorable order from the FERC. On November 1, 1994, Pipeline began collecting new rates, subject to refund, under the provisions of its rate case filed April 29, 1994. This filing seeks a revenue increase for a projected deficiency caused by increased costs and the impact of a transportation contract terminated subsequent to the rate case filed on October 1, 1992. On November 14, 1995, Pipeline filed an uncontested settlement proposal with the FERC. The settlement resolves substantially all the issues in this rate case. The FERC's final order on this settlement was received on February 16, 1996. No requests for rehearing were filed. Pipeline has not adjusted its reserve accruals in the accompanying financial statements to reflect the favorable settlement. -6- 9 On February 1, 1996, Pipeline began collecting new rates, subject to refund, under the provisions of its rate case filed August 1, 1995. This rate case is set for hearing in the fall of 1996. The filing seeks a revenue increase for increases in rate base related primarily to the mainline expansion facilities placed into service December 1, 1995, increased operating costs primarily associated with an increase in headquarters office rent and increased depreciation expense. See Note 2 of Notes to Financial Statements for fair value of financial instruments and Note 7 for the effects of a new accounting standard on other postretirement and postemployment benefits. Effect of Inflation Pipeline generally has experienced increased costs in recent years due to the effect of inflation on the cost of labor, materials and supplies, and property, plant and equipment. A portion of the increased labor and materials and supplies cost can directly affect income through increased maintenance and operating costs. The cumulative impact of inflation over a number of years has resulted in increased costs for current replacement of productive facilities. The majority of Pipeline's property, plant and equipment and inventory is subject to ratemaking treatment, and under current FERC practices, recovery is limited to historical costs. While amounts in excess of historical cost are not recoverable under current FERC practices, Pipeline believes it will be allowed to recover and earn a return based on increased actual cost incurred when existing facilities are replaced. Cost based regulation along with competition and other market factors limit Pipeline's ability to price services or products based upon inflation's effect on costs. Contingencies Reference is made to Note 9 of Notes to Financial Statements for information about regulatory and judicial developments which cause operating and financial uncertainties. -7- 10 ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA INDEX TO FINANCIAL STATEMENTS
Page ---- Report of independent auditors . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9 Covered by report of independent auditors: Statement of income for the years ended December 31, 1995, 1994 and 1993 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 Balance sheet at December 31, 1995 and 1994 . . . . . . . . . . . . . . . . . . . 11 Statement of cash flows for the years ended December 31, 1995, 1994 and 1993 . . . . . . . . . . . . . . . . . . . . . . 13 Statement of capitalization for the years ended December 31, 1995, 1994 and 1993 . . . . . . . . . . . . . . . . . . . . . . 14 Notes to financial statements . . . . . . . . . . . . . . . . . . . . . . . . . . 15 Not covered by report of independent auditors: Quarterly financial data (unaudited) . . . . . . . . . . . . . . . . . . . . . . . 25
All other schedules have been omitted since the required information is not present or is not present in amounts sufficient to require submission of the schedule or because the information required is included in the financial statements and notes thereto. -8- 11 REPORT OF INDEPENDENT AUDITORS The Board of Directors Northwest Pipeline Corporation We have audited the accompanying balance sheet of Northwest Pipeline Corporation as of December 31, 1995 and 1994, and the related statements of income, cash flows and capitalization for each of the three years in the period ended December 31, 1995. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits. We conducted our audits in accordance with generally accepted auditing standards. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion. In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Northwest Pipeline Corporation at December 31, 1995 and 1994, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 1995, in conformity with generally accepted accounting principles. ERNST & YOUNG LLP Tulsa, Oklahoma February 9, 1996 -9- 12 NORTHWEST PIPELINE CORPORATION STATEMENT OF INCOME ================================================================================
Year Ended December 31, -------------------------------------------- 1995 1994 1993 --------- --------- --------- (Thousands of Dollars) OPERATING REVENUES (Notes 1, 3, 8 and 9) . . . . . . $255,219 $238,473 $276,543 --------- --------- --------- OPERATING EXPENSES: Gas Purchases . . . . . . . . . . . . . . . . . . - - 41,122 Amortization of contract reformation costs (Note 9) - 4,053 14,114 Operation . . . . . . . . . . . . . . . . . . . . 77,266 75,894 73,987 Maintenance . . . . . . . . . . . . . . . . . . . 11,204 10,136 11,745 Depreciation and amortization (Note 1) . . . . . . 30,657 29,607 26,457 Taxes, other than income taxes . . . . . . . . . . 12,640 12,844 9,648 --------- --------- --------- 131,767 132,534 177,073 --------- --------- --------- Operating income . . . . . . . . . . . . . . . 123,452 105,939 99,470 --------- --------- --------- OTHER INCOME (EXPENSES) - net (Note 1) . . . . . . . (689) 1,117 7,970 --------- --------- --------- INTEREST CHARGES: Interest on long-term debt . . . . . . . . . . . . 29,253 29,798 31,565 Other interest . . . . . . . . . . . . . . . . . . 4,228 6,391 8,226 Allowance for borrowed funds used during construction (Note 1) . . . . . . . . . (3,146) (978) (4,655) --------- --------- --------- 30,335 35,211 35,136 --------- --------- --------- INCOME BEFORE INCOME TAXES . . . . . . . . . . . . . 92,428 71,845 72,304 PROVISION FOR INCOME TAXES (Notes 1 and 4) . . . . . . . . . . . . . . . . . . 33,101 26,947 28,405 --------- --------- --------- NET INCOME . . . . . . . . . . . . . . . . . . . . . $ 59,327 $ 44,898 $ 43,899 ========= ========= ========= CASH DIVIDENDS ON COMMON STOCK . . . . . . . . . . . $ 20,000 $ 30,000 $ 18,000 ========= ========= =========
- --------------------- See accompanying notes. -10- 13 NORTHWEST PIPELINE CORPORATION BALANCE SHEET ================================================================================ ASSETS
December 31, -------------------------------- 1995 1994 ---------- ----------- (Thousands of Dollars) PROPERTY, PLANT AND EQUIPMENT, at cost (Note 5) . . . . . . . . . . . . . $1,402,437 $1,264,539 Less - Accumulated depreciation and amortization . . . . . . . . . . 518,780 497,075 ---------- ----------- 883,657 767,464 Construction work in progress . . . . . . . . . . . . . . . . . . . . 31,040 43,429 ---------- ----------- 914,697 810,893 ---------- ----------- CURRENT ASSETS: Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . 570 1,818 Advances to parent . . . . . . . . . . . . . . . . . . . . . . . . . 41,215 11,909 Accounts receivable - Trade . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36,773 35,578 Affiliated companies . . . . . . . . . . . . . . . . . . . . . . . 1,234 2,055 Gas stored underground (principally at average cost) . . . . . . . . - 8,354 Materials and supplies (principally at average cost) . . . . . . . . 11,065 10,826 Exchange gas due from others . . . . . . . . . . . . . . . . . . . . 9,390 6,821 Costs recoverable through rate adjustments . . . . . . . . . . . . . 5,951 2,148 Income taxes receivable . . . . . . . . . . . . . . . . . . . . . . . 4,480 - Deferred income taxes (Note 4) . . . . . . . . . . . . . . . . . . . 17,729 2,368 Prepayments and other . . . . . . . . . . . . . . . . . . . . . . . . 6,286 2,795 ---------- ----------- 134,693 84,672 ---------- ----------- OTHER ASSETS: Deferred charges (Note 1) . . . . . . . . . . . . . . . . . . . . . . 26,177 23,207 ---------- ----------- $1,075,567 $ 918,772 ========== ===========
- --------------------- See accompanying notes. -11- 14 NORTHWEST PIPELINE CORPORATION BALANCE SHEET ================================================================================ LIABILITIES AND STOCKHOLDER'S EQUITY
December 31, 1995 1994 ---------- -------- (Thousands of Dollars) CAPITALIZATION: Common stockholder's equity - Common stock, par value $1 per share, authorized and outstanding, 1,000 shares . . . . . . . . . . . . . . . . . . $ 1 $ 1 Additional paid-in capital . . . . . . . . . . . . . . . . . . . . . 262,440 262,440 Retained earnings (Note 5) . . . . . . . . . . . . . . . . . . . . . 197,019 164,536 ---------- -------- 459,460 426,977 Long-term debt, less current maturities (Note 6) . . . . . . . . . . . 372,228 297,705 ---------- -------- 831,688 724,682 ---------- -------- CURRENT LIABILITIES: Current maturities of long-term debt (Note 6) . . . . . . . . . . . . . 8,591 8,591 Accounts payable - Trade . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30,033 15,301 Affiliated companies . . . . . . . . . . . . . . . . . . . . . . . . 423 371 Accrued liabilities - Income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . - 1,779 Taxes, other than income taxes . . . . . . . . . . . . . . . . . . . 4,404 6,724 Interest . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12,752 11,890 Employee costs . . . . . . . . . . . . . . . . . . . . . . . . . . . 6,873 6,950 Exchange gas due to others . . . . . . . . . . . . . . . . . . . . . 14,630 11,007 Reserves for estimated rate refunds . . . . . . . . . . . . . . . . 43,883 39,998 Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7,228 2,704 ---------- -------- 128,817 105,315 ---------- -------- DEFERRED INCOME TAXES (Notes 1 and 4) . . . . . . . . . . . . . . . . . . . 105,855 78,183 ---------- -------- OTHER DEFERRED CREDITS (Note 1) . . . . . . . . . . . . . . . . . . . . . 9,207 10,592 ---------- -------- CONTINGENT LIABILITIES AND COMMITMENTS (Note 9) . . . . . . . . . . . . . . ---------- -------- $1,075,567 $918,772 ========== ========
- ---------------------- See accompanying notes. -12- 15 NORTHWEST PIPELINE CORPORATION STATEMENT OF CASH FLOWS ================================================================================
Year Ended December 31, ------------------------------------------------- 1995 1994 1993 --------- -------- --------- (Thousands of Dollars) OPERATING ACTIVITIES: Net Income . . . . . . . . . . . . . . . . . . . . . . . $ 59,327 $ 44,898 $ 43,899 Adjustments to reconcile to cash provided by operations- Depreciation and amortization . . . . . . . . . . . . 30,657 29,607 26,457 Provision (credit) for deferred income taxes . . . . 12,311 223 (2,627) Amortization of deferred charges and credits . . . . 976 1,212 (768) Allowance for equity funds used during construction . (4,273) (1,323) (6,077) Premium on early retirement of long-term debt . . . . - - (170) Increase (decrease) from changes in: Accounts receivable . . . . . . . . . . . . . . . (7,423) (2,305) 14,166 Inventory . . . . . . . . . . . . . . . . . . . . 2,415 10,029 7,054 Other current assets . . . . . . . . . . . . . . . (7,294) 7,188 6,185 Other assets and deferred charges . . . . . . . . (3,952) (362) 10,597 Accounts payable . . . . . . . . . . . . . . . . . 23,567 (7,898) 22,487 Other current liabilities . . . . . . . . . . . . 5,095 14,144 11,234 Other deferred credits . . . . . . . . . . . . . . (185) - (1) Other . . . . . . . . . . . . . . . . . . . . . . . . (85) 8 575 --------- -------- --------- Net cash provided by operating activities . . . . . . . 111,136 95,421 133,011 --------- -------- --------- INVESTING ACTIVITIES: Property, plant and equipment - Capital expenditures . . . . . . . . . . . . . . . . (130,481) (62,583) (175,726) Asset removal cost . . . . . . . . . . . . . . . . . (766) (1,973) (1,774) Changes in accounts payable . . . . . . . . . . . . . (5,160) 1,202 (65,625) Advances to parent . . . . . . . . . . . . . . . . . . . (29,306) (11,909) - --------- -------- --------- Net cash used by investing activities . . . . . . . . . (165,713) (75,263) (243,125) --------- -------- --------- FINANCING ACTIVITIES: Proceeds from issuance of long-term debt . . . . . . . . 85,000 - - Debt issue costs . . . . . . . . . . . . . . . . . . . . (1,156) - - Principal payments on long-term debt . . . . . . . . . . (10,515) (13,015) (29,165) Proceeds from notes payable to banks . . . . . . . . . . 23,450 - - Payments on notes payable to banks . . . . . . . . . . . (23,450) - - Cash dividends paid . . . . . . . . . . . . . . . . . . (20,000) (30,000) (18,000) --------- -------- --------- Net cash provided (used) by financing activities . . . . 53,329 (43,015) (47,165) --------- -------- --------- NET DECREASE IN CASH AND CASH EQUIVALENTS (Note 1) . . . . (1,248) (22,857) (157,279) --------- -------- --------- CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR . . . . . . 1,818 24,675 181,954 --------- -------- --------- CASH AND CASH EQUIVALENTS AT END OF YEAR . . . . . . . . . $ 570 $ 1,818 $ 24,675 ========= ======== =========
- --------------------- See accompanying notes. -13- 16 NORTHWEST PIPELINE CORPORATION STATEMENT OF CAPITALIZATION ================================================================================
Year Ended December 31, --------------------------------------------- 1995 1994 1993 -------- -------- -------- (Thousands of Dollars) COMMON STOCKHOLDER'S EQUITY: Common stock, par value $1 per share, authorized and outstanding, 1,000 shares . . . . . . $ 1 $ 1 $ 1 -------- -------- -------- Additional paid-in capital - Balance at beginning and end of period . . . . . . . 262,440 262,440 262,440 -------- -------- -------- Retained earnings (Note 5) - Balance at beginning of period . . . . . . . . . . . 164,536 151,301 126,797 Net income . . . . . . . . . . . . . . . . . . . . 59,327 44,898 43,899 Cash dividends . . . . . . . . . . . . . . . . . . (20,000) (30,000) (18,000) Noncash dividend (Note 5) . . . . . . . . . . . . (6,844) (1,663) (1,395) -------- -------- -------- Balance at end of period . . . . . . . . . . . . . . 197,019 164,536 151,301 -------- -------- -------- Total common stockholder's equity . . . . . . . . 459,460 426,977 413,742 -------- -------- -------- LONG-TERM DEBT (Note 6): Debentures - 7.125%, payable 2025 . . . . . . . . . . . . . . . . 85,000 - - 9%, payable through 2001 . . . . . . . . . . . . . . 12,500 17,500 25,000 9%, payable 2003 through 2022 . . . . . . . . . . . . 149,351 149,313 149,275 9.25%, payable through 2006 . . . . . . . . . . . . . 15,380 19,228 23,076 10.65%, payable 1999 through 2018 . . . . . . . . . . 100,000 100,000 100,000 Adjustable rate notes, payable through 2002 . . . . . . 9,997 11,664 13,331 -------- -------- -------- Total long-term debt . . . . . . . . . . . . . . . 372,228 297,705 310,682 -------- -------- -------- Total capitalization . . . . . . . . . . . . . . . $831,688 $724,682 $724,424 ======== ======== ========
- --------------------- See accompanying notes. -14- 17 NORTHWEST PIPELINE CORPORATION NOTES TO FINANCIAL STATEMENTS ================================================================================ (1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Northwest Pipeline Corporation ("Pipeline") is wholly owned by The Williams Companies, Inc. ("Williams"). Pipeline owns and operates a pipeline system for the mainline transmission of natural gas. This system extends from the San Juan Basin in northwestern New Mexico and southwestern Colorado through Colorado, Utah, Wyoming, Idaho, Oregon and Washington to a point on the Canadian border near Sumas, Washington. Use of Estimates The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. Actual results could differ from those estimates. Property, Plant and Equipment Property, plant and equipment ("plant"), consisting principally of natural gas transmission facilities, is recorded at original cost. Expenditures which materially increase values or capacities or extend useful lives of plant are capitalized. Routine maintenance, repairs and renewal costs are charged to income as incurred. Gains or losses from the ordinary sale or retirement of plant are charged or credited to accumulated depreciation and amortization ("D&A"). Depreciation is provided by the straight-line method for transmission plant over its useful life. The composite annual D&A rate was 2.19%, 2% and 2.13% for 1995, 1994 and 1993, respectively. The Financial Accounting Standards Board has issued a new Statement of Financial Accounting Standards ("FAS") No. 121, "Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed Of," effective for fiscal years beginning after December 15, 1995. The standard, which will be adopted in the first quarter of 1996, is not expected to have a material effect on Pipeline's financial position or results of operations. Allowance for Borrowed and Equity Funds Used During Construction Allowance for funds used during construction ("AFUDC") represents the estimated cost of borrowed and equity funds applicable to utility plant in process of construction. Recognition is made of this item as a cost of utility plant because it constitutes an actual cost of construction under established regulatory practices. The Federal Energy Regulatory Commission ("FERC") has prescribed a formula to be used in computing separate allowances for borrowed and equity AFUDC. The composite rate used to capitalize AFUDC was approximately 11.8% for 1995, 1994 and 1993. Equity AFUDC of $4.3 million, $1.3 million and $6.1 million for 1995, 1994 and 1993, respectively, is reflected in other income. Income Taxes Pipeline is included in Williams' consolidated federal income tax return. Pipeline's Federal income tax provisions are computed as though separate tax returns are filed. Deferred income taxes are computed using the liability method and are provided on all temporary differences between the financial basis and the tax basis of Pipeline's assets and liabilities. Deferred Charges Pipeline amortizes deferred charges over varying periods consistent with FERC approved accounting treatment for such deferred items. Unamortized debt expense, debt discount and gains or losses on reacquired long-term debt are amortized by the bonds outstanding method over the related debt repayment periods. -15- 18 Deferred Credits The regulatory liability, recorded as a result of new accounting principles for income taxes was adjusted to reflect the increase in the Federal income tax rate from 34 percent to 35 percent in 1993. This liability of $9.1 million and $10.2 million at December 31, 1995 and 1994, respectively, is reflected in other deferred credits. The regulatory liability is being amortized over the lives of the related depreciable assets. Cash and Cash Equivalents Cash and cash equivalents include demand and time deposits, certificates of deposit and other marketable securities with a term to maturity of three months or less when acquired. Exchange Gas Imbalances In the course of providing transportation services to customers, Pipeline may receive different quantities of gas from shippers than the quantities delivered on behalf of those shippers. These transactions result in imbalances which are typically settled through the receipt or delivery of gas in the future although some may be settled in cash. Customer imbalances to be repaid or recovered in-kind are recorded as exchange gas due from others or due to others in the accompanying balance sheets. Settlement of imbalances requires agreement between the pipelines and shippers as to allocations of volumes to specific transportation contracts and timing of delivery of gas based on operational conditions. Revenue Recognition Pipeline recognizes revenues for the transportation of natural gas based upon contractual terms and the related transported volume through month end. Pursuant to FERC regulations, a portion of the revenues being collected may be subject to possible refunds upon final orders in pending cases. Pipeline establishes financial reserves for such contingencies based on the facts and circumstances of the pending case. Environmental Matters Pipeline is subject to Federal, state, and local environmental laws and regulations. Environmental expenditures are expensed or capitalized depending on their future economic benefit and potential for rate recovery. Pipeline believes that, with respect to any expenditures required to meet applicable standards and regulations, FERC would grant the requisite rate relief so that, for the most part, such expenditures would be permitted to be recovered. Pipeline believes that compliance with applicable environmental requirements is not likely to have a material effect upon Pipeline's financial position. Interest Payments Cash payments for interest were $27.8 million, $28.9 million and $26.8 million, net of $3.1 million, $1 million and $4.7 million of interest capitalized in 1995, 1994 and 1993, respectively. Stock-Based Compensation The Financial Accounting Standards Board has issued a new accounting standard, FAS No. 123 "Accounting for Stock-Based Compensation," effective for fiscal years beginning after December 15, 1995. As provided for in the standard, Pipeline will not adopt the recognition provisions and will provide the pro forma net income disclosures required by the standard in its 1996 annual financial statements. (2) DISCLOSURES ABOUT THE FAIR VALUE OF FINANCIAL INSTRUMENTS The following disclosure of the estimated fair value of financial instruments is made in accordance with the requirements of FAS No. 107, Disclosures About Fair Value of Financial Instruments. The estimated fair value amounts have been determined by Pipeline, using available market information and appropriate valuation methodologies. However, considerable judgement is necessarily required in interpreting market data to develop the estimates of fair value. Accordingly, the estimates presented herein are not necessarily indicative of the amounts that Pipeline could realize in a current market exchange. The use and complexity of different market assumptions and/or estimation methodologies may have a material effect on the estimated fair value amounts. -16- 19 NORTHWEST PIPELINE CORPORATION NOTES TO FINANCIAL STATEMENTS - CONTINUED =============================================================================== The following methods and assumptions were used to estimate the fair value of each class of financial instruments for which it is practicable to estimate that value: Cash and cash equivalents - The carrying amount of these items are assumed to be indicative of their fair value. Long-term debt - The fair value of Pipeline's publicly traded long-term debt is valued using year-end traded market prices. Private debt is valued based on the prices of similar securities with similar terms and credit ratings. Pipeline used the expertise of an outside investment banking firm to estimate the fair value of long-term debt. The carrying amount and estimated fair value of Pipeline's long term debt, including current maturities, were $380.8 million and $416.2 million, respectively, at December 31, 1995, and $306.3 million and $314.3 million, respectively, at December 31, 1994. (3) REVENUES ATTRIBUTABLE TO MAJOR CUSTOMERS During some or all of the periods presented, more than 10% of Pipeline's operating revenues were generated from each of the following customers who are large distribution companies.
Year Ended December 31, -------------------------------------------- 1995 1994 1993 -------- ------ ------- (Thousands of Dollars) Washington Natural Gas Co. $47,219 $48,658 $71,661 Northwest Natural Gas Co. 31,232 29,911 31,450 Pacific Interstate Transmission 25,938 23,493 24,119 Cascade Natural Gas Corp. 25,382 25,709 33,594
Pipeline's major customers are located in the Pacific Northwest. As a general policy, collateral is not required for receivables, but customers' financial condition and credit worthiness are regularly evaluated and historical losses have been minimal. A portion of the revenues reflected above (subsequent to April 1, 1993) may be subject to refund due to Pipeline's pending rate cases as discussed in Note 9. -17- 20 NORTHWEST PIPELINE CORPORATION NOTES TO FINANCIAL STATEMENTS - CONTINUED ================================================================================ (4) INCOME TAXES Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. Significant components of the deferred tax liabilities and assets are as follows:
December 31, ---------------------------- (Thousands of Dollars) 1995 1994 --------- --------- Property, plant and equipment $ 106,922 $ 93,871 Regulatory assets 5,465 4,657 Other - net 110 2,263 --------- --------- Deferred tax liabilities 112,497 100,791 --------- --------- Rate refunds (15,914) (14,638) Regulatory liabilities (3,547) (3,982) Accrued liabilities (1,629) (3,533) State deferred taxes (3,281) (2,823) --------- --------- Deferred tax assets (24,371) (24,976) --------- --------- Net deferred tax liabilities $ 88,126 $75,815 ========= ========= Reflected as: Deferred income taxes - asset $ (17,729) $ (2,368) Deferred income taxes - liability 105,855 78,183 --------- --------- $ 88,126 $75,815 ========= =========
The provision for income taxes includes:
Year Ended December 31, ------------------------------------------- 1995 1994 1993 -------- -------- --------- (Thousands of Dollars) Current: Federal . . . . . . . . . . . . . . . . . . $ 18,536 $ 23,811 $ 28,127 State . . . . . . . . . . . . . . . . . . . 2,254 2,913 2,905 -------- -------- --------- 20,790 26,724 31,032 -------- -------- --------- Deferred: Federal . . . . . . . . . . . . . . . . . . 11,001 200 (1,113) State . . . . . . . . . . . . . . . . . . . 1,310 23 (1,514) -------- -------- --------- 12,311 223 (2,627) -------- -------- --------- Total provision . . . . . . . . . . . . . . . . $ 33,101 $ 26,947 $ 28,405 ======== ======== =========
-18- 21 NORTHWEST PIPELINE CORPORATION NOTES TO FINANCIAL STATEMENTS - CONTINUED ================================================================================ A reconciliation of the statutory Federal income tax rate to the provision for income taxes on continuing operations is as follows:
Year Ended December 31, --------------------------------------- 1995 1994 1993 ------- ------- ------- (Thousands of Dollars) Provision at statutory Federal income tax rate of 35% . . . . . . . . . . . . . . . . . . . . . $32,350 $25,146 $25,306 Increase (decrease) in tax provision resulting from - Increase in Federal rates on beginning of year deferred tax balances . . . . . . . . . . . . . - - 1,936 Federal audits . . . . . . . . . . . . . . . . . . (1,593) - - State income taxes, net of Federal tax benefit . . 2,531 1,908 904 Other - net . . . . . . . . . . . . . . . . . . . . (187) (107) 259 ------- ------- ------- Provision for income taxes . . . . . . . . . . . . $33,101 $26,947 $28,405 ======= ======= ======= Effective tax rate . . . . . . . . . . . . . . . . . . . 35.81% 37.51% 39.29% ======= ======= =======
Net cash payments made to Williams for income taxes were $27 million, $22.7 million and $36.2 million in 1995, 1994 and 1993, respectively. (5) RETAINED EARNINGS Noncash Dividends On December 31, 1993, Pipeline transferred certain aircraft and computer assets, net of associated deferred income tax liabilities, to Williams by dividend. These assets, which are not included in the accompanying balance sheet as of December 31, 1993, had a net book value of $1.4 million. On January 31, 1994, Pipeline transferred certain telecommunication and measurement assets, net of associated deferred income tax liabilities, to Williams by dividend. These assets, which are not included in the accompanying balance sheet as of December 31, 1994, had a net book value of $.9 million. On September 30, 1994, Pipeline transferred certain gas transmission assets located in Oklahoma, net of associated deferred income tax liabilities, to Williams by dividend. These assets, which are not included in the accompanying balance sheet as of December 31, 1994, had a net book value of $.7 million. On May 1, 1995, Pipeline transferred an aircraft, net of associated deferred income tax liabilities, to Williams by dividend. This asset, which is not included in the accompanying balance sheet as of December 31, 1995, had a net book value of $5.5 million. On December 31, 1995, Pipeline transferred the Green River Area Office, net of associated deferred income tax liabilities, to Williams by dividend. This asset, which is not included in the accompanying balance sheet as of December 31, 1995, had a net book value of $1.3 million. -19- 22 NORTHWEST PIPELINE CORPORATION NOTES TO FINANCIAL STATEMENTS - CONTINUED ================================================================================ Restrictions Pipeline's debt indentures contain provisions limiting common stock dividends. Under the most restrictive provisions, the amount of Pipeline's retained earnings available for dividends on its common stock as of December 31, 1995, was approximately $182.9 million. (6) LONG-TERM DEBT, LEASES AND BANKING ARRANGEMENTS Debt Covenants The terms of Pipeline's debt indentures preclude the issuance of mortgage bonds. The indentures contain provisions for the acceleration of repayment or the reset of interest rates under certain conditions. Pipeline's debt indentures also contain restrictions which, under certain circumstances, limit the issuance of additional debt, restrict the payment of cash dividends and restrict the disposal of a major portion of its natural gas pipeline system. Long-Term Debt On April 27, 1994, Pipeline called $2.5 million of its outstanding 9% Series B Debentures and $1.9 million of its outstanding 9.25% Series C Debentures, due 2001 and 2006, respectively, under terms of the optional prepayment provisions in the debenture agreement. No early redemption premium was required. The prepayment was in addition to the May 31, 1994 sinking fund payments of $5 million for the 9% Series B and $1.9 million for the 9.25% Series C. On May 31, 1995, Pipeline called $1.9 million of its outstanding 9.25% Series C Debentures, due 2006 under terms of the optional prepayment provisions in the debenture agreement. No early redemption premium was required. The prepayment was in addition to the scheduled May 31, 1995 sinking fund payment of $1.9 million for the 9.25% Series C. On September 14, 1995, Pipeline filed a registration statement for issuance of up to $150 million in public debt securities; and on November 30, 1995, $85 million was marketed and priced, with an interest rate of 7.125%. On December 5, 1995, Pipeline received net proceeds of approximately $83.9 million. The terms of the offering include a 30- year no-call life, maturing December 1, 2025, and no sinking fund requirement. Adjustable Interest Rate Notes The interest rate on these notes will be adjusted periodically, but will never exceed 25% or be less than 9% per annum. The interest rate at December 31, 1995 was 9%. Sinking Fund Requirements and Maturities As of December 31, 1995, cumulative sinking fund requirements and other maturities of long-term debt for each of the next five years are as follows:
(Thousands of Dollars) ----------- 1996 . . . $ 8,591 1997 . . . 8,591 1998 . . . 8,591 1999 . . . 11,091 2000 . . . 8,591
-20- 23 NORTHWEST PIPELINE CORPORATION NOTES TO FINANCIAL STATEMENTS - CONTINUED ================================================================================ Line-of-Credit Arrangements Pipeline shared in a $600 million Revolving Credit Agreement with Williams and two affiliated companies during 1994 and the first two months of 1995. Pipeline's maximum borrowing availability, subject to prior borrowing by other affiliated companies, was $300 million, none of which was used by Pipeline during 1994 or the first two months of 1995. Effective February 23, 1995, this agreement was renegotiated to an $800 million Revolving Credit Agreement with Williams and four affiliated companies, with Pipeline's maximum borrowing availability, subject to prior borrowing by other affiliated companies, increasing to $400 million, none of which was used by Pipeline at December 31, 1995. As with the original agreement, interest rates vary with current market conditions. The agreement contains restrictions that limit, under certain circumstances, the issuance of additional debt, the attachment of liens on any assets and any change of ownership of Pipeline. Any borrowings by Pipeline using this agreement are not guaranteed by Williams and are based on Pipeline's financial need and credit worthiness. Pipeline has also arranged various uncommitted lines-of-credit at market interest rates. These credit facilities are also subject to Pipeline's continued credit worthiness. Leases Pipeline's leasing arrangements include mostly premise and equipment leases that are classified as operating leases. The major operating lease is a leveraged lease which became effective during 1982 for Pipeline's headquarters building. The agreement has an initial term of approximately 27 years, with options for consecutive renewal terms of approximately 9 years and 10 years. The major component of the lease payment is set through the initial and first renewal terms of the lease except for a potential one time adjustment in 1995 to track an allowed interest rate change on a portion of the lessor's debt. Various purchase options exist under the building lease, including options involving adverse regulatory development. Following are the estimated future minimum yearly rental payments required under operating leases which have initial or remaining noncancelable lease terms in excess of one year:
(Thousands of Dollars) ---------- 1996 . . . . . . . $ 8,379 1997 . . . . . . . 8,351 1998 . . . . . . . 8,351 1999 . . . . . . . 8,351 2000 . . . . . . . 8,351 Thereafter . . . . 98,508 ---------- Total . . . . . $ 140,291 ==========
Operating lease rental expense amounted to $4.9 million, $4.6 million and $4.3 million for 1995, 1994 and 1993, respectively. Capital lease payments for the periods presented are not significant. -21- 24 NORTHWEST PIPELINE CORPORATION NOTES TO FINANCIAL STATEMENTS - CONTINUED ================================================================================ (7) EMPLOYEE BENEFIT PLANS Pipeline's employees are covered by Williams' noncontributory defined benefit pension plan. Benefits are based on years of service and average final compensation. Pension costs are funded to satisfy minimum requirements prescribed by the Employee Retirement Income Security Act of 1974. Pipeline accrued pension expense of $.8 million, $.5 million and $1.1 million in 1995, 1994 and 1993, respectively. Such accrued expenses have been or are being funded currently. Substantially all retirees who were hired prior to January 1, 1992, are provided medical benefits. Employees hired after January 1, 1992 will not be provided postretirement medical benefits. As of January 1, 1993, Northwest Pipeline adopted FAS No. 106, "Employers' Accounting for Postretirement Benefits Other than Pensions". During 1995, 1994 and 1993 the expense of providing medical benefits to retirees was approximately $2.3 million, $2.8 million and $2.8 million, respectively. Included in 1995, 1994 and 1993 expenses is the amortization of Pipeline's estimated transition obligation of $19.2 million which is being amortized prospectively over 20 years. Effective January 1, 1994 Pipeline adopted FAS No. 112, "Employers' Accounting for Postemployment Benefits", which requires the accrual of benefits provided to former or inactive employees after regular employment but before retirement. The adoption of the new standard had no effect on Pipeline's net income and had no significant effect on Pipeline's balance sheet. Williams maintains various defined contribution plans covering substantially all employees. Company contributions are based on employees' compensation and, in part, match employee contributions. All Company contributions are invested in Williams stock. Contributions by Pipeline to these plans totaled $1.6 million for 1995 and $1.8 million for each of the years 1994 and 1993. (8) RELATED PARTY TRANSACTIONS Williams' corporate overhead expenses allocated to Pipeline were $4 million, $4.6 million and $4.2 million for 1995, 1994 and 1993, respectively. Such expenses have been allocated to Pipeline by Williams, primarily based on the Massachusetts formula until April 30, 1995 and the Distrigas formula thereafter, which are FERC approved methods utilizing a combination of operating revenues or net revenues, gross payroll and gross plant for the allocation base. In addition, Williams or an affiliate has provided executive, data processing, legal, aviation, internal audit and other administrative services to Pipeline on a direct charge basis which amounted to $3.2 million, $3.4 million and $4.9 million for 1995, 1994 and 1993, respectively. In addition, Pipeline received interest income from advances to parent of $1.1 million and $1.2 million during 1995 and 1994, respectively. There were no advances to parent during 1993. During the periods presented, Pipeline's revenues reflect gas sales, transportation and exchange transactions with subsidiaries of Williams. Combined revenues for these activities totaled $1.8 million, $3.4 million and $4.8 million for 1995, 1994 and 1993, respectively. Pipeline has entered into various other transactions with certain related parties, the amounts of which were not significant. These transactions and the above described transactions are charged on the basis of commercial relationships and prevailing market prices or general industry practices. -22- 25 NORTHWEST PIPELINE CORPORATION NOTES TO FINANCIAL STATEMENTS - CONTINUED ================================================================================ (9) CONTINGENT LIABILITIES AND COMMITMENTS Contract Reformation Pursuant to FERC policy, Pipeline filed and received approval to recover a portion of contract reformation costs through direct bills to former sales customers and through surcharges to transportation as well as sales commodity rates. Recovery of these amounts was completed in 1994. The FERC initially approved a method for Pipeline to direct bill its contract reformation costs, but when challenged on appeal, sought a remand to reassess such method. Pipeline received an order from the FERC that required a different allocation of such costs and rebilled its customers accordingly. This reallocation has had no significant financial impact. Pending Rate Cases On April 1, 1993, Pipeline began collecting new rates, subject to refund, under the provisions of its rate case filed October 1, 1992. On May 31, 1995, Pipeline received a favorable order from the FERC on this rate case. A number of parties have sought rehearing on the rate of return on equity and various other issues. Pipeline has adjusted its reserve accruals in the accompanying financial statements to reflect the favorable order from the FERC. On November 1, 1994, Pipeline began collecting new rates, subject to refund, under the provisions of its rate case filed April 29, 1994. This filing seeks a revenue increase for a projected deficiency caused by increased costs and the impact of a transportation contract terminated subsequent to the rate case filed on October 1, 1992. On November 14, 1995, Pipeline filed an uncontested settlement proposal with the FERC. The settlement resolves substantially all the issues in this rate case. The FERC's final order on this settlement was received on February 16, 1996. No requests for rehearing were filed. Pipeline has not adjusted its reserve accruals in the accompanying financial statements to reflect the favorable settlement. On February 1, 1996, Pipeline began collecting new rates, subject to refund, under the provisions of its rate case filed August 1, 1995. This rate case is set for hearing in the fall of 1996. The filing seeks a revenue increase for increases in rate base related primarily to the mainline expansion facilities placed into service December 1, 1995, increased operating costs primarily associated with an increase in headquarters office rent and increased depreciation expense. Significant Litigation In October 1995, Pipeline received a judge's order following a non-jury trial involving claims arising from a transportation agreement of a former customer. In the decision which was amended in January 1996, it was held that Pipeline was liable to the former customer in the amount of $5.3 million, plus interest. Although Pipeline recorded a charge to "other expenses" in the third quarter 1995, Pipeline is appealing the decision. Other Legal and Regulatory Matters In addition to the foregoing, various other proceedings are pending against Pipeline incidental to its operations. -23- 26 NORTHWEST PIPELINE CORPORATION NOTES TO FINANCIAL STATEMENTS - CONTINUED ================================================================================ Summary of Contingent Liabilities Management believes that the ultimate resolution of the foregoing matters, after consideration of amounts accrued, insurance coverage and other indemnification arrangements, will not have a materially adverse effect upon Pipeline's future financial position, results of operations, and future cash flow requirements. Other Matters Commitments for construction and acquisition of property, plant and equipment are approximately $24.5 million at December 31, 1995. During 1994 Pipeline sold, with limited recourse, certain receivables. Until the expiration of the arrangement in July 1994, net proceeds to Pipeline were limited to $40 million, none of which was utilized at the expiration date. During 1994, Pipeline utilized this facility at varying times up to $18 million. -24- 27 NORTHWEST PIPELINE CORPORATION QUARTERLY FINANCIAL DATA (UNAUDITED) The following is a summary of quarterly financial data for 1995 and 1994:
Quarter of 1995 ---------------------------------------------------------- First Second Third Fourth -------- -------- -------- -------- (Thousands of Dollars) Operating revenues . . . . . . . . . . . . $ 59,073 $ 59,052 $ 75,638 $ 61,456 Operating income . . . . . . . . . . . . . 26,407 27,297 43,323 26,425 Net income . . . . . . . . . . . . . . . . 12,578 15,599 24,344 6,806
Operating results in the third quarter include the reversal of certain reserve accruals, including amounts previously accrued for rate refunds. (See Management's Discussion & Analysis of Financial Condition and Results of Operations and Note 9 of Notes to Financial Statements.)
Quarter of 1994 ---------------------------------------------------------- First Second Third Fourth -------- -------- -------- -------- (Thousands of Dollars) Operating revenues . . . . . . . . . . . . $ 64,686 $ 57,816 $ 57,022 $ 58,949 Operating income . . . . . . . . . . . . . 30,475 26,673 24,110 24,681 Net income . . . . . . . . . . . . . . . . 12,894 12,282 10,217 9,505
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE None. -25- 28 PART III Since Pipeline meets the conditions set forth in General Instruction (J)(1)(a) and (b) of Form 10-K, this information is omitted. PART IV ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K (A)1 AND 2. FINANCIAL STATEMENTS AND SCHEDULES (included in Parts II and IV of this report). The financial statements are listed in the Index to Financial Statements on page 8. No schedules are required to be filed. (A)3. EXHIBITS: (2) Plan of acquisition, reorganization, arrangement, liquidation or succession: *(a) Merger Agreement, dated as of September 20, 1983, between Williams and Energy (Exhibit 18 to Energy schedule 14D-9 (Amendment No. 3) dated September 22, 1983). *(b) The Plan of Merger, dated as of November 7, 1983, between Energy and a subsidiary of Williams (Exhibit 2(b) to Pipeline report on Form 10-K, No. 1-7414, filed March 22, 1984). (3) Articles of incorporation and by-laws: *(a) Restated Certificate of Incorporation (Exhibit 3a to Amendment No. 1 to Registration Statement on Form S-1, No. 2-55-273, filed January 13, 1976). *(b) By-laws, as amended (Exhibit 3c to Registration Statement on Form S-1, No. 2-55273, filed December 30, 1975). (4) Instruments defining the rights of security holders, including indentures: *(a) Note Purchase Agreement, dated as of April 15, 1982, between Pipeline and Teachers Insurance and Annuity Association of America relating to Adjustable Rate Notes, due March 31, 2002 (Exhibit (a)4(e) to Energy Report on Form 10-Q for the quarter ended June 30, 1982, No. 1-7987). *(b) Debenture Purchase Agreement, dated as of June 6, 1986, between Pipeline and certain institutional investors relating to the 8.75% Series A Debentures, due 1996, 9.0% Series B Debentures, due 2001 and 9.25% Series C Debentures, due 2006 (Exhibit 4(n) to Pipeline Report on Form 10-K, No. 1-7414, filed March 31, 1987.) *(c) Indenture, dated as of November 15, 1988, between Pipeline and The Chase Manhattan Bank, relating to Pipeline's 10.65% Debentures (Exhibit 4.1 to Amendment No. 1 to Registration Statement on Form S-3, No. 33-25512, filed November 18, 1988). *(d) Senior Indenture, dated as of August 1, 1992, between Pipeline and Continental Bank, N.A., relating to Pipeline's 9% Debentures, due 2022 (Exhibit 4.1 to Registration Statement on Form S-3, No. 33-49150, filed July 2, 1992). *(e) Senior Indenture, dated as of November 30, 1995 between Pipeline and Chemical Bank, relating to Pipeline's 7.125% Debentures, due 2025 (Exhibit 4.1 to Registration Statement on Form S-3, No. 33- 62639, filed September 14, 1995). -26- 29 (10) Material contracts: (c) *(1) Form of Transfer Agreement, dated July 1, 1991, between Pipeline and Gas Processing (Exhibit 10(c)(8) to Pipeline Report on Form 10-K, No. 1-7414, filed March 26, 1992). *(2) Form of Operating Agreement, dated July 1, 1991, between Pipeline and Williams Field Services Company (Exhibit 10(c)(9) to Pipeline Report on Form 10-K, No. 1-7414, filed March 26, 1992). (23) Consent of Independent Auditors (27) Financial Data Schedule (submitted to the SEC for its information). (B) REPORTS ON FORM 8-K: No reports on Form 8-K have been filed by Pipeline during the last quarter of the period covered by this report. - --------------- *Exhibits so marked have heretofore been filed with the Securities and Exchange Commission as part of the filing indicated and are incorporated herein by reference. -27- 30 SIGNATURES Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized. NORTHWEST PIPELINE CORPORATION (Registrant) By /s/ Brian E. O'Neill ----------------------------- Brian E. O'Neill, President Date: March 27, 1996 Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated.
Signature Title --------- ----- /s/ Keith E. Bailey Chairman of the Board and Director - ---------------------------------- Keith E. Bailey /s/ Brian E. O'Neill President (Principal Executive Officer) and Director - ---------------------------------- Brian E. O'Neill /s/ J. Douglas Whisenant Sr. Vice President and General Manager and Director - ---------------------------------- J. Douglas Whisenant /s/ Timothy J. Hausler Vice President - Finance and Administration, Treasurer and Director - ---------------------------------- (Principal Financial Officer) Timothy J. Hausler /s/ Matt J. Gillis Vice President - Operations and Director - ---------------------------------- Matt J. Gillis /s/ Ronald M. Mucci Vice President - Marketing and Director - ---------------------------------- Ronald M. Mucci /s/ Lewis A. Posekany, Jr. Vice President and Director - ---------------------------------- Lewis A. Posekany, Jr. /s/ Curtis C. Kennedy Controller (Principal Accounting Officer) - ---------------------------------- Curtis C. Kennedy /s/ Robert L. Sluder, Jr. Director - ---------------------------------- Robert L. Sluder, Jr.
Date: March 27, 1996 -28- 31 INDEX TO EXHIBITS
EXHIBIT NUMBER DESCRIPTION - ------- ----------- 23 Consent of Independent Auditors 27 Financial Data Schedule
EX-23 2 CONSENT OF INDEPENDENT AUDITORS 1 EXHIBIT 23 CONSENT OF INDEPENDENT AUDITORS We consent to the incorporation by reference in the Registration Statement (Form S-3 No. 33-62639) of Northwest Pipeline Corporation and in the related Prospectus of our report dated February 9, 1996, with respect to the financial statements of Northwest Pipeline Corporation included in this Annual Report (Form 10-K) for the year ended December 31, 1995. Ernst & Young LLP Tulsa, Oklahoma March 27, 1996 EX-27 3 FINANCIAL DATA SCHEDULE
5 1,000 YEAR DEC-31-1995 DEC-31-1995 570 0 36,773 0 11,065 134,693 1,402,437 518,780 1,075,567 128,817 372,228 1 0 0 459,459 1,075,567 0 255,219 0 131,767 0 0 30,335 92,428 33,101 59,327 0 0 0 59,327 0 0
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