-----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, NXvr/2o7/dYRB5iYFGfoY6g9QQaDZVcvs8woTWH/DT8ItzHeOz5Ok1PsULjyfJWT dnHGNQ88UKyDz/C+21MwdQ== 0000950134-00-002452.txt : 20000328 0000950134-00-002452.hdr.sgml : 20000328 ACCESSION NUMBER: 0000950134-00-002452 CONFORMED SUBMISSION TYPE: 10-K405 PUBLIC DOCUMENT COUNT: 4 CONFORMED PERIOD OF REPORT: 19991231 FILED AS OF DATE: 20000327 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-K405 SEC ACT: SEC FILE NUMBER: 001-07414 FILM NUMBER: 579540 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-K405 1 FORM 10-K FOR FISCAL YEAR END DECEMBER 31, 1999 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, 1999 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 --------------------------- ----------------------- 6.625 % Debentures due 2007 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 24, 2000 - ------------------------------------------ ----------------------------- Common stock, $1 par value 1,000 shares Documents Incorporated by References: None The registrant meets the conditions set forth in General Instruction (I)(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 ...................................................... 5 Item 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS (Omitted)........... 5 PART II Item 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCK- HOLDER MATTERS ........................................................ 6 Item 6. SELECTED FINANCIAL DATA (Omitted)....................................... 6 Item 7. MANAGEMENT'S NARRATIVE ANALYSIS OF THE RESULTS OF OPERATIONS ........... 6 Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA ............................ 10 Item 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE .............................................. 27 PART III Item 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT (Omitted)............ Item 11. EXECUTIVE COMPENSATION (Omitted)........................................ Item 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT (Omitted)................................................... Item 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS (Omitted)................ PART IV Item 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K .......................................................... 28
3 NORTHWEST PIPELINE CORPORATION FORM 10-K PART I ITEMS 1 AND 2. BUSINESS AND PROPERTIES BUSINESS ENVIRONMENT Northwest Pipeline Corporation ("Pipeline") is a wholly-owned subsidiary of Williams Gas Pipeline Company ("WGP"). WGP is a wholly-owned subsidiary of 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, 1999, Pipeline's system, having an aggregate mainline deliverability of approximately 2.9 Bcf* of gas per day, was composed of approximately 3,900 miles of mainline and branch transmission pipelines, and 41 mainline compressor stations with a combined capacity of approximately 318,000 horsepower. Pipeline operates under an open-access transportation certificate wherein gas is transported for third party shippers. In 1999, Pipeline transported natural gas for a total of 156 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 1999 accounted for approximately 15.2% and 13.6%, respectively, of total operating revenues. No other customer accounted for more than 10% of total operating revenues in 1999. 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. - ---------------- * 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. 4 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. 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. 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 is authorized to utilize the Clay Basin Field at a seasonal storage level of 3.04 Bcf of working gas, with a firm delivery capability of 25.3 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 18.3 Bcf of working gas. The facility provides peak day deliveries to Pipeline of up to 850 MMcf per day on a firm basis and up to an additional 150 MMcf per day on a best-efforts basis. 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 2.285 Bcf of working gas, liquefaction capability of 12 MMcf per day and regasification capability of 300 MMcf per day. Certain of Pipeline's major customers own the working gas stored at the LNG plant. EXPANSION PROJECTS During 1999, Pipeline completed the Columbia Gorge Project, which will meet the growing peak-day and annual market growth of British Columbia, Washington and Oregon. The project, which was put into service on November 1, 1999, serves BC Gas Utility Ltd., the major gas distributor in lower British Columbia, with firm transportation of 50,000 MMBtu per day between a Stanfield, Washington receipt point and a delivery point near Sumas, Washington. Total cost to complete this project was approximately $16.2 million. In March 1998, Pipeline filed for certificate authority to realign storage capacity authorized by the FERC to be retained for system balancing by replacing 3.04 Bcf of existing firm Clay Basin storage facility capacity (and 25.3 MMcf per day of associated firm deliverability) with 1.067 Bcf of Jackson Prairie expansion capacity (and 100 MMcf per day of associated firm deliverability). The FERC order authorizing expansion of the Jackson Prairie storage facility was received and accepted during September 1998. The project was put into service on November 1, 1999. The total cost of Northwest's share of the expansion project was approximately $9.8 million. Pipeline has several system expansion and enhancement proposals in various stages of development, although at the present time, there are no pending certificate applications for major expansion projects. -2- 5 OPERATING STATISTICS The following table summarizes volumes and capacity for the periods indicated:
Year Ended December 31, 1999 1998 1997 ------ ------ ------ Total throughput (TBtu) .......................... 708 732 714 Average Daily Transportation Volumes (TBtu) ...... 1.9 2.0 2.0 Average Daily Firm Reserved Capacity (TBtu) ...... 2.5 2.6 2.5
OTHER REGULATORY MATTERS Pipeline's transportation of natural gas in interstate commerce is subject to regulation by the FERC under the Natural Gas Act and the NGPA. Pipeline holds certificates of public convenience and necessity issued by the 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. In July 1998, the FERC issued a Notice of Proposed Rulemaking ("NOPR") concerning the regulation of short-term transportation services and a Notice of Inquiry ("NOI") addressing long-term transportation services. The scope of the inquiry initiated by these two proceedings and the potential policy implications are unprecedented in the history of natural gas regulation. It is likely that, when finalized and implemented, these changes will materially affect the pipeline business. On February 9, 2000, the FERC issued a final rule, Order 637, in response to the comments received on the NOPR and NOI. The FERC adopts in Order 637 certain policies that it finds are necessary to adjust its current regulatory model to the needs of the evolving markets, but determines that any fundamental changes to its regulatory policy, which changes were raised and commented on in the NOPR and NOI, will be considered after further study and evaluation of the evolving marketplace. Most significantly, in Order 637, the FERC (i) revises its pricing policy to waive, for a two-year period, the maximum price ceilings for short-term releases of capacity of less than one year, and (ii) permits pipelines to file proposals to implement seasonal rates for short-term services and term-differentiated rates, subject to certain requirements including the requirement that a pipeline be limited to recovering its annual revenue requirement under those rates. On April 1, 1993, Pipeline began collecting new rates, subject to refund, under its rate case filed October 1, 1992 ("1993 Rate Case"). On May 31, 1995, Pipeline received an order from the Federal Energy Regulatory Commission ("FERC") on this rate case, which, among other issues supported an equity rate of return of 13.2 percent. In a further order issued on July 19, 1996, the FERC required an Administrative Law Judge ("ALJ") to reconsider the long-term growth component of the equity rate of return formula, and upheld its May 31, 1995 decision on all other issues. On October 22, 1996, the ALJ issued an initial decision, which recommended an equity rate of return of 11.62 percent. Pipeline took exception to this decision before the FERC. On June 11, 1997, the FERC issued an order revising its approved equity rate of return to 12.59 percent based on a new policy for industry-wide application that requires the use of forecasts of growth in the gross domestic product as the long-term growth component of the rate of return formula. On July 11, 1997, Pipeline and several parties in the case sought rehearing of the June 11 rate of return on equity decision, seeking to have the FERC reconsider various aspects of its new rate of return on equity policy. On October 16, 1997, the FERC issued an opinion denying rehearing and reaffirming its previous policy pronouncements concerning rate of return on equity, but convened a conference on January 30, 1998 to consider, on an industry-wide basis, issues with respect to pipeline rates of return. Pipeline made refunds to customers in June 1998 totaling $27 million, including interest, reflecting the FERC's resolution of all disputed matters in this case. Pipeline and other parties sought judicial review of the FERC's decision concerning rate of return on equity. One party is seeking judicial review of the inclusion of unpaid accruals in rate base. In July 1998, the FERC issued orders concerning its rate of return on equity policy in rate proceedings of other pipelines -3- 6 adopting a formula that gives less weight to the long-term growth component. In April 1999, the Court of Appeals for the D.C. Circuit remanded the 1993 Rate Case to the FERC for application of its revised rate of return on equity policy. On July 14, 1999, the FERC issued an order requiring Pipeline to: (a) submit a surcharge plan to the FERC, (b) recalculate rates consistent with the new weighting formula favoring short term growth, and (c) address in a remand hearing the appropriate source for GDP growth data. The new weighting formula generally results in a higher authorized rate of return on equity. Pipeline and its customers resolved by settlement those issues relating to long term GDP growth. In February 2000, the FERC approved the long-term growth settlement and issued an order related to return on equity issues requiring Pipeline to incorporate the effects of the settlement and to calculate its allowed rate of return on equity consistent with the recently announced policy changes in other proceedings. As a part of this recalculation of allowed return on equity, the FERC provided that Pipeline must use the median instead of the midpoint of the various results of DCF analysis for a proxy group. This results in a higher return on equity for Pipeline. Pipeline will be making the necessary compliance filings in April 2000 to implement the FERC's decision including the establishment of surcharges in order to recollect moneys that shippers will owe Pipeline for these corrective actions. On February 1, 1996, Pipeline began collecting new rates, subject to refund, under the provisions of its rate case filed August 1, 1995 ("1995 Rate Case"). On October 18, 1996, the Commission issued an order approving a settlement concerning certain liquid revenue credit issues relating to Pipeline's agreement with an affiliate to have liquid hydrocarbon products extracted from Pipeline's transportation stream at Ignacio, Colorado. The litigation of all remaining issues took place in late 1996. Pipeline's rate application sought a revenue increase for increases in rate base related primarily to the Northwest Natural and Expansion II facilities placed into service December 1, 1995 and increased operating costs primarily associated with an increase in headquarters office rent. During the first quarter of 1998, the ALJ issued an Initial Decision. The ALJ found that the facts of this case continue to support Pipeline's capital structure of 55% equity and 45% debt. The ALJ also determined that Pipeline fits within the average risk range for determining pipeline return on equity and allowed a return on equity of 11.2 percent. On June 1, 1999, the FERC issued its order affirming many aspects of the ALJ's initial decision, but finding that the return on equity issue should be resolved by using the FERC's new policy concerning rate of return determinations. This resulted in an allowed return on equity of 12.22 percent. During the second quarter of 1999, Pipeline reduced its rate refund liabilities $9.9 million, of which $7.7 million increased revenues and $2.2 million reduced interest expense, to reflect the FERC's action in this proceeding. On March 1, 1997, Pipeline began collecting new rates, subject to refund, under the provisions of its rate case filed August 30, 1996 ("1996 Rate Case"). The application sought an increase in rates due to a proposed use of a higher depreciation rate which also considers a net negative salvage value for Pipeline's facilities, higher operating costs and a redesign of Pipeline's rates because of impacts relating to the sale of Pipeline's south-end facilities in the third quarter of 1996. On July 22, 1997, Pipeline filed a settlement, which would have resolved all issues in this rate case. On November 25, 1997, the FERC, over the objection of one dissenting party, issued an order approving all aspects of the settlement. The one dissenting party sought and was denied rehearing of the FERC's order. That party has now sought judicial review of certain aspects of the FERC's decisions. Pipeline made refunds to customers in August 1998 totaling $16.7 million, including interest, in this rate case. A settlement in principle has been reached with the one dissenting party on issues pending review in the proceeding and on other business related issues which should lead to the withdrawal of any further judicial challenges in this matter by mid-year 2000. 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, 1999, Pipeline employed 552 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. -4- 7 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, the 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. FORWARD-LOOKING INFORMATION Certain matters discussed in this report, excluding historical information, include forward-looking statements. Although Pipeline believes such forward-looking statements are based on reasonable assumptions, no assurance can be given that every objective will be reached. Such statements are made in reliance on the "safe harbor" protections provided under the Private Securities Litigation Reform Act of 1995. As required by such Act, Pipeline hereby identifies the following important factors that could cause actual results to differ materially from any results projected, forecasted, estimated or budgeted by Pipeline in forward-looking statements: (i) risks and uncertainties related to changes in general economic conditions in the United States, changes in laws and regulations to which Pipeline is subject, including tax, environmental and employment laws and regulations, the cost and effects of legal and administrative claims and proceedings against Pipeline or its subsidiary or which may be brought against Pipeline or its subsidiary, the effect of changes in accounting policies, and conditions of the capital markets Pipeline utilizes to access capital to finance operations; (ii) risks and uncertainties related to the impact of future federal and state regulation of business activities, including allowed rates of return and the resolution of other regulatory matters discussed herein; (iii) risks and uncertainties related to the ability to develop expanded markets as well as the ability to maintain existing markets; and (iv) risks and uncertainties related to the ability to control costs. In addition, future utilization of pipeline capacity will depend on energy prices, competition from other pipelines and alternate fuels, the general level of natural gas demand, decisions by customers not to renew expiring natural gas transportation contracts and weather conditions, among other things. 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 (I)(1)(a) and (b) of Form 10-K, this information is omitted. -5- 8 PART II ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS Pipeline is wholly-owned by WGP, a wholly-owned subsidiary of 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, 1999, was approximately $192 million. In 1999 and 1998, Pipeline paid cash dividends on common stock of $56 million and $36 million, respectively. ITEM 6. SELECTED FINANCIAL DATA Since Pipeline meets the conditions set forth in General Instruction (I)(1)(a) and (b) of Form 10-K, this information is omitted. ITEM 7. MANAGEMENT'S NARRATIVE ANALYSIS OF THE RESULTS OF OPERATIONS This analysis discusses financial results of Pipeline's operations for the years 1997 through 1999. Variances due to changes in price and volume have little impact on revenues, because under Pipeline's rate design methodology, the majority of overall cost of service is recovered through firm capacity reservation charges in its transportation rates. RESULTS OF OPERATIONS Year Ended December 31, 1999 vs. Year Ended December 31, 1998 Operating revenues increased $.4 million due primarily to the 1999 reductions to rate refund liabilities of $8.3 million associated with the 1995 rate case and a $1.4 million gain on the sale of gas from Jackson Prairie, mostly offset by lower short-term firm and interruptible transportation revenues, reductions in 1998 of a demand charge credit reserve of $1.2 million and rate refund liabilities of $4.2 million associated with the 1993 and 1996 rate cases and a gain in 1998 of $.4 million on the sale of system balancing gas. Pipeline's transportation service accounted for 95% of operating revenues for each of the years ended December 31, 1999 and 1998. Additionally, gas storage service represented 2% and 3% of operating revenues for the years ended December 31, 1999 and 1998, respectively. Operating expenses decreased $4.6 million, or 3%, primarily due to a $2.1 million reduction to depreciation associated with the 1995 rate case, a $1.4 million reduction to liability reserves for sales and use tax audits resulting from a favorable ALJ decision, the 1998 increase to property damage reserves of $1.2 million, and the 1998 modification of an employee benefit program associated with the vesting of paid time off of $3 million, partially offset by $1.2 million of software reengineering, training and other costs previously capitalized, a $2.6 million increase in depreciation resulting primarily from additions of short-lived property and accruals for damages of $2.3 million associated with 1999 pipeline ruptures. Operating income increased $5 million, or 4%, due to reasons identified above. Interest on long-term debt decreased $3 million as a result of the early retirement of the remaining $34 million owed on the 10.65% Debentures in November of 1998. Other interest expense decreased $4.3 million due to the reduction to accrued interest liabilities of $2.2 million associated with the 1995 rate case and lower revenues subject to refund as a result of lower rate refund liabilities. Year Ended December 31, 1998 vs. Year Ended December 31, 1997 Operating revenues increased $14.3 million, or 5%, primarily due to the impact of a new rate design effective March 1, 1997 that enables greater short-term firm and interruptible transportation revenues, the favorable adjustments to rate refund accruals associated with the 1993 and 1996 rate cases and the reversal of a demand charge credit reserve in 1998, coupled with the 1997 unfavorable adjustments to rate refund accruals, partially offset by a $3.5 million gain on the sale of system balancing gas in 1997. -6- 9 Pipeline's transportation service accounted for 95% and 94% of operating revenues for the years ended December 31, 1998 and 1997, respectively. Additionally, gas storage service represented 3% of operating revenues for each of the years ended December 31, 1998 and 1997. Operating expenses increased $.4 million due primarily to higher operation and maintenance and general and administrative expenses as a result of increases in property damage reserves and modification of an employee benefit program associated with the vesting of paid time off, mostly offset by lower taxes other than income taxes. Operating income increased $13.9 million, or 11%, due to reasons identified above. Other interest expense decreased $2.6 million due to the use of a revolving credit agreement facility in 1997 and lower revenues subject to refund as a result of rate case settlements in 1998, partially offset by higher amortization of loss on reacquired debt as a result of the early debt retirements in late 1998 and 1997. FINANCIAL CONDITION AND LIQUIDITY Capital Expenditures and Financing Pipeline's expenditures for property, plant and equipment additions amounted to $65.6 million, $60.1 million and $44.4 million for 1999, 1998 and 1997, 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. As of December 31, 1999, Pipeline was a participant in Williams' cash management program. The advances due Pipeline by Williams were represented by demand notes. Effective February 1, 2000, Pipeline began participating in WGP's cash management program. The advances due Pipeline by WGP are represented by demand notes. The interest rate on intercompany demand notes is the London Interbank Offered Rate ("LIBOR") on the first day of the month plus an applicable margin based on the current Standard and Poor's Rating of the Borrower. Pipeline has an outstanding registration statement filed with the Securities and Exchange Commission. At March 1, 2000, approximately $150 million of shelf availability remains under this outstanding registration statement and may be used to issue debt securities. Interest rates and market conditions will affect amounts borrowed, if any, under this arrangement. Pipeline is a participant in a $1 billion Revolving Credit Facility with Williams and certain 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, 1999. Interest rates vary with current market conditions based on the base rate of Citibank N.A., three-month certificates of deposit of major United States money market banks, federal funds rate or LIBOR. The Facility 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 under this Facility are not guaranteed by Williams and are based on Pipeline's financial need and credit worthiness. NWP Enterprises ("Enterprises"), a wholly-owned subsidiary of Pipeline, participates in an agreement for the sale, with limited recourse, of certain receivables of Pipeline. Net proceeds to Enterprises are limited to $15 million of which $10 million was utilized at December 31, 1999, 1998 and 1997. Based on amounts outstanding at December 31, 1999, the maximum contractual credit loss under these arrangements is approximately $1.6 million, but the likelihood of loss is remote. Pipeline has also arranged various uncommitted lines-of-credit at market interest rates. Pipeline's credit facilities are subject to Pipeline's continued credit worthiness. -7- 10 OTHER Refer to Items 1 and 2 Business and Properties for information about regulation of Pipeline's business. See Note 2 of Notes to Financial Statements for fair value of financial instruments. Contingencies Reference is made to Note 9 of Notes to Financial Statements for information about regulatory, judicial and business developments which cause operating and financial uncertainties. 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 rate-making 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. Year 2000 Compliance Pipeline encountered only minor problems associated with the date change from 1999 to 2000, and it experienced no business disruptions. The total estimated cost of its project to prepare for the year 2000 date change was $1.6 million. Pipeline believes that limited and insignificant continued exposure to year 2000 complications remains. Williams and its wholly-owned subsidiaries, which include Pipeline, initiated its enterprise-wide project in 1997 to address the year 2000 compliance issue for both traditional information technology areas and non-traditional areas, including embedded technology that is prevalent throughout the company. This project focused on all technology hardware and software, external interfaces with customers and suppliers, operations process control, automation and instrumentation systems, and facility items. The phases of the project were awareness, inventory and assessment, renovation and replacement, testing and validation and contingency planning. During the inventory and assessment phase, all systems with possible year 2000 implications were inventoried and classified into five categories: 1) highest, business critical; 2) high, compliance necessary within a short period of time following January 1, 2000; 3) medium, compliance necessary within 30 days from January 1, 2000; 4) low, compliance desirable but not required; and 5) unnecessary. Categories 1 through 3 were designated as critical and were the major focus of this project. Pipeline initiated a formal communications process with other companies with which it conducted business in 1998 to determine the extent to which those companies were addressing year 2000 compliance. Pipeline also worked directly with key business partners to reduce the risk of a break in service or supply and with non-compliant companies to mitigate any material adverse effect on Pipeline. Significant focus on the contingency plan phase of the project took place in 1999. Contingency plans were developed for critical business processes, critical business partners, suppliers and system replacements that experience significant delays. Renovation/replacement and testing/validation of critical systems was completed by December 31, 1999. Over the December 31, 1999 to January 4, 2000 weekend, an extensive system monitoring plan was in place with regular reporting of results. Pipeline utilized both internal resources (consisting of a core group of 30 people) and external contractors to complete the year 2000 compliance project. Costs incurred for new software and hardware purchases were capitalized and other costs were expensed as incurred. Prior to 1998 and during the first quarter of 1998, Pipeline was conducting the project awareness and inventory/assessment phases of the project. The second quarter of 1998 was spent on the renovation/replacement and testing/validation phases and completion of the inventory/assessment phase. The third and fourth quarters of 1998 focused on the renovation/replacement and testing/validation phases. During the first quarter 1999, renovation/replacement and testing/validation continued and contingency planning began. During the second quarter of 1999 the primary focus shifted to testing/validation and contingency planning. The third and fourth quarters of 1999 -8- 11 focused mainly on contingency planning and final testing. The first two quarters of 2000 will be spent on monitoring and minor problem resolution. Of the $1.5 million incurred to date, approximately $.5 million has been expensed, and approximately $1 million has been capitalized. The future costs for monitoring and problem resolution will be immaterial. This estimate does not include Pipeline's potential share of year 2000 costs that were incurred by partnerships and joint ventures in which the company participates but is not the operator. The costs of previously planned system replacements are not considered to be year 2000 costs and are, therefore, excluded from the amounts discussed above. The preceding discussion contains forward-looking statements including, without limitation, statements relating to Pipeline's expectations, intentions, and adequate resources, that are made pursuant to the "safe harbor" provisions of the Private Securities Litigation Reform Act of 1995. Readers are cautioned that such forward-looking statements contained in the year 2000 update are based on certain assumptions, which may vary from actual results. Specifically, management's assumptions about the final impact on Pipeline and the total costs to Pipeline of the year 2000 compliance issue are based upon the assumption that there will not be a significant future impact resulting from, for example, problems caused by customers or suppliers that have not yet been fully recognized, or problems with billing, payroll, or financial closing at the quarters or year end. However, there can be no guarantee that these assumptions are correct. MARKET RISK DISCLOSURES Interest Rate Risk Pipeline's interest rate risk exposure primarily results from its debt portfolio, which is influenced by short-term rates, primarily LIBOR based borrowings from commercial banks and long-term U.S. Treasury rates. To mitigate the impact of fluctuations in interest rates, Pipeline targets to maintain a significant portion of its debt portfolio in fixed rate debt. At December 31, 1999, the amount of Pipeline's fixed and variable rate debt was at targeted levels. Pipeline has traditionally maintained an investment grade credit rating as one aspect of managing its interest rate risk. In order to fund its 2000 capital expenditure plan, Pipeline may need to access various sources of liquidity, which may include traditional borrowing. The following table provides information as of December 31, 1999, about Pipeline's long-term debt that is subject to interest rate risk. The table presents principal cash flows and weighted average interest rates by expected maturity dates. December 31, 1999 (Millions of Dollars)
2000 2001 2002 2003 2004 Thereafter Total Fair Value ------- ------- ------- ------- ------- ---------- ------- ---------- Long-term debt, including current portion: Fixed rate -- -- -- $ 7.5 $ 7.5 $ 352.5 $ 367.5 $ 347.2 Interest rate 7.0% 7.0% 7.0% 6.9% 6.9% 6.8% Variable rate $ 1.7 $ 1.7 $ 1.6 -- -- -- $ 5.0 $ 5.2 Interest rate (1)
(1) The interest rate on these notes will be adjusted periodically based on a calculation using the United States Treasury Rate, but will never exceed 25% or be less than 9% per annum. The interest rate at December 31, 1999 was 9%. -9- 12 ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA INDEX TO FINANCIAL STATEMENTS
Page ---- Report of independent auditors............................................... 11 Covered by report of independent auditors: Consolidated statement of income for the years ended December 31, 1999, 1998 and 1997.................................. 12 Consolidated balance sheet at December 31, 1999 and 1998 ............... 13 Consolidated statement of cash flows for the years ended December 31, 1999, 1998 and 1997.................................. 15 Consolidated statement of capitalization for the years ended December 31, 1999, 1998 and 1997.................................. 16 Notes to consolidated financial statements.............................. 17 Not covered by report of independent auditors: Quarterly financial data (unaudited).................................... 27
All 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. -10- 13 REPORT OF INDEPENDENT AUDITORS The Board of Directors Northwest Pipeline Corporation We have audited the accompanying consolidated balance sheet of Northwest Pipeline Corporation as of December 31, 1999 and 1998, and the related consolidated statements of income, cash flows, and capitalization for each of the three years in the period ended December 31, 1999. 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 auditing standards generally accepted in the United States. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion. In our opinion, the financial statements referred to above present fairly, in all material respects, the consolidated financial position of Northwest Pipeline Corporation at December 31, 1999 and 1998, and the consolidated results of its operations and its cash flows for each of the three years in the period ended December 31, 1999, in conformity with accounting principles generally accepted in the United States. /s/ ERNST & YOUNG LLP Tulsa, Oklahoma February 17, 2000 -11- 14 NORTHWEST PIPELINE CORPORATION CONSOLIDATED STATEMENT OF INCOME ================================================================================
Year Ended December 31, ----------------------------------- 1999 1998 1997 --------- --------- --------- (Thousands of Dollars) OPERATING REVENUES ..................... $ 287,793 $ 287,390 $ 273,083 OPERATING EXPENSES: General and administrative .......... 43,441 47,283 46,548 Operation and maintenance ........... 37,784 38,156 37,422 Depreciation ........................ 51,444 50,957 50,883 Taxes, other than income taxes ...... 11,777 12,610 13,771 --------- --------- --------- 144,446 149,006 148,624 --------- --------- --------- Operating income ................. 143,347 138,384 124,459 --------- --------- --------- OTHER INCOME - net ..................... 2,657 3,722 2,908 --------- --------- --------- INTEREST CHARGES: Interest on long-term debt .......... 26,064 29,064 28,908 Other interest ...................... 4,185 8,496 11,051 Allowance for borrowed funds used during construction .............. (833) (520) (394) --------- --------- --------- 29,416 37,040 39,565 --------- --------- --------- INCOME BEFORE INCOME TAXES ............ 116,588 105,066 87,802 PROVISION FOR INCOME TAXES ............. 43,575 41,030 30,626 --------- --------- --------- NET INCOME ............................. $ 73,013 $ 64,036 $ 57,176 ========= ========= ========= CASH DIVIDENDS ON COMMON STOCK ......... $ 56,000 $ 36,000 $ 73,616 ========= ========= =========
- ---------------- See accompanying notes. -12- 15 NORTHWEST PIPELINE CORPORATION CONSOLIDATED BALANCE SHEET ================================================================================ ASSETS
December 31, ----------------------- 1999 1998 ---------- ---------- (Thousands of Dollars) PROPERTY, PLANT AND EQUIPMENT, at cost ............................... $1,616,904 $1,573,593 Less - Accumulated depreciation .................................. 701,127 667,163 ---------- ---------- 915,777 906,430 Construction work in progress .................................... 26,900 21,258 ---------- ---------- 942,677 927,688 ---------- ---------- CURRENT ASSETS: Cash and cash equivalents ........................................ 342 1,164 Advances to parent ............................................... 30,842 26,734 Accounts receivable - Trade ......................................................... 17,748 16,023 Affiliated companies .......................................... 2,027 3,395 Materials and supplies (principally at lower of average cost or market) ....................................................... 10,734 10,575 Exchange gas due from others ..................................... 1,389 19,792 Deferred income taxes ............................................ 19,741 20,261 Prepayments and other ............................................ 1,139 1,763 ---------- ---------- 83,962 99,707 ---------- ---------- OTHER ASSETS: Deferred charges ................................................. 47,594 52,876 ---------- ---------- $1,074,233 $1,080,271 ========== ==========
- ---------------- See accompanying notes. -13- 16 NORTHWEST PIPELINE CORPORATION CONSOLIDATED BALANCE SHEET ================================================================================ LIABILITIES AND STOCKHOLDER'S EQUITY
December 31, ----------------------- 1999 1998 ---------- ---------- (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 ......................... 262,844 262,844 Retained earnings .................................. 206,794 190,507 ---------- ---------- 469,639 453,352 Long-term debt, less current maturities ............... 370,793 372,440 ---------- ---------- 840,432 825,792 ---------- ---------- CURRENT LIABILITIES: Current maturities of long-term debt .................. 1,667 1,667 Accounts payable - Trade .............................................. 10,289 12,576 Affiliated companies ............................... 10,784 7,900 Accrued liabilities - Taxes, other than income taxes ..................... 2,400 4,138 Interest ........................................... 12,030 11,225 Employee costs ..................................... 11,413 10,602 Exchange gas due to others ......................... 2,078 20,481 Reserves for estimated rate refunds ................ 29,059 38,958 Other .............................................. 2,001 818 ---------- ---------- 81,721 108,365 ---------- ---------- DEFERRED INCOME TAXES ..................................... 143,519 135,920 ---------- ---------- OTHER DEFERRED CREDITS .................................... 8,561 10,194 ---------- ---------- CONTINGENT LIABILITIES AND COMMITMENTS ---------- ---------- $1,074,233 $1,080,271 ========== ==========
- ----------------- See accompanying notes. -14- 17 NORTHWEST PIPELINE CORPORATION CONSOLIDATED STATEMENT OF CASH FLOWS ================================================================================
Year Ended December 31, ----------------------------------- 1999 1998 1997 --------- --------- --------- (Thousands of Dollars) OPERATING ACTIVITIES: Net Income ................................................ $ 73,013 $ 64,036 $ 57,176 Adjustments to reconcile to cash provided by operations- Depreciation ........................................... 51,444 50,957 50,883 Provision for deferred income taxes .................... 8,119 14,725 13,541 Amortization of deferred charges and credits ........... 2,112 1,908 (872) Sale of receivables .................................... -- -- 10,000 Allowance for equity funds used during construction .... (1,475) (813) (541) Increase (decrease) from changes in: Accounts receivable and exchange gas due from others ............................................ 18,046 1,190 (9,718) Materials and supplies .............................. (159) 44 (109) Other current assets ................................ 624 6,332 17,218 Other assets and deferred charges ................... 2,075 (124) (858) Accounts payable and exchange gas due to others ..... (18,118) (8,225) 8,201 Other accrued liabilities ........................... (8,838) (46,420) 25,171 Other deferred credits .............................. (518) 3,312 1,233 Other .................................................. 3 (7) (521) --------- --------- --------- Net cash provided by operating activities ................. 126,328 86,915 170,804 --------- --------- --------- INVESTING ACTIVITIES: Property, plant and equipment - Capital expenditures ................................... (65,642) (60,102) (44,427) Proceeds from sales .................................... -- 1,455 968 Asset removal cost ..................................... (45) -- -- Changes in accounts payable ............................ 312 878 (7,096) Payments from (advances to) parent ........................ (4,108) 45,089 (55,147) --------- --------- --------- Net cash used by investing activities ..................... (69,483) (12,680) (105,702) --------- --------- --------- FINANCING ACTIVITIES: Proceeds from issuance of long-term debt .................. -- -- 250,000 Debt issue costs .......................................... -- -- (6,673) Principal payments on long-term debt ...................... (1,667) (35,847) (210,557) Premium on early retirement of long-term debt ............. -- (1,851) (23,869) Proceeds from notes payable to banks ...................... -- -- 207,000 Payments on notes payable to banks ........................ -- -- (207,000) Dividends paid ............................................ (56,000) (36,000) (73,616) --------- --------- --------- Net cash used by financing activities ..................... (57,667) (73,698) (64,715) --------- --------- --------- NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS ......... (822) 537 387 --------- --------- --------- CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR ............... 1,164 627 240 --------- --------- --------- CASH AND CASH EQUIVALENTS AT END OF YEAR ..................... $ 342 $ 1,164 $ 627 ========= ========= =========
- ------------------- See accompanying notes. -15- 18 NORTHWEST PIPELINE CORPORATION CONSOLIDATED STATEMENT OF CAPITALIZATION ================================================================================
Year Ended December 31, ----------------------------------- 1999 1998 1997 --------- --------- --------- (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 .... 262,844 262,844 262,844 --------- --------- --------- Retained earnings - Balance at beginning of period ............ 190,507 162,617 179,485 Net income ............................. 73,013 64,036 57,176 Cash dividends ......................... (56,000) (36,000) (73,616) Noncash dividend ....................... (726) (146) (428) --------- --------- --------- Balance at end of period .................. 206,794 190,507 162,617 --------- --------- --------- Total common stockholder's equity ...... 469,639 453,352 425,462 --------- --------- --------- LONG-TERM DEBT: Debentures - 6.625%, payable 2007 ...................... 250,000 250,000 250,000 7.125%, payable 2025 ...................... 84,706 84,695 84,683 9%, payable 2003 through 2022 ............. 32,758 32,749 32,941 10.65%, paid 1998 ......................... -- -- 34,000 Adjustable rate notes, payable through 2002 .. 3,329 4,996 6,663 --------- --------- --------- Total long-term debt ................... 370,793 372,440 408,287 --------- --------- --------- Total capitalization ................... $ 840,432 $ 825,792 $ 833,749 ========= ========= =========
- -------------------- See accompanying notes. -16- 19 NORTHWEST PIPELINE CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS ================================================================================ (1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Northwest Pipeline Corporation ("Pipeline") is a wholly-owned subsidiary of Williams Gas Pipeline Company ("WGP"). WGP is a wholly owned subsidiary of 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. Basis of Presentation The consolidated financial statements include the operating results of NWP Enterprises ("Enterprises"), a wholly owned subsidiary of Pipeline. Use of Estimates The preparation of financial statements in conformity with accounting principles generally accepted in the United States 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. Depreciation is provided by the straight-line method for transmission plant over its useful life. The composite annual depreciation rate was 2.88%, 3.03% and 2.86% for 1999, 1998 and 1997, respectively, including an allowance for negative salvage. 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 9.9%, 9.7% and 10.6% for 1999, 1998 and 1997, respectively. Equity AFUDC of $1.5 million, $.8 million and $.5 million for 1999, 1998 and 1997, 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 the 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. -17- 20 NORTHWEST PIPELINE CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED =============================================================================== 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, under certain circumstances, 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 Revenues from the transportation of gas are recognized based on contractual terms and the related transported volumes. Pipeline is subject to FERC regulations and, accordingly, certain revenues collected may be subject to possible refunds upon final orders in pending cases. Pipeline records rate refund liabilities considering Pipeline and other third party regulatory proceedings, advice of counsel and estimated total exposure, as discounted and risk weighted, as well as collection and other risks. 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, the 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 $25.3 million, $29 million and $35.5 million, net of $.8 million, $.5 million and $.4 million of interest capitalized in 1999, 1998 and 1997, respectively. Stock-Based Compensation Williams' employee stock-based awards are accounted for under Accounting Principles Board ("APB") Opinion No. 25, "Accounting for Stock Issued to Employees" and related interpretations. Williams' fixed plan common stock options do not result in compensation expense, because the exercise price of the stock options equals the market price of the underlying stock on the date of grant. Recent Accounting Standards The Financial Accounting Standards Board issued Statement of Accounting Standards No. 133, "Accounting for Derivative Instruments and Hedging Activities." This standard, as amended, is effective for Pipeline on January 1, 2001. This standard requires that all derivatives be recognized as assets or liabilities on the balance sheet and that those instruments be measured at fair value. The effect of this standard on Pipeline's results of operations and financial position is being evaluated. Effective January 1, 1999, Pipeline adopted Statement of Position ("SOP") 98-5, "Reporting on the Costs of Start-Up Activities." The SOP requires that all start-up costs be expensed as incurred. There was no financial impact to Pipeline's results of operations or financial position from the adoption of SOP 98-5. -18- 21 NORTHWEST PIPELINE CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED =============================================================================== Reclassifications Certain reclassifications have been made in the 1998 and 1997 financial statements to conform to the 1999 presentation. (2) DISCLOSURES ABOUT THE FAIR VALUE OF FINANCIAL INSTRUMENTS 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, cash equivalents and advances to affiliate - The carrying amounts 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 $372 million and $352 million, respectively, at December 31, 1999, and $374 million and $388 million, respectively, at December 31, 1998. (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.
Year Ended December 31, --------------------------------- 1999 1998 1997 --------- --------- --------- (Thousands of Dollars) Puget Sound Energy, Inc. $ 43,762 $ 42,565 $ 46,540 Northwest Natural Gas Co. 39,064 40,557 46,213 Cascade Natural Gas Corp. 20,282 23,467 28,337 IGI Resources, Inc. 18,541 26,236 32,323 Pacific Interstate Transmission -- 26,700 28,971
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 may be subject to refund due to Pipeline's pending rate cases as discussed in Note 9. -19- 22 NORTHWEST PIPELINE CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED =============================================================================== (4) INCOME TAXES Significant components of the deferred tax liabilities and assets are as follows:
December 31, --------------------- (Thousands of Dollars) 1999 1998 --------- --------- Property, plant and equipment $ 138,257 $ 126,946 Regulatory assets 5,483 5,483 Loss on reacquired debt 9,173 10,334 Other - net 624 685 State deferred taxes 903 -- --------- --------- Deferred tax liabilities 154,440 143,448 --------- --------- Rate refunds 14,509 18,310 Regulatory liabilities 1,812 2,246 Accrued liabilities 6,231 2,927 Contributions in aid of construction 2,599 -- State deferred taxes 5,511 4,306 --------- --------- Deferred tax assets 30,662 27,789 --------- --------- Net deferred tax liabilities $ 123,778 $ 115,659 ========= ========= Reflected as: Deferred income taxes - current asset $ 19,741 $ 20,261 Deferred income taxes - noncurrent liability 143,519 135,920 --------- --------- $ 123,778 $ 115,659 ========= =========
The provision for income taxes includes:
Year Ended December 31, --------------------------------- 1999 1998 1997 --------- --------- --------- (Thousands of Dollars) Current: Federal ......................... $ 31,804 $ 22,480 $ 15,708 State ........................... 3,652 3,825 1,377 --------- --------- --------- 35,456 26,305 17,085 --------- --------- --------- Deferred: Federal ......................... 7,255 13,159 12,144 State ........................... 864 1,566 1,397 --------- --------- --------- 8,119 14,725 13,541 --------- --------- --------- Total provision .................... $ 43,575 $ 41,030 $ 30,626 ========= ========= =========
-20- 23 NORTHWEST PIPELINE CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED =============================================================================== A reconciliation of the statutory Federal income tax rate to the provision for income taxes is as follows:
Year Ended December 31, --------------------------------- 1999 1998 1997 -------- -------- -------- (Thousands of Dollars) Provision at statutory Federal income tax rate of 35% ........................................... $ 40,806 $ 36,773 $ 30,731 Increase (decrease) in tax provision resulting from - State income taxes net of Federal tax benefit ........ 2,999 3,504 1,842 Other - net .......................................... (230) 753 (1,947) -------- -------- -------- Provision for income taxes ........................ $ 43,575 $ 41,030 $ 30,626 ======== ======== ======== Effective tax rate ...................................... 37.38% 39.05% 34.88% ======== ======== ========
Net cash payments made to Williams for income taxes were $35.5 million, $26.7 million and $13.1 million in 1999, 1998 and 1997, respectively. (5) 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 and restrict the disposal of a major portion of its natural gas pipeline system. Pipeline's debt indentures also 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, 1999, was approximately $192 million. Long-Term Debt On November 15, 1998, Pipeline made an optional prepayment of the remaining $34 million of its 10.65% Debentures, due 2018, with a premium of $1.8 million, under the early redemption provisions of the indenture. The early redemption premium and the unamortized debt expense associated with the 10.65% Debentures, totaling $2 million, will be amortized over the life of the retired debt. Excess funds previously advanced to Williams were used to fund the prepayment and premium. Adjustable Interest Rate Notes The interest rate on these notes will be adjusted periodically based on a calculation using the United States Treasury Rate, but will never exceed 25% or be less than 9% per annum. The interest rate at December 31, 1999 was 9%. -21- 24 NORTHWEST PIPELINE CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED =============================================================================== Sinking Fund Requirements and Maturities As of December 31, 1999, cumulative sinking fund requirements and other maturities of long-term debt for each of the next five years are as follows:
(Thousands of Dollars) ------------------ 2000........... $ 1,667 2001........... 1,667 2002........... 1,662 2003........... 7,500 2004........... 7,500 Thereafter..... $ 352,464 ------------------ Total $ 372,460 ==================
Line-of-Credit Arrangements Pipeline is a participant in a $1 billion Revolving Credit Facility with Williams and certain 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, 1999 or 1998. Interest rates vary with current market conditions based on the base rate of Citibank N.A., three-month certificates of deposit of major United States money market banks, federal funds rate or London Interbank Offered Rate ("LIBOR"). The Facility 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 under this Facility 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 that were unused by Pipeline at December 31, 1999 and 1998. Pipeline's credit facilities are 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. Various purchase options exist under the building lease, including options involving adverse regulatory development. -22- 25 NORTHWEST PIPELINE CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED =============================================================================== 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) ----------- 2000 ................ $ 8,757 2001 ................ 8,757 2002 ................ 8,757 2003 ................ 8,757 2004 ................ 8,757 Thereafter........... 63,374 -------- Total............ $107,159 ========
Operating lease rental expense amounted to $8.3 million, $8.3 million and $8 million for 1999, 1998 and 1997, respectively. Capital lease payments for the periods presented are not significant. (6) EMPLOYEE BENEFIT PLANS Pipeline's employees are covered by Williams' non-contributory defined-benefit pension plan and Williams' health care plan that provides postretirement medical benefits to certain retired employees. Contributions for pension and postretirement medical benefits related to Pipeline's participation in these plans were $4.9 million, $5.5 million and $5.2 million in 1999, 1998 and 1997, respectively. Pipeline's employees are also covered by various Williams' defined-contribution plans. Pipeline's costs related to these plans totaled $1.7 million, $1.9 million and $1.5 million in 1999, 1998 and 1997, respectively. (7) STOCK-BASED COMPENSATION Williams has several plans providing for common stock-based awards to its employees and employees of its subsidiaries. The plans permit the granting of various types of awards including, but not limited to, stock options, stock appreciation rights, restricted stock and deferred stock. The purchase price per share for stock options may not be less than the market price of the underlying stock on the date of grant. Stock options generally become exercisable after three and five years, subject to accelerated vesting if certain future stock prices are achieved. Stock options expire 10 years after grant. FAS No. 123, "Accounting for Stock-Based Compensation," requires that companies who continue to apply APB Opinion No. 25 disclose pro forma net income assuming that the fair-value method in FAS 123 had been applied in measuring compensation cost. Pro forma net income for Pipeline was $71.5 million, $63 million and $56.1 million for 1999, 1998 and 1997, respectively. Reported net income was $73 million, $64 million and $57.2 million for 1999, 1998 and 1997, respectively. Pro forma amounts for 1999, 1998 and 1997 include the remaining total compensation expense from the awards made in 1998, 1997 and 1996, respectively, as these awards fully vested in 1999, 1998 and 1997, respectively, as a result of the accelerated vesting provisions. Since compensation expense from stock options is recognized over the future years' vesting period, and additional awards generally are made each year, pro forma amounts may not be representative of future years' amounts. Stock options granted to employees of Pipeline in 1999, 1998 and 1997 were 160,647 shares, 149,850 shares and 288,384 shares, respectively, at a weighted average grant date fair value of $11.90, $8.19 and $5.98, respectively. Stock options outstanding and options exercisable for employees of Pipeline were 1,182,172 shares and 1,150,997 shares, respectively, at December 31, 1999; 1,292,429 shares and 1,143,757 shares, respectively, at December 31, 1998; and 1,185,523 shares and 901,139 shares, respectively, at December 31, 1997. -23- 26 NORTHWEST PIPELINE CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED =============================================================================== The fair value of the stock options was estimated at the date of grant using a Black-Scholes option pricing model with the following weighted average assumptions: expected life of the stock options of approximately five years; volatility of the expected market price of Williams common stock of 28 percent (25 percent in 1998 and 23 percent in 1997); risk-free interest rate of 5.6 percent (5.3 percent in 1998 and 6.1 percent in 1997); and a dividend yield of 1.5 percent (2.0 percent in 1998 and 2.4 percent in 1997). (8) RELATED PARTY TRANSACTIONS As a subsidiary of Williams, Pipeline engages in transactions with Williams and other Williams subsidiaries characteristic of group operations. As of December 31, 1999, Pipeline was a participant in Williams' cash management program. The advances due Pipeline by Williams were represented by demand notes. Effective February 1, 2000, Pipeline began participating in WGP's cash management program. The advances due Pipeline by WGP are represented by demand notes. The interest rate on intercompany demand notes is LIBOR on the first day of the month plus an applicable margin based on the current Standard and Poor's Rating of the Borrower. Pipeline received interest income from advances to Williams of $1.4 million, $3.2 million, and $1.8 million during 1999, 1998 and 1997, respectively. Williams' corporate overhead expenses allocated to Pipeline were $4.3 million, $4.1 million and $3.9 million for 1999, 1998 and 1997, respectively. Such expenses have been allocated to Pipeline by Williams primarily based on the Modified Massachusetts formula, which is a FERC approved method utilizing a combination of 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 $3.8 million, $3.2 million and $3 million for 1999, 1998 and 1997, respectively. During the periods presented, Pipeline's revenues reflect transportation and exchange transactions with subsidiaries of Williams. Combined revenues for these activities totaled $.6 million, $1.4 million and $2.8 million for 1999, 1998 and 1997, 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. (9) CONTINGENT LIABILITIES AND COMMITMENTS Pending Rate Cases On April 1, 1993, Pipeline began collecting new rates, subject to refund, under its rate case filed October 1, 1992 ("1993 Rate Case"). On May 31, 1995, Pipeline received an order from the Federal Energy Regulatory Commission ("FERC") on this rate case, which, among other issues supported an equity rate of return of 13.2 percent. In a further order issued on July 19, 1996, the FERC required an Administrative Law Judge ("ALJ") to reconsider the long-term growth component of the equity rate of return formula, and upheld its May 31, 1995 decision on all other issues. On October 22, 1996, the ALJ issued an initial decision, which recommended an equity rate of return of 11.62 percent. Pipeline took exception to this decision before the FERC. On June 11, 1997, the FERC issued an order revising its approved equity rate of return to 12.59 percent based on a new policy for industry-wide application that requires the use of forecasts of growth in the gross domestic product as the long-term growth component of the rate of return formula. On July 11, 1997, Pipeline and several parties in the case sought rehearing of the June 11 rate of return on equity decision, seeking to have the FERC reconsider various aspects of its new rate of return on equity policy. On October 16, 1997, the FERC issued an opinion denying rehearing and reaffirming its previous policy pronouncements concerning rate of return on equity, but convened a conference on January 30, 1998 to consider, on an industry-wide basis, issues with respect to pipeline rates of return. Pipeline made refunds to customers in June 1998 totaling $27 million, including interest, reflecting the FERC's resolution of all disputed matters in this case. Pipeline and other parties sought judicial review of the FERC's decision concerning rate of return on equity. One party is seeking judicial review of the inclusion of unpaid accruals in rate base. In July 1998, the FERC issued orders concerning its rate of return on equity policy in rate proceedings of other pipelines adopting a formula that gives less weight to the long-term growth component. In April 1999, the Court of -24- 27 NORTHWEST PIPELINE CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED =============================================================================== Appeals for the D.C. Circuit remanded the 1993 Rate Case to the FERC for application of its revised rate of return on equity policy. On July 14, 1999, the FERC issued an order requiring Pipeline to: (a) submit a surcharge plan to the FERC, (b) recalculate rates consistent with the new weighting formula favoring short term growth, and (c) address in a remand hearing the appropriate source for GDP growth data. The new weighting formula generally results in a higher authorized rate of return on equity. Pipeline and its customers resolved by settlement those issues relating to long term GDP growth. In February 2000, the FERC approved the long-term growth settlement and issued an order related to return on equity issues requiring Pipeline to incorporate the effects of the settlement and to calculate its allowed rate of return on equity consistent with the recently announced policy changes in other proceedings. As a part of this recalculation of allowed return on equity, the FERC provided that Pipeline must use the median instead of the midpoint of the various results of DCF analysis for a proxy group. This results in a higher return on equity for Pipeline. Pipeline will be making the necessary compliance filings in April 2000 to implement the FERC's decision including the establishment of surcharges in order to recollect moneys that shippers will owe Pipeline for these corrective actions. On February 1, 1996, Pipeline began collecting new rates, subject to refund, under the provisions of its rate case filed August 1, 1995 ("1995 Rate Case"). On October 18, 1996, the Commission issued an order approving a settlement concerning certain liquid revenue credit issues relating to Pipeline's agreement with an affiliate to have liquid hydrocarbon products extracted from Pipeline's transportation stream at Ignacio, Colorado. The litigation of all remaining issues took place in late 1996. Pipeline's rate application sought a revenue increase for increases in rate base related primarily to the Northwest Natural and Expansion II facilities placed into service December 1, 1995 and increased operating costs primarily associated with an increase in headquarters office rent. During the first quarter of 1998, the ALJ issued an Initial Decision. The ALJ found that the facts of this case continue to support Pipeline's capital structure of 55% equity and 45% debt. The ALJ also determined that Pipeline fits within the average risk range for determining pipeline return on equity and allowed a return on equity of 11.2 percent. On June 1, 1999, the FERC issued its order affirming many aspects of the ALJ's initial decision, but finding that the return on equity issue should be resolved by using the FERC's new policy concerning rate of return determinations. This resulted in an allowed return on equity of 12.22 percent. During the second quarter of 1999, Pipeline reduced its rate refund liabilities $9.9 million, of which $7.7 million increased revenues and $2.2 million reduced interest expense, to reflect the FERC's recent action in this proceeding. On March 1, 1997, Pipeline began collecting new rates, subject to refund, under the provisions of its rate case filed August 30, 1996 ("1996 Rate Case"). The application sought an increase in rates due to a proposed use of a higher depreciation rate which also considers a net negative salvage value for Pipeline's facilities, higher operating costs and a redesign of Pipeline's rates because of impacts relating to the sale of Pipeline's south-end facilities in the third quarter of 1996. On July 22, 1997, Pipeline filed a settlement, which would have resolved all issues in this rate case. On November 25, 1997, the FERC, over the objection of one dissenting party, issued an order approving all aspects of the settlement. The one dissenting party sought and was denied rehearing of the FERC's order. That party has now sought judicial review of certain aspects of the FERC's decisions. Pipeline made refunds to customers in August 1998 totaling $16.7 million, including interest, in this rate case. A settlement in principle has been reached with the one dissenting party on issues pending review in the proceeding and on other business related issues which should lead to the withdrawal of any further judicial challenges in this matter by mid-year 2000. Significant Litigation In 1998, the United States Department of Justice informed Williams that Jack Grynberg, an individual, had filed claims in the United States District Court for the District of Colorado under the False Claims Act against Williams and certain of its wholly-owned subsidiaries including Pipeline. Mr. Grynberg had also filed claims against approximately 300 other energy companies and alleged that the defendants violated the False Claims Act in connection with the measurement and purchase of hydrocarbons. The relief sought was an unspecified amount of royalties allegedly not paid to the Federal government, treble damages, a civil penalty, attorneys' fees and costs. On April 9, 1999, the United States Department of Justice announced that it was declining to intervene in any of the Grynberg qui tam cases; including the action filed against the Williams entities in the United States District Court for the District of Colorado. On October 21, 1999, the Panel on Multi-District Litigation transferred all of the Grynberg qui tam cases, including the ones filed against Williams to the United States District Court for the District of Wyoming for pre-trial purposes. -25- 28 NORTHWEST PIPELINE CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED =============================================================================== Other Legal and Regulatory Matters On February 9, 2000, the FERC issued a final rule, Order 637, in response to the comments received on the Notice of Proposed Rulemaking ("NOPR") and Notice of Inquiry ("NOI"). The FERC adopts in Order 637 certain policies that it finds are necessary to adjust its current regulatory model to the needs of the evolving markets, but determines that any fundamental changes to its regulatory policy, which changes were raised and commented on in the NOPR and NOI, will be considered after further study and evaluation of the evolving marketplace. Most significantly, in Order 637, the FERC (i) revises its pricing policy to waive, for a two-year period, the maximum price ceilings for short-term releases of capacity of less than one year, and (ii) permits pipelines to file proposals to implement seasonal rates for short-term services and term-differentiated rates, subject to certain requirements including the requirement that a pipeline be limited to recovering its annual revenue requirement under those rates. In addition to the foregoing, various other proceedings are pending against Pipeline incidental to its operations. Summary of Contingent Liabilities Management believes that the ultimate resolution of the foregoing matters, after consideration of amounts accrued, insurance coverage or other indemnification arrangements, will not have a materially adverse effect upon Pipeline's future financial position, results of operations, or cash flow requirements. Other Matters Commitments for construction and acquisition of property, plant and equipment are approximately $18.6 million at December 31, 1999. Enterprises participates in an agreement for the sale, with limited recourse, of certain receivables of Pipeline. Net proceeds to Enterprises are limited to $15 million of which $10 million was utilized at December 31, 1999, 1998 and 1997. Based on amounts outstanding at December 31, 1999, the maximum contractual credit loss under these arrangements is approximately $1.6 million, but the likelihood of loss is remote. -26- 29 NORTHWEST PIPELINE CORPORATION QUARTERLY FINANCIAL DATA (UNAUDITED) The following is a summary of quarterly financial data for 1999 and 1998:
Quarter of 1999 ------------------------------------------------------------ First Second Third Fourth -------- -------- -------- -------- (Thousands of Dollars) Operating revenues............................ $ 70,141 $ 77,276 $ 68,642 $ 71,734 Operating income.............................. 29,981 42,470 32,509 38,387 Net income.................................... 13,276 23,917 15,879 19,941
Operating results for the second quarter of 1999 include reductions to rate refund liabilities associated with the 1995 rate case. See Note 9 of Notes to Consolidated Financial Statements.
Quarter of 1998 ------------------------------------------------------------ First Second Third Fourth -------- -------- -------- -------- (Thousands of Dollars) Operating revenues............................ $ 71,218 $ 70,312 $ 73,908 $ 71,952 Operating income.............................. 34,244 35,843 36,128 32,169 Net income.................................... 16,190 17,385 16,687 13,774
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE None. -27- 30 PART III Since Pipeline meets the conditions set forth in General Instruction (I)(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 11. 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 Northwest Energy Company ("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) 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). *(c) 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). *(d) Second Amended and Restated Credit Agreement dated as of July 23, 1997, by and among Pipeline, Williams, Texas Gas Transmission Corporation, Transcontinental Gas Pipe Line Corporation, Williams Holdings of Delaware, Inc., Williams Communications Solutions, LLC, and Citibank N.A., as agent, and the banks named therein (Exhibit 4(c) to Williams Form 10-K for the year ended 1997, Commission File Number 1-4174). *(e) Senior indenture, dated as of December 8, 1997 between Pipeline and The Chase Manhattan Bank, relating to Pipeline's 6.625% Debentures, due 2007 (Exhibit 4.1 to Registration Statement on Form S-3, No. 333-35101, filed September 8, 1997. -28- 31 (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 (24) Power of Attorney with Certified Resolution (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. -29- 32 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/ Jeffrey R. Valentine --------------------------------------- Jeffrey R. Valentine Controller (Principal Accounting Officer) Date: March 24, 2000 Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant in the capacities and on the dates indicated.
Signature Title --------- ----- /s/ Keith E. Bailey* Chairman of the Board and Director - ---------------------------------- Keith E. Bailey /s/ Cuba Wadlington, Jr.* President (Principal Executive Officer) and Director - ---------------------------------- Cuba Wadlington, Jr. /s/ J. Douglas Whisenant* Sr. Vice President and General Manager and Director - ---------------------------------- J. Douglas Whisenant /s/ Nick A. Bacile* Vice President and Treasurer (Principal Financial Officer) - ---------------------------------- Nick A. Bacile /s/ Jeffrey R. Valentine* Controller (Principal Accounting Officer) - ---------------------------------- Jeffrey R. Valentine * By /s/Jeffrey R. Valentine - ---------------------------------- Jeffrey R. Valentine Attorney-in-fact
Date: March 24, 2000 -30- 33 EXHIBIT INDEX Exhibit - ------- 23 Consent of Independent Auditors 24 Power of Attorney with Certified Resolution 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. 333-35101) of Northwest Pipeline Corporation and in the related Prospectus of our report dated February 17, 2000, with respect to the consolidated financial statements of Northwest Pipeline Corporation included in this Annual Report (Form 10-K) for the year ended December 31, 1999. /s/ Ernst & Young LLP Tulsa, Oklahoma March 22, 2000 EX-24 3 POWER OF ATTORNEY WITH CERTIFIED RESOLUTION 1 EXHIBIT 24 NORTHWEST PIPELINE CORPORATION POWER OF ATTORNEY KNOW ALL MEN BY THESE PRESENTS that each of the undersigned individuals, in their capacity as a director or officer, or both, as hereinafter set forth below their signature, of NORTHWEST PIPELINE CORPORATION, a Delaware corporation ("NWP"), does hereby constitute and appoint NICK A. BACILE AND JEFF R. VALENTINE their true and lawful attorneys and each of them (with full power to act without the other) their true and lawful attorneys for them and in their name and in their capacity as a director or officer, or both, of NWP, as hereinafter set forth below their signature, to sign NWP's Annual Report to the Securities and Exchange Commission on Form 10-K for the fiscal year ended December 31, 1999, and any and all amendments thereto or all instruments necessary or incidental in connection therewith; and THAT the undersigned NWP does hereby constitute and appoint NICK A. BACILE AND JEFF R. VALENTINE its true and lawful attorneys and each of them (with full power to act without the other) its true and lawful attorney for it and in its name and on its behalf to sign said Form 10-K and any and all amendments thereto and any and all instruments necessary or incidental in connection therewith. Each of said attorneys shall have full power of substitution and resubstitution, and said attorneys or any of them or any substitute appointed by any of them hereunder shall have full power and authority to do and perform in the name and on behalf of each of the undersigned, in any and all capacities, every act whatsoever requisite or necessary to be done in the premises, as fully to all intents and purposes as each of the undersigned might or could do in person, the undersigned hereby ratifying and approving the acts of said attorneys or any of them or of any such substitute pursuant hereto. IN WITNESS WHEREOF, the undersigned have executed this instrument, all as of the 18th day of February, 2000. /s/ Cuba Wadlington, Jr. /s/ Nick A. Bacile - ----------------------------------------- ------------------------------ Cuba Wadlington, Jr. Nick A. Bacile President, Chief Executive Vice President and Officer, and Director Chief Financial Officer (Principal Executive Officer) (Principal Financial Officer) /s/ Jeff R. Valentine ---------------------- Jeff R. Valentine Controller (Principal Accounting Officer) /s/ Keith E. Bailey /s/ J. Douglas Whisenant - ----------------------------------------- ------------------------------ Keith E. Bailey J. Douglas Whisenant Director Director 2 NORTHWEST PIPELINE CORPORATION By /s/ Nick A. Bacile ---------------------------- Nick A. Bacile Vice President and Chief Financial Officer ATTEST: /s/ Shawna L. Gehres - ------------------------------ Shawna L. Gehres Secretary 3 NORTHWEST PIPELINE CORPORATION I, the undersigned, Shawna L. Gehres, Secretary of NORTHWEST PIPELINE CORPORATION, a Delaware company (hereinafter called the "Company"), do hereby certify that pursuant to Section 141(f) of the General Corporation Law of Delaware, the Board of Directors of this Corporation unanimously consented, as of February 18, 2000, to the following: RESOLVED that the Chairman of the Board, the President or any Vice President of the Company be, and each of them hereby is, authorized and empowered to execute a Power of Attorney for use in connection with the execution and filing, for and on behalf of the Company, under the Securities Exchange Act of 1934, of the Company's Annual Report on Form 10-K for the fiscal year ended December 31, 1999. I further certify that the foregoing resolution has not been modified, revoked or rescinded and is in full force and effect. IN WITNESS WHEREOF, I have hereunto set my hand and affixed the corporate seal of NORTHWEST PIPELINE CORPORATION this 18th day of February, 2000. /s/ Shawna L. Gehres ------------------------------ Shawna L. Gehres Secretary [CORPORATE SEAL] EX-27 4 FINANCIAL DATA SCHEDULE
5 1,000 YEAR DEC-31-1999 DEC-31-1999 342 0 19,775 0 10,734 83,962 1,643,804 701,127 1,074,233 81,721 370,793 0 0 1 469,638 1,074,233 0 287,793 0 144,446 0 0 29,416 116,588 43,575 73,013 0 0 0 73,013 0 0
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