Back to GetFilings.com

Table of Contents

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

x    QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF

THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2003

OR

¨    TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF

THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from                      to                     

Commission File No.: 1-16335

Williams Energy Partners L.P.

(Exact name of registrant as specified in its charter)

One Williams Center, P.O. Box 22186, Tulsa, Oklahoma 74121-2186

(Address of principal executive offices and zip code)

877-934-6571

(Registrant’s telephone number, including area code)

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 whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Exchange Act).     Yes  x No  ¨

As of May 12, 2003, there were outstanding 13,679,694 common units, 7,830,924 Class B units and 5,679,694 subordinated units.

Table of Contents

TABLE OF CONTENTS

PART I

FINANCIAL INFORMATION

1

Table of Contents

PART I

FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

WILLIAMS ENERGY PARTNERS L.P.

CONSOLIDATED STATEMENTS OF INCOME

(In thousands, except per unit amounts)

(Unaudited)

See accompanying notes.

2

Table of Contents

WILLIAMS ENERGY PARTNERS L.P.

CONSOLIDATED BALANCE SHEETS

(In thousands)

See accompanying notes.

3

Table of Contents

WILLIAMS ENERGY PARTNERS L.P.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)

See accompanying notes.

4

Table of Contents

WILLIAMS ENERGY PARTNERS L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1. Basis of Presentation

In the opinion of management, the accompanying financial statements of Williams Energy Partners L.P. (the “Partnership”), which are unaudited except for the Balance Sheet as of December 31, 2002, which is derived from audited financial statements, include all normal and recurring adjustments necessary to present fairly the Partnership’s financial position as of March 31, 2003 and the results of operations for the three month period ended March 31, 2003 and 2002. The results of operations for the three months ended March 31, 2003 are not necessarily indicative of the results to be expected for the full year ending December 31, 2003.

The historical results for Williams Pipe Line Company, LLC (“Williams Pipe Line”) included income and expenses and assets and liabilities that were conveyed to and assumed by an affiliate of Williams Pipe Line prior to the Partnership’s acquisition of it. The assets principally included Williams Pipe Line’s interest in and agreements related to Longhorn Partners Pipeline (“Longhorn”), an inactive refinery site at Augusta, Kansas, a pipeline construction project and the ATLAS 2000 software system. The liabilities principally included the environmental liabilities associated with the inactive refinery site in Augusta, Kansas and current and deferred income taxes and affiliate note payable. The current and deferred income taxes and the affiliate note payable were contributed to the Partnership in the form of a capital contribution by an affiliate of The Williams Companies, Inc. (“Williams”). The income and expenses associated with Longhorn have not been included in the financial results of the Partnership since the acquisition of Williams Pipe Line by the Partnership in April 2002. Also, as agreed between the Partnership and Williams, revenues from Williams Pipe Line’s blending operations, other than an annual blending fee of approximately $3.6 million, have not been included in the financial results of the Partnership since April 2002. In addition, general and administrative expenses related to the Williams Pipe Line system for which the Partnership has been reimbursing its General Partner, WEG GP LLC (the “General Partner”), were limited to $30.7 million on an annual basis, which was increased to $31.0 million on February 1, 2003 when Williams Pipe Line began operating the Rio Grande Pipeline.

Pursuant to the rules and regulations of the Securities and Exchange Commission, the financial statements do not include all of the information and notes normally included with financial statements prepared in accordance with accounting principles generally accepted in the United States. These financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2002.

Certain previously reported amounts have been classified differently to conform to the current period presentation. Net income and total assets were not affected by these reclassifications.

2. Organization

Williams Energy Partners L.P. is a Delaware limited partnership that was formed in August 2000, to own, operate and acquire a diversified portfolio of complementary energy assets. At the time of the Partnership’s initial public offering in February 2001, the Partnership owned petroleum products terminals and an ammonia pipeline system.

On April 11, 2002, the Partnership acquired all of the membership interests of Williams Pipe Line for approximately $1.0 billion (see Note 3 – Acquisitions). Because Williams Pipe Line was an affiliate of the Partnership at the time of the acquisition, the transaction was between entities under common control and, as such, has been accounted for similarly to a pooling of interests. Accordingly, the consolidated financial statements and notes of the Partnership have been restated to reflect the combined historical results of operations, financial position and cash flows of Williams Energy Partners and Williams Pipe Line throughout the periods presented. Williams Pipe Line’s operations are presented as a separate operating segment of the Partnership (see Note 4 – Segment Disclosures).

On April 11, 2002, the Partnership issued 7,830,924 Class B units representing limited partner interests to Williams GP LLC. The securities, valued at $304.4 million and along with $6.2 million of additional

5

Table of Contents

General Partner equity interests were issued as partial payment for the acquisition of Williams Pipe Line (See Note 3 – Acquisitions). According to the provisions in the Williams Pipe Line private placement debt agreement dated November 15, 2002, the Partnership can redeem the Class B units only with proceeds from an equity offering. When the Class B units are redeemed, the price will be based on the 20-day average closing price of the common units prior to the redemption date. If the Class B units are not redeemed by April 11, 2003, then upon the request of the holder of the Class B units and approval of the holders of a majority of the common units voting at a meeting of the unitholders, the Class B units will convert into common units. If the approval of the conversion by the common unitholders is not obtained within 120 days of this request, the holder of the Class B units will be entitled to receive distributions with respect to its Class B units, on a per unit basis, equal to 115% of the amount of distributions paid on a common unit.

In May 2002, the Partnership issued 8 million common units representing limited partner interests in the Partnership at a price of $37.15 per unit for total proceeds of $297.2 million. Associated with this offering, Williams contributed $6.1 million to the Partnership to maintain its 2% General Partner interest. A portion of the total proceeds was used to pay underwriting discounts and commissions of $12.6 million. Legal, professional fees and costs associated with this offering were approximately $1.7 million. The remaining cash proceeds of $289.0 million were used to partially repay the $700.0 million short-term note assumed by the Partnership to help finance the Williams Pipe Line acquisition (see Note 7 – Debt).

3. Acquisitions

On April 11, 2002, the Partnership acquired all of the membership interests of Williams Pipe Line from Williams Energy Services, LLC (“WES”) for approximately $1.0 billion. The Partnership remitted to WES consideration in the amount of $674.4 million and WES retained $15.0 million of Williams Pipe Line’s receivables. The $310.6 million balance of the consideration consisted of $304.4 million of Class B units representing limited partner interests in the Partnership issued to Williams GP LLC and affiliates of WES and Williams’ contribution to the Partnership of $6.2 million to maintain its 2% General Partner interest. The Partnership borrowed $700.0 million from a group of financial institutions, paid WES $674.4 million and used $10.6 million of the borrowed funds to pay debt fees and other transaction costs. The Partnership retained $15.0 million to meet working capital needs.

Because Williams Pipe Line was an affiliate of the Partnership at the time of the acquisition, the transaction was between entities under common control. As such, generally accepted accounting principles required that Williams Pipe Line’s assets and liabilities be recorded on the Partnership’s consolidated financial statements at their historical values, despite their having been acquired at market value. As a result, the General Partner’s capital account was decreased by $474.5 million, which equaled the difference between the historical and market values of Williams Pipe Line. The effect of this treatment on the Partnership’s overall capital balance resulted in a debt-to-total capitalization ratio on March 31, 2003 of 54.5%.

4. Segment Disclosures

Management evaluates performance based upon segment profit or loss from operations, which includes revenues from affiliate and external customers, operating expenses, depreciation and affiliate general and administrative expenses. Affiliate revenues are accounted for as if the sales were to unaffiliated third parties.

The Partnership’s reportable segments are strategic business units that offer different products and services. The segments are managed separately because each segment requires different marketing strategies and business knowledge.

6

Table of Contents

5. Related Party Transactions

The Partnership has entered into agreements with various Williams subsidiaries. The Partnership has several agreements with Williams Energy Marketing & Trading, which provide for: (i) capacity utilization rights to substantially all of the capacity of the Gibson, Louisiana marine terminal facility, (ii) the lease of the Carthage, Missouri propane storage cavern, iii) throughput and deficiency agreements for product movements through a third-party capacity lease and (iv) access and utilization of storage on the Williams Pipe Line system. Williams Pipe Line has entered into pipeline lease agreements and tank storage agreements with Mid-America Pipeline Company and Williams Bio-Energy, LLC (“Williams Bio-Energy”), respectively. Williams Bio-Energy is an affiliate entity and Mid-America Pipeline Company was an affiliate entity until August 1, 2002, when it was sold to Enterprise Products Partners L.P. The Partnership also has a leased storage contract with Williams Bio-Energy at its Galena Park, Texas marine terminal facility and an agreement with Williams Refining & Marketing for the access and utilization of the inland terminals.

The Partnership also has agreements with Williams Energy Marketing & Trading, Williams Refining & Marketing and Williams Bio Energy for the non-exclusive and non-transferable sub-license to use the ATLAS 2000 software system. Payment terms for affiliate entities are generally the same as for third-party companies. Generally, at each month-end, the Partnership is in a net payable position with Williams. The Partnership deducts any amounts owed to it by Williams before remitting the monthly cash amounts owed to Williams. The following are revenues from various Williams’ subsidiaries (in thousands):

7

Table of Contents

Beginning with the closing date of the initial public offering, the General Partner, through provisions included in the Omnibus Agreement, has limited the amount of general and administrative costs charged to the Partnership for the petroleum products terminals and ammonia pipeline system operations. In addition, beginning with the acquisition of Williams Pipe Line, the General Partner has limited the amount of general and administrative expense charged to the Partnership for these operations. The additional general and administrative costs incurred, but not charged to the Partnership, totaled $3.3 million and $2.8 million for the three months ended March 31, 2003 and 2002, respectively.

6. Inventories

Inventories at March 31, 2003 and December 31, 2002 were as follows (in thousands):

7. Debt

As of March 31, 2003, the Partnership had a $175.0 million bank credit facility with $90.0 million borrowed under that facility and $85.0 million of additional borrowing capacity. The credit facility is comprised of a $90.0 million term loan facility and an $85.0 million revolving credit facility, which includes a $73.0 million acquisition sub-facility and a $12.0 million working capital sub-facility. The credit facility’s term extends through February 5, 2004, with all amounts due at that time. As a result, the entire $90.0 million outstanding under this facility is classified as current at March 31, 2003. Borrowings under the credit facility carry an interest rate equal to the Eurodollar rate plus a spread from 1.0% to 1.5%, depending on the leverage ratio of Williams OLP, L.P. (“OLP”), a subsidiary of the Partnership. Interest is also assessed on the unused portion of the credit facility at a rate from 0.2% to 0.4%, depending on the OLP’s leverage ratio. The OLP’s leverage ratio is defined as the ratio of consolidated total debt to consolidated earnings before interest, income taxes, depreciation and amortization for the period of the four fiscal quarters ending on such date. Debt placement fees associated with the initiation of the credit facility were $0.9 million, which are being amortized over the life of the facility. The weighted average interest rate on the credit facility was 2.5% and 3.4% on March 31, 2003 and 2002, respectively.

In April 2002, the Partnership borrowed $700.0 million from a group of financial institutions. This short-term loan was used to help finance the Partnership’s acquisition of Williams Pipe Line. During the second quarter of 2002, the Partnership repaid $289.0 million of the short-term loan with net proceeds from an equity offering. Debt placement fees associated with this borrowing were $7.1 million and were amortized over the six-month life of the short-term loan. In October 2002, the Partnership negotiated an extension to the maturity of this short-term loan from October 8, 2002, to November 27, 2002. The Partnership paid additional fees of approximately $2.1 million associated with this maturity date extension.

8

Table of Contents

During September 2002, in anticipation of a new debt placement to replace the short-term loan used to acquire Williams Pipe Line, the Partnership entered into an interest rate hedge. The effect of this interest rate hedge was to set the coupon rate on a portion of the fixed-rate debt at 7.75% prior to actual execution of the debt agreement. The loss on the hedge, approximately $1.0 million, was recorded in accumulated other comprehensive loss and is being amortized over the five-year life of the fixed-rate debt.

During October 2002, Williams Pipe Line entered into a private placement debt agreement with a group of financial institutions for up to $200.0 million aggregate principal amount of Floating Rate Series A-1 and Series A-2 Senior Secured Notes and up to $340.0 million aggregate principal amount of Fixed Rate Series B-1 and Series B-2 Senior Secured Notes. Both notes are secured with the Partnership’s membership interest in and assets of Williams Pipe Line. The maturity date of both notes is October 7, 2007; however, Williams Pipe Line will be required on each of October 7, 2005 and October 7, 2006 to repay 5% of the then outstanding principal amount of the Senior Secured Notes.

Two borrowings have occurred in relation to these notes. The first borrowing was completed in November 2002 and was for $420.0 million, of which $156.0 million was borrowed under the Series A-1 notes and $264.0 million under the Series B-1 notes. The proceeds from this initial borrowing were used to repay Williams Pipe Line’s $411.0 million short-term loan and pay related debt placement fees. The second borrowing was completed in December 2002 for $60.0 million, of which $22.0 million was borrowed under the Series A-2 notes and $38.0 million under the Series B-2 notes. Of the proceeds from this second borrowing, $58.0 million was used to repay the acquisition sub-facility of OLP and $2.0 million was used for general corporate purposes. The Series A-1 and Series A-2 notes bear interest at a rate equal to the six month Eurodollar Rate plus 4.25%. The rate on the Series A-1 and Series A-2 notes was 5.7% at March 31, 2003. The Series B-1 notes bear interest at a fixed rate of 7.7%, while the Series B-2 notes bear interest at a fixed rate of 7.9%. The weighted-average rate for the Williams Pipe Line Senior Secured Notes at March 31, 2003 was 7.0%. Debt placement fees associated with these notes were $10.5 million, and are being amortized over the life of the notes. Payment of interest and repayment of the principal is guaranteed by the Partnership.

8. Commitments and Contingencies

WES has agreed to indemnify the Partnership against any covered environmental losses up to $15.0 million relating to assets it contributed to the Partnership at the time of the initial public offering that arose prior to February 9, 2001, that become known by February 9, 2004, and that exceed all amounts recovered or recoverable by the Partnership under contractual indemnities from third parties or under any applicable insurance policies. Covered environmental losses are those non-contingent terminal and ammonia system environmental losses, costs, damages and expenses suffered or incurred by the Partnership arising from correction of violations of, or performance of remediation required by, environmental laws in effect at February 9, 2001, due to events and conditions associated with the operation of the assets and occurring before February 9, 2001. Reimbursements from Williams relative to its environmental indemnities are received as remediation is performed.

In connection with the acquisition of Williams Pipe Line, WES agreed to indemnify the Partnership for any breaches of representations or warranties that result in losses and damages up to $110.0 million after the payment of a $2.0 million deductible. With respect to any amount exceeding $110.0 million, WES will be responsible for one-half of that amount up to $140.0 million. In no event will WES’ liability under this indemnity exceed $125.0 million. This indemnification obligation will survive for one year, except that those obligations relating to employees and employee benefits will survive for the applicable statute of limitations and those obligations relating to real property, including title to WES’ assets, will survive for ten years. This indemnity also provides that the Partnership will be indemnified for an unlimited amount of losses and damages related to tax liabilities. In addition, any losses and damages related to environmental liabilities caused by events that occurred prior to the acquisition will be subject only to a $2.0 million deductible, which was met during 2002, for claims made within six years of the Partnership’s acquisition of Williams Pipe Line in April 2002. Covered environmental losses include those losses arising from the correction of violations of, or performance of remediation required by, environmental laws in effect at April 11, 2002. Williams has provided a performance guarantee for the remaining amount of this environmental indemnification.

9

Table of Contents

Estimated liabilities for environmental costs were $22.8 million and $22.3 million at March 31, 2003 and December 31, 2002, respectively. These estimates, provided on an undiscounted basis, were determined based primarily on data provided by a third-party environmental evaluation service and Williams’ internal environmental engineers. These liabilities have been classified as current or non-current based on management’s estimates regarding the timing of actual payments. Management estimates that expenditures associated with these environmental remediation liabilities will be paid over the next five years. Receivables from Williams or its affiliates associated with indemnified environmental costs of $24.2 million and $22.9 million at March 31, 2003 and December 31, 2002, respectively, have been recognized in the Consolidated Balance Sheet. Reimbursements from Williams and its affiliates relative to their environmental indemnities are received as remediation work is performed.

In conjunction with the 1999 acquisition of the Gulf Coast marine terminals from Amerada Hess Corporation (“Hess”), Hess has disclosed to the Partnership all suits, actions, claims, arbitrations, administrative, governmental investigation or other legal proceedings pending or threatened, against or related to the assets acquired by the Partnership, which arise under environmental law. In the event that any pre-acquisition releases of hazardous substances at the Partnership’s Corpus Christi and Galena Park, Texas and Marrero, Louisiana marine terminal facilities were unknown at closing but subsequently identified by the Partnership prior to July 30, 2004, the Partnership will be liable for the first $2.5 million of environmental liabilities, Hess will be liable for the next $12.5 million of losses and the Partnership will assume responsibility for any losses in excess of $15.0 million subject to Williams’ indemnities to the Partnership. Also, Hess agreed to indemnify the Partnership through July 30, 2014, against all known and required environmental remediation costs at the Corpus Christi and Galena Park, Texas marine terminal facilities from any matters related to pre-acquisition actions. Hess has indemnified the Partnership for a variety of pre-acquisition fines and claims that may be imposed or asserted against the Partnership under certain environmental laws.

During 2001, the Partnership recorded an environmental liability of $2.3 million at its New Haven and Hamden, Connecticut facilities, which were acquired in September 2000. This liability was based on third-party environmental engineering estimates completed as part of a Phase II environmental assessment, routinely required by the State of Connecticut to be conducted by the purchaser following the acquisition of a petroleum storage facility. The Partnership completed Phase III environmental assessments at the New Haven facilities, and a Phase II was conducted at the Hamden facility during 2002. During the first quarter of 2003, a Risk Management Plan was prepared for each of the facilities, which set the groundwork for potential remediation strategies. Remediation activities are currently being conducted and will continue at each of the facilities. More extensive remediation systems are being evaluated, and will be installed in the fourth quarter of 2003. The environmental liabilities at the Connecticut facilities are not expected to change materially once the evaluation of the assessment is completed. The seller of these assets agreed to indemnify the Partnership for certain of these environmental liabilities. In addition, the Partnership purchased insurance for up to $25.0 million of environmental liabilities associated with these assets, which carries a deductible of $0.3 million. Any environmental liabilities at this location not covered by the seller’s indemnity and not covered by insurance are covered by the WES environmental indemnifications to the Partnership, subject to the $15.0 million limitation.

During 2001, the Environmental Protection Agency (“EPA”), pursuant to Section 308 of the Clean Water Act, preliminarily determined that Williams may have systemic problems with petroleum discharges from pipeline operations. The inquiry primarily focused on Williams Pipe Line, which was subsequently acquired by the Partnership. The response to the EPA’s information request was submitted during November 2001. The EPA has recently informed us that they have initiated a review of the response we submitted in 2001. Any claims the EPA may assert relative to this inquiry would be covered by the Partnership’s environmental indemnifications from Williams.

Williams Natural Gas Liquids, Inc. (“WNGL”) agreed to indemnify the Partnership for right-of-way defects or failures in the ammonia pipeline easements for 15 years after the initial public offering closing date. WES has also indemnified the Partnership for right-of-way defects or failures associated with the marine terminal facilities at Galena Park and Corpus Christi, Texas and Marrero, Louisiana for 15 years after the initial public offering closing date.

The Partnership is party to various other claims, legal actions and complaints arising in the ordinary course of business. In the opinion of management, the ultimate resolution of all claims, legal actions and complaints after consideration of amounts accrued, insurance coverage or other indemnification

10

Table of Contents

arrangements will not have a material adverse effect upon the Partnership’s future financial position, results of operations or cash flows.

9. Long-Term Incentive Plan

In February 2001, the General Partner adopted the Williams Energy Partners’ Long-Term Incentive Plan for Williams’ employees who perform services for the Partnership and directors of the General Partner. The General Partner subsequently amended and restated the Long-Term Incentive Plan in 2003. The Long-Term Incentive Plan permits the granting of various types of awards, including units, options, phantom units and bonus units but to-date only phantom units have been granted. The Long-Term Incentive Plan allows the grant of awards up to an aggregate of 700,000 common units. The Long-Term Incentive Plan is administered by the Compensation Committee of the General Partner’s Board of Directors. In addition to units, members of the General Partner’s Board of Directors may receive phantom units as compensation for their director fees. Members of the General Partner’s Board of Directors received 82 units and 75 phantom units in the first quarter of 2003 and 665 units in the first quarter of 2002 as partial compensation for their services as board members.

In April 2001, the General Partner issued grants of 92,500 phantom units to certain key employees associated with the Partnership’s initial public offering in February 2001. These awards allowed for early vesting if established performance measures were met prior to February 9, 2004. The Partnership met all of these performance measures and all of the awards vested during 2002. Of the 92,500 units that vested, 26,317 units were deferred by the respective employees to whom these units were to be paid out. The Partnership recognized compensation expense of $1.1 million associated with these awards in the three months ended March 31, 2002.

In April 2001, the General Partner issued grants of 64,200 phantom units associated with the long-term incentive compensation program. The actual number of units that will be awarded under this grant will be determined by the Partnership in early 2004. At that time, the Partnership will assess whether certain performance criteria have been met as of the end of 2003 and determine the number of units that will be awarded, which could range from zero units up to a total of 128,400 units. These units are subject to forfeiture if employment is terminated prior to vesting. These awards do not have an early vesting feature, except for a change in control of the Partnership’s General Partner or for specific participants in the event of their death or disability. In the event of a change in control of the General Partner, these awards will vest and payout immediately at the number of units associated with achieving the highest performance level under the plan. The Partnership is expensing compensation costs associated with these awards assuming the highest level of performance will be achieved; accordingly, the Partnership recognized $0.8 million and $0.4 million of compensation expense in the three months ended March 31, 2003 and 2002, respectively. The fair market value of the phantom units associated with this grant was $4.7 million and $4.2 million on March 31, 2003 and December 31, 2002, respectively, which is calculated based on the fair market value of an equivalent number of partnership units.

During 2002, the Compensation Committee of the Board of Directors of the Partnership’s General Partner approved 22,650 phantom units associated with the 2002 long-term incentive compensation program. The actual number of units that will be awarded under this grant will be determined by the Partnership in early 2005. At that time, the Partnership will assess whether certain performance criteria have been met and determine the number of units that will be awarded, which could range from zero units up to a total of 45,300 units. These units are also subject to forfeiture if employment is terminated prior to the vesting date. These awards do not have an early vesting feature, except in the event of a change in control of the Partnership’s General Partner or for specific participants in the event of their death or disability. In the event of a change in control of the General Partner, these awards will vest and payout immediately at the number of units associated with achieving the highest performance level under the plan. The Partnership is expensing compensation costs associated with these awards assuming 22,650 units will vest; accordingly, the Partnership recorded incentive compensation expense of $0.1 million during the three months ended March 31, 2003. This plan was approved in the third quarter of 2002; therefore, no incentive compensation costs associated with this plan were recorded in the first quarter of 2002. The fair market value of the phantom units associated with this grant was $0.8 million and $0.7 million on March 31, 2003 and December 31, 2002, respectively.

In February 2003, the Compensation Committee of the Board of Directors of the Partnership’s General Partner approved 52,825 phantom units associated with the 2003 long-term incentive compensation

11

Table of Contents

program. The actual number of units that will be awarded under this grant will be determined by the Partnership at the end of 2003 with vesting not to occur until the end of 2005. At that time, the Partnership will assess whether certain performance criteria have been met and determine the number of units that will be awarded, which could range from zero units up to a total of 105,650 units. These units are also subject to forfeiture if employment is terminated prior to the vesting date. These awards do not have an early vesting feature, except for: (i) specific participants in the event of their death or disability, or (ii) in the event that there is a change in control of the Partnership’s General Partner and the participant is terminated for reasons other than cause within the two years following the change in control of the General Partner, in which case the awards will vest and payout immediately at the highest performance level under the plan. The Partnership is expensing compensation costs associated with these awards assuming 52,825 units will vest; accordingly, the Partnership recorded incentive compensation expense of $0.1 million during the three months ended March 31, 2003. The value of these units on March 31, 2003 was $1.9 million.

The Partnership accounts for stock-based compensation under Accounting Principles Board (“APB”) Opinion No. 25, “Accounting for Stock Issued to Employees,” and related interpretations. The Partnership has adopted the disclosure-only provisions of Statement of Financial Accounting Standards (“SFAS”) No. 123, “Accounting for Stock-Based Compensation,” and SFAS No. 148, “Accounting for Stock-Based Compensation – Transition and Disclosure,” which was released in December 2002 as an amendment of SFAS No. 123. The following table illustrates the effect on net income and earnings per share if the fair value-based method had been applied to all awards.

These pro forma results may not be indicative of future results for the full fiscal year of the Partnership.

10. Distributions

Distributions paid by the Partnership during 2002 and 2003 are as follows:

(a) The General Partner declared this cash distribution on April 22, 2003 to be paid on May 15, 2003, to unitholders of record at the close of business on May 5, 2003.

12

Table of Contents

11. Net Income Per Unit

The following table provides details of the basic and diluted net income per unit computations (in thousands, except per unit amounts):

Units reported as dilutive securities are related to phantom unit grants associated with the one-time initial public offering award and the 2001 unit awards (see Note 9 – Long-Term Incentive Plan).

12. Subsequent Events

On April 21, 2003, the Partnership announced that Williams agreed to sell its 54.6% interest in the Partnership to a new entity formed jointly by private equity firms Madison Dearborn Partners, LLC and Carlyle/Riverstone Global Energy and Power Fund II, L.P. for $512.0 million. The transaction is expected to close in the second quarter of 2003. The acquisition includes Williams’ 100% ownership interest in the Partnership’s General Partner and Williams’ 1.1 million common units, 5.7 million subordinated units and 7.8 million Class B units representing limited partner interests in the Partnership.

The sale of Williams’ interest in the Partnership’s General Partner will result in a change in control of the General Partner, which will result in all of the 2001 and 2002 long-term incentive awards vesting, at the highest performance level under the plan, on the date of the sale. Assuming the transaction closes before June 30, 2003, the Partnership estimates its equity-based incentive compensation expense will be approximately $2.5 million during the second quarter of 2003. Also, the deferred units discussed in Note 9 will be paid out at that time to the employees.

As part of this transaction, the buyer will agree to a New Omnibus Agreement, which will maintain the G&A cap but allow for a yearly escalation factor of 7% beginning in 2004. In addition, the buyer will assume a limited environmental indemnity from Williams to the Partnership for $21.9 million. Environmental costs in excess of $21.9 million are indemnified by Williams subject to the same limitations described in Note 8 – Commitments and Contingencies.

13

Table of Contents

INTRODUCTION

Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the consolidated financial statements and notes thereto. Williams Energy Partners L.P. is a publicly traded limited partnership created to own, operate and acquire a diversified portfolio of energy assets. We are principally engaged in the transportation, storage and distribution of refined petroleum products and ammonia. Our current asset portfolio consists of:

On April 11, 2002, we acquired for approximately $1.0 billion all of the membership interests of Williams Pipe Line Company, LLC (“Williams Pipe Line”) from a wholly owned subsidiary of The Williams Companies, Inc. (“Williams”). Williams Pipe Line owns and operates the Williams Pipe Line system. Because Williams Pipe Line was an affiliate of ours at the time of the acquisition, the transaction was between entities under common control and, as such, was accounted for similar to a pooling of interest. Accordingly, our consolidated financial statements and notes have been restated to reflect the historical results of operations, financial position and cash flows of Williams Pipe Line and us on a combined basis throughout the periods presented.

The historical results for the Williams Pipe Line system include revenue and expenses and assets and liabilities that were conveyed to and assumed by an affiliate of Williams Pipe Line prior to our acquisition of it. These assets primarily include Williams Pipe Line’s interest in and agreements related to Longhorn Partners Pipeline, L.P. (“Longhorn”), an inactive refinery at Augusta, Kansas, a pipeline construction project, the ATLAS 2000 software system and the pension asset and obligations associated with the non-contributory defined-benefit pension plan that covered employees assigned to Williams Pipe Line’s operations. The results from these assets have not been included in our financial results since our acquisition of Williams Pipe Line in April 2002. In addition, revenues from Williams Pipe Line’s blending operations, other than an annual blending fee, have not been included in our financial results since April 2002. We report the Williams Pipe Line system’s operations as a separate operating segment.

RECENT DEVELOPMENTS

On April 21, 2003, Williams announced that it had agreed to sell its 54.6% interest in us to a new entity formed jointly by private equity firms Madison Dearborn Partners, LLC and Carlyle/Riverstone Global Energy and Power Fund II, L.P. The equity firms will acquire 1.1 million of our common units, 5.7 million subordinated units, 7.8 million Class B units and 100% of the ownership interest in our General Partner. The transaction is expected to close in the second quarter of 2003.

Following the close of this transaction, the following items will result due to our separation from Williams:

14

Table of Contents

Because the transaction involves a change in ownership of more than 50% of the partnership in one year:

Beginning in 2003, we will begin to conduct annual unitholder meetings, at which time a class of our General Partner’s directors will be elected. Our partnership agreement indicates this annual meeting will be held on the second Wednesday in May unless changed by our General Partner. Based on the timing of Williams’ sale of its interest in us, our General Partner has changed the meeting date to be held after the transaction closes. Once the meeting date has been established, we will notify our unitholders of the meeting specifics.

On April 22, 2003, our General Partner declared a quarterly cash distribution of $0.75 per unit for the period of January 1 through March 31, 2003. The first-quarter distribution represents a 3% increase over the fourth-quarter 2002 distribution and a 43% increase since our initial public offering in February 2001. The distribution will be paid on May 15, 2003 to unitholders of record at the close of business on May 5, 2003.

15

Table of Contents

RESULTS OF OPERATIONS

Three Months Ended March 31, 2003 Compared to Three Months Ended March 31, 2002

Our revenues, excluding product sales and management fee revenues, for the three months ended March 31, 2003 were $87.7 million compared to $80.3 million for the three months ended March 31, 2002, an increase of $7.4 million, or 9%. This increase was a result of:

16

Table of Contents

volumes was overcome principally by higher average revenues per barrel for our terminals services; and

Operating expenses including environmental expenses net of environmental indemnifications from Williams and excluding product purchases were $34.4 million for the three months ended March 31, 2003, compared to $33.0 million for the three months ended March 31, 2002, an increase of $1.4 million, or 4%. This increase was a result of:

Revenues from Williams Pipe Line product sales were $29.1 million for the three months ended March 31, 2003, while product purchases were $27.4 million, resulting in a net margin of $1.7 million in 2003. The 2003 net margin represents a decrease of $1.5 million compared to a net margin in 2002 of $3.2 million resulting from product sales for the three months ended March 31, 2002 of $21.6 million and product purchases of $18.4 million. The margin decline in 2003 reflects our agreement with an affiliate of Williams to provide blending services for them for an annual fee. As a result of this agreement, we no longer generate a commodity margin from butane blending related activities. Revenues from petroleum products terminals product sales were $2.9 million for the three months ended March 31, 2003 and $0.5 million for the same period in 2002, resulting in an increase of $2.4 million primarily due to the sale of product overages during a high pricing environment.

Affiliate management fee revenues for the three months ended March 31, 2003 were zero compared to $0.2 million for the three months ended March 31, 2002. Historically, Williams Pipe Line received a fee to manage Longhorn. Prior to our acquisition of Williams Pipe Line, the agreement with Longhorn was transferred to a wholly owned subsidiary of Williams.

Depreciation and amortization expense for the three months ended March 31, 2003 was $9.4 million, representing a $0.4 million increase from 2002 at $9.0 million. Additional depreciation associated with capital improvements exceeded the elimination of depreciation associated with assets we did not acquire as part of the Williams Pipe Line acquisition.

G&A expenses for the three months ended March 31, 2003 were $10.4 million compared to $13.4 million for the three months ended March 31, 2002, a decrease of $3.0 million, or 22%. G&A expenses are paid to Williams as defined by the Omnibus Agreement and are limited to $9.5 million per quarter during 2003 plus equity-based incentive compensation expenses. Incentive compensation costs associated with our long-term equity-based incentive plan are specifically excluded from the expense limitation and were $1.0 million during first-quarter 2003. During first-quarter 2002, we paid Williams $1.7 million for G&A services plus equity-based incentive compensation expenses. Incentive compensation costs associated with our long-term equity-based incentive plan were $1.5 million during first-quarter 2002, including $1.0 million associated with the early vesting of phantom units issued to key employees at the time of our initial public

17

Table of Contents

offering. The early vesting was triggered as a result of our meeting targets for growth in cash distributions paid to unitholders. Williams Pipe Line was allocated G&A costs from Williams based on a three-factor formula that considers operating margin, payroll costs and property, plant and equipment prior to being acquired by us. The amount of G&A costs we pay will continue to be adjusted in the future to reflect additional G&A expenses incurred in connection with acquisitions as well as annual escalation. As discussed above in Recent Developments, the amount of G&A incurred by us in the future, and the way we recognize G&A expenses, will change following Williams’ sale of its interest in us and the associated termination of the existing Omnibus Agreement and the adoption of the New Omnibus Agreement.

Net interest expense for the three months ended March 31, 2003 was $8.5 million compared to $0.8 million for the three months ended March 31, 2002. The increase in interest expense was primarily related to the long-term debt financing of Williams Pipe Line. The weighted average interest rates on all our borrowings increased from 2.6% in 2002 to 6.3% in 2003, and the weighted average debt outstanding increased from $280.3 million in 2002 to $570.0 million in 2003.

We do not pay income taxes because we are a partnership. However, Williams Pipe Line was subject to income taxes prior to our acquisition of it in April 2002. Taxes on these earnings were at income tax rates of approximately 38% for the three months ended March 31, 2002 based on the effective income tax rate for Williams as a result of Williams’ tax-sharing arrangement with its subsidiaries. The effective income tax rate exceeds the U.S. federal statutory income tax rate primarily due to state income taxes.

Net income for the three months ended March 31, 2003 was $29.1 million compared to $21.1 million for the three months ended March 31, 2002, an increase of $8.0 million, or 38%. Operating profit increased $9.3 million primarily due to increased revenues from the Williams Pipe Line system and petroleum products terminals and reduced G&A expenses. Net interest expense increased $7.7 million primarily due to costs from the debt financing associated with the Williams Pipe Line acquisition. Other income decreased $1.5 million primarily due to a $1.0 million gain on the sale of land during 2002 and an increase in debt placement fee amortization expense of $0.5 million. Income taxes decreased $7.8 million as a result of Williams Pipe Line being included in our partnership structure in the first quarter of 2003, compared to the first quarter of 2002 when it was a taxable entity.

Other Known Trends or Events

We have significant relationships with Williams, which is the current owner of our General Partner, and Farmland. Williams has completed a number of asset sales and entered into secured debt agreements to address its liquidity needs, and Farmland has filed for bankruptcy. Our relationships with these two entities are described below:

Williams – During the past year, Williams has experienced financial and liquidity difficulties and currently does not have an investment grade credit rating. These financial difficulties have raised questions concerning Williams’ ability to meet its existing financial obligations. However, Williams has not filed for bankruptcy protection and neither Williams, our General Partner nor any other Williams’ affiliate has advised us of any intention by Williams, any Williams’ affiliate or our General Partner to place Williams or our General Partner into bankruptcy.