Sunoco Logistics--Form 10-K
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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

 


 

FORM 10-K

 


 

(Mark One)

 

x ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 

For the fiscal year ended December 31, 2004

 

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 number 1-31219

 


 

SUNOCO LOGISTICS PARTNERS L.P.

(Exact name of registrant as specified in its charter)

 


 

Delaware   23-3096839
(State or other jurisdiction of
incorporation or organization)
  (I.R.S. Employer
Identification No.)

Ten Penn Center

1801 Market Street, Philadelphia, PA

  19103-1699
(Address of principal executive offices)   (Zip Code)

 

Registrant’s telephone number, including area code: (215) 977-3000

 


 

Securities registered pursuant to Section 12(b) of the Act:

 

Title of each class


 

Name of each exchange
on which registered


Common Units representing limited partnership interests   New York Stock Exchange
Senior Notes 7.25%, due February 15, 2012   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 amendments of this Form 10-K.    x

 

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

 

The aggregate value of the Common Units held by non-affiliates of the registrant (treating all executive officers and directors of the registrant and holders of 10 percent or more of the Common Units outstanding (including the General Partner of the registrant, Sunoco Partners LLC, as if they may be affiliates of the registrant)) was approximately $328.5 million as of June 30, 2004, based on $35.90 per unit, the closing price of the Common Units as reported on the New York Stock Exchange on that date.

 

At February 28, 2005, the number of the registrant’s Common Units outstanding was 15,606,314, and its Subordinated Units outstanding was 8,537,729.

 

DOCUMENTS INCORPORATED BY REFERENCE: NONE



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TABLE OF CONTENTS

 

PART I

   1
   

ITEM 1.

  

BUSINESS

   1
   

ITEM 2.

  

PROPERTIES

   20
   

ITEM 3.

  

LEGAL PROCEEDINGS

   20
   

ITEM 4.

  

SUBMISSION OF MATTERS TO A VOTE OF SECURITYHOLDERS

   20

PART II

   21
   

ITEM 5.

  

MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED SECURITYHOLDER MATTERS AND PURCHASES OF EQUITY SECURITIES

   21
   

ITEM 6.

  

SELECTED FINANCIAL DATA

   22
   

ITEM 7.

  

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

   26
   

ITEM 7A.

  

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

   52
   

ITEM 8.

  

FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

   52
   

ITEM 9.

  

CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

   85
   

ITEM 9A.

  

CONTROLS AND PROCEDURES

   85

PART III

   86
   

ITEM 10.

  

DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT

   86
   

ITEM 11.

  

EXECUTIVE COMPENSATION

   90
   

ITEM 12.

  

SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED SECURITYHOLDER MATTERS

   97
   

ITEM 13.

  

CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS

   101
   

ITEM 14.

  

PRINCIPAL ACCOUNTANT FEES AND SERVICES

   102

PART IV

   103
   

ITEM 15.

  

EXHIBITS AND FINANCIAL STATEMENT SCHEDULES

   103

SIGNATURES

   106


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Forward-Looking Statements

 

Certain matters discussed in this report, excluding historical information, include forward-looking statements made in reliance on the safe harbor provisions of the Private Securities Litigation Reform Act of 1995.

 

Forward-looking statements discuss Sunoco Logistics Partners L.P.’s (the “Partnership”) expected future results based on current and pending business operations, and may be identified by words such as “anticipates”, “believes”, “expects”, “planned”, “scheduled” or similar expressions. Although management of the Partnership believes these forward-looking statements are reasonable, they are based upon a number of assumptions, any or all of which ultimately may prove to be inaccurate. Statements made regarding future results are subject to numerous assumptions, uncertainties and risks that may cause future results to be materially different from the results stated or implied in this document.

 

The following are among the important factors that could cause actual results to differ materially from any results projected, forecasted, estimated or budgeted:

 

    Changes in demand both for crude oil we buy and sell, as well as for crude oil and refined petroleum products that we store and distribute;

 

    Changes in demand for storage in the Partnership’s petroleum terminals;

 

    The loss of Sunoco, Inc. (R&M) as a customer or a significant reduction in its current level of throughput and storage with the Partnership;

 

    An increase in the competition encountered by the Partnership’s petroleum terminals, pipelines and crude oil acquisition and marketing operations;

 

    Changes in the throughput on petroleum pipelines owned and operated by third parties and connected to the Partnership’s petroleum pipelines and terminals;

 

    Changes in the financial condition or operating results of joint ventures and other holdings in which the Partnership has an equity ownership interest;

 

    Changes in the general economic conditions in the United States;

 

    Changes in laws and regulations to which the Partnership is subject, including federal, state, and local tax, safety, environmental and employment laws;

 

    Phase-outs or restrictions on the use of MTBE;

 

    Improvements in energy efficiency and technology resulting in reduced demand;

 

    The Partnership’s ability to manage rapid growth;

 

    The Partnership’s ability to control costs;

 

    The effect of changes in accounting principles and tax laws and interpretations of both;

 

    Global and domestic economic repercussions from terrorist activities and international hostilities and the government’s response thereto;

 

    Changes in the level of operating expenses and hazards related to operating facilities (including equipment malfunction, explosions, fires, spills and the effects of severe weather conditions);

 

    The occurrence of operational hazards or unforeseen interruptions for which the Partnership may not be adequately insured;

 

    The age of, and changes in the reliability and efficiency of the Partnership’s operating facilities or those of Sunoco, Inc. (R&M) or third parties;

 

    Changes in the expected level of environmental capital, operating, or remediation spending;


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    Delays related to construction of, or work on, new or existing facilities and issuance of applicable permits;

 

    Changes in insurance markets resulting in increased costs and reductions in the level and types of coverage available;

 

    The Partnership’s ability to identify acquisitions under favorable terms, successfully consummate announced acquisitions or expansions and integrate them into existing business operations;

 

    Risks related to labor relations and workplace safety;

 

    Non-performance by major customers, suppliers or other business partners;

 

    Price trends and overall demand for refined petroleum products, crude oil and natural gas liquids in the United States, economic activity, weather, alternative energy sources, conservation and technological advances may affect price trends and demand for the Partnership’s business activities;

 

    Changes in the Partnership’s tariff rates, implemented by federal and/or state government regulators;

 

    The amount of the Partnership’s indebtedness, which could make the Partnership vulnerable to general adverse economic and industry conditions, limit the Partnership’s ability to borrow additional funds, place it at competitive disadvantages compared to competitors that have less debt, or have other adverse consequences;

 

    Restrictive covenants in the Partnership’s or Sunoco, Inc.’s credit agreements;

 

    Changes in the Partnership’s or Sunoco, Inc.’s credit ratings, as assigned by ratings agencies;

 

    The condition of the debt capital markets and equity capital markets in the United States, and the Partnership’s ability to raise capital in a cost-effective way;

 

    Changes in interest rates on the Partnership’s outstanding debt, which could increase the costs of borrowing;

 

    Military conflicts between, or internal instability in, one or more oil-producing countries, and governmental actions or other disruptions in the ability to obtain crude oil;

 

    Changes in applicable statutes and governmental regulations (or the interpretations thereof), including those relating to the environment and global warming;

 

    Claims of the Partnership’s non-compliance with regulatory and statutory requirements; and

 

    The costs and effects of legal and administrative claims and proceedings against the Partnership or any entity which it has an ownership interest, and changes in the status of, or the initiation of new litigation, claims or proceedings, to which the Partnership, or any entity which it has an ownership interest, is a party.

 

These factors are not necessarily all of the important factors that could cause actual results to differ materially from those expressed in any of the Partnership’s forward-looking statements. Other unknown or unpredictable factors could also have material adverse effects on future results. The Partnership undertakes no obligation to update publicly any forward-looking statement whether as a result of new information or future events.


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PART I

 

ITEM 1. BUSINESS

 

(a) General Development of Business

 

The Partnership is a Delaware limited partnership formed by Sunoco, Inc. on October 15, 2001 to own, operate and acquire a geographically diversified portfolio of complementary pipeline, terminalling, and crude oil acquisition and marketing assets. The Partnership completed its initial public offering (“IPO”) on February 8, 2002. The principal executive offices of Sunoco Partners LLC, the Partnership’s general partner (the “General Partner”), are located at Ten Penn Center, 1801 Market Street, Philadelphia, Pennsylvania 19103 (telephone (215) 977-3000). The Partnership’s website address is www.sunocologistics.com.

 

Sunoco, Inc., through its wholly-owned subsidiaries (collectively, “Sunoco”), owns approximately 62.6 percent of the partnership interests at December 31, 2004, including the 2 percent general partner interest.

 

(b) Financial Information about Segments

 

See Part II, Item 8. Financial Statements and Supplementary Data.

 

(c) Narrative Description of Business

 

The Partnership is principally engaged in the transport, terminalling and storage of refined products and crude oil and the purchase and sale of crude oil. Sunoco, Inc. (R&M), a wholly-owned refining and marketing subsidiary of Sunoco (“Sunoco R&M”), accounted for approximately 51 percent of the Partnership’s total revenues for the year ended December 31, 2004. The business comprises three segments:

 

    The Eastern Pipeline System primarily serves the Northeast and Midwest United States operations of Sunoco R&M and includes: approximately 1,740 miles of refined product pipelines, including a two-thirds interest in the 80-mile refined product Harbor pipeline, and 58 miles of interrefinery pipelines between two of Sunoco R&M’s refineries; a 123-mile crude oil pipeline; a 9.4 percent interest in Explorer Pipeline Company, a joint venture that owns a 1,413-mile refined product pipeline; a 31.5 percent interest in Wolverine Pipe Line Company, a joint venture that owns a 721-mile refined product pipeline; a 12.3 percent interest in West Shore Pipe Line Company, a joint venture that owns a 652-mile refined product pipeline; and a 14.0 percent interest in Yellowstone Pipe Line Company, a joint venture that owns a 655-mile refined product pipeline.

 

    The Terminal Facilities consist of 35 inland refined product terminals with an aggregate storage capacity of 5.9 million barrels, primarily serving the Partnership’s Eastern Pipeline System; a 2.0 million barrel refined product terminal serving Sunoco R&M’s Marcus Hook refinery near Philadelphia, Pennsylvania; a 12.5 million barrel marine crude oil terminal on the Texas Gulf Coast, the Nederland Terminal; one inland and two marine crude oil terminals with a combined capacity of 3.4 million barrels, and related pipelines, all of which serve Sunoco R&M’s Philadelphia refinery; a ship and barge dock which serves Sunoco R&M’s Eagle Point refinery; and a 1.0 million barrel liquefied petroleum gas (“LPG”) terminal near Detroit, Michigan.

 

    The Western Pipeline System gathers, purchases, sells, and transports crude oil principally in Oklahoma and Texas and consists of approximately 1,930 miles of crude oil trunk pipelines and approximately 520 miles of crude oil gathering lines that supply the trunk pipelines; approximately 120 crude oil transport trucks; approximately 130 crude oil truck unloading facilities; and a 43.8 percent interest in West Texas Gulf Pipe Line Company, a joint venture that owns a 579-mile crude oil pipeline.

 

The Partnership and its equity interests are principally engaged in the transport, terminalling, and storage of refined products and crude oil and in the purchase and sale of crude oil in 19 states. Revenues are generated by

 

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charging tariffs for transporting refined products, crude oil and other hydrocarbons through the pipelines and by charging fees for storing refined products, crude oil, and other hydrocarbons, and for providing other services at the Partnership’s terminals. The Partnership also generates revenue by purchasing domestic crude oil and selling it to Sunoco R&M and other customers. Generally, as crude oil is purchased, corresponding sale transactions are simultaneously entered into involving physical deliveries of crude oil, which enables the Partnership to secure a profit on the transaction at the time of purchase and establish a substantially balanced position, thereby minimizing exposure to price volatility after the initial purchase. The Partnership’s practice is to not enter into futures contracts.

 

Upon the closing of the Partnership’s IPO on February 8, 2002, the Eastern Pipeline System, Terminal Facilities and Western Pipeline System were transferred to the Partnership, including certain related liabilities. Certain other liabilities, including environmental and toxic tort liabilities, have been retained by Sunoco, Inc. under the indemnification provisions of an omnibus agreement (the “Omnibus Agreement”) (see Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations-Agreements with Sunoco R&M and Sunoco, Inc.”). The following discussion has been prepared as if the assets were operated as a stand-alone business throughout the periods presented. Unless otherwise noted, the Partnership owns and operates all of the assets described.

 

Eastern Pipeline System

 

Sunoco R&M accounted for approximately 66 percent of the Eastern Pipeline segment’s total revenues for the year ended December 31, 2004.

 

Refined Product Pipelines

 

The refined product pipelines transport refined products from Sunoco R&M’s Philadelphia and Marcus Hook, Pennsylvania, Toledo, Ohio and Eagle Point, New Jersey refineries, as well as from third parties, to markets in New York, New Jersey, Pennsylvania, Ohio, and Michigan. The refined products transported in these pipelines include multiple grades of gasoline, middle distillates (such as heating oil, diesel and jet fuel), LPGs (such as propane, butane, isobutene, and a butane/butylene mixture), refining feedstocks, and other hydrocarbons (such as toluene and xylene). The Federal Energy Regulatory Commission (“FERC”) regulates the rates for interstate shipments on the Eastern Pipeline System and the Pennsylvania Public Utility Commission (“PA PUC”) regulates the rates for intrastate shipments in Pennsylvania. The Partnership also leases to Sunoco R&M three bi-directional, 18-mile interrefinery pipelines and a four-mile pipeline spur extending to the Philadelphia International Airport.

 

The following table details the total shipments on the refined product pipelines in each of the years presented. Total shipments represent the total average daily pipeline throughput multiplied by the number of miles of pipeline through which each barrel has been shipped. Management of the Partnership believes that total shipments is a better performance indicator for the Eastern Pipeline System than barrels transported as certain refined product pipelines, including interrefinery and transfer pipelines, transport large volumes over short distances and generate minimal revenues. The following excludes amounts attributable to equity ownership interests in the corporate joint ventures:

 

     Year Ended December 31,

     2002

   2003

   2004

Total shipments (in thousands of barrel miles per day)

   45,712    44,657    46,284

 

The mix of refined petroleum products delivered varies seasonally, with gasoline demand peaking during the summer months, and demand for heating oil and other distillate fuels being higher in the winter. In addition, weather conditions in the areas served by the Eastern Pipeline System affect both the demand for, and the mix of,

 

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the refined petroleum products delivered through the Eastern Pipeline System, although historically any overall impact on the total volume shipped has been short term.

 

Crude Oil Pipeline

 

This 123-mile, 16-inch crude oil pipeline runs from Marysville, Michigan to Toledo, Ohio. This pipeline receives crude oil from the Enbridge pipeline system for delivery to Sunoco R&M and BP refineries located in Toledo, Ohio and to Marathon Ashland’s (“MAP”) Samaria, Michigan tank farm, which supplies its refinery in Detroit, Michigan. Marysville is also a truck injection point for local production. Sunoco R&M is the major shipper on the pipeline.

 

The table below sets forth the average daily number of barrels of crude oil transported through this crude oil pipeline in each of the years presented:

 

     Year Ended December 31,

     2002

   2003

   2004

Crude oil throughput (in barrels per day (“bpd”))

   95,311    91,951    111,104

 

Explorer Pipeline

 

The Partnership owns a 9.4 percent interest in Explorer Pipeline Company (“Explorer”), a joint venture that owns a 1,413-mile common carrier refined product pipeline. Other owners of Explorer are Shell, MAP, ChevronTexaco, CITGO, and ConocoPhillips. The system, which is operated by Explorer employees, originates from the refining centers of Lake Charles, Louisiana and Beaumont, Port Arthur and Houston, Texas, and extends to Chicago, Illinois, with delivery points in the Houston, Dallas/Fort Worth, Tulsa, St. Louis, and Chicago areas. Shippers on the pipeline include most of the affiliates of the owners and non-affiliated customers. Sunoco R&M does not regularly ship on the pipeline. In 2000, the FERC approved Explorer’s application for market-based rates for all its tariffs. The Partnership receives a quarterly cash dividend from Explorer that is proportionate with its ownership interest.

 

During the third quarter of 2003, Explorer completed its $100 million plus expansion of the system’s capacity. The capacity from Port Arthur to Tulsa was expanded by 130,000 bpd to 690,000 bpd and the capacity from Tulsa to Chicago was expanded by 100,000 bpd to 450,000 bpd.

 

Wolverine Pipe Line

 

On November 15, 2002, the Partnership acquired a 31.5 percent interest in Wolverine Pipe Line Company (“Wolverine”), a joint venture that owns a 721-mile common carrier pipeline that transports primarily refined products. Other owners of Wolverine are Citgo, ExxonMobil, MAP, and Shell. The system, which is operated by ExxonMobil and Wolverine employees, originates from Chicago, Illinois and extends to Detroit, Grand Haven, and Bay City, Michigan with delivery points along the way. Shippers on the pipeline include affiliates of most of the owners and non-affiliated customers. The Partnership and its affiliates do not ship on the pipeline. In 2002, the FERC approved Wolverine’s application for market-based rates for the Detroit, Jackson, Niles, Hammond, and Lockport destinations. The Partnership receives a quarterly cash dividend from Wolverine that is proportionate with its ownership interest.

 

West Shore Pipe Line

 

On November 15, 2002, the Partnership acquired a 9.2 percent interest in West Shore Pipe Line Company (“West Shore”), a joint venture that owns a 652-mile common carrier refined product pipeline. On September 30, 2003, the Partnership acquired an additional 3.1 percent interest in West Shore increasing its overall ownership percentage to 12.3 percent. Other owners of West Shore are Citgo, ExxonMobil, BP, Buckeye, and Shell. The

 

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system, which is operated by Citgo employees, originates from the Chicago, Illinois refining center and extends to Madison and Green Bay, Wisconsin with delivery points along the way. Shippers on the pipeline include affiliates of most of the owners and non-affiliated customers. The Partnership and its affiliates do not ship on the pipeline. In 2002, the FERC approved West Shore’s application for market-based rates for the Chicago area. The Partnership receives a quarterly cash dividend from West Shore that is proportionate with its ownership interest.

 

Yellowstone Pipe Line

 

On November 15, 2002, the Partnership acquired a 14.0 percent interest in Yellowstone Pipe Line Company (“Yellowstone”), a joint venture that owns a 655-mile common carrier refined product pipeline. Other owners of Yellowstone are ExxonMobil and ConocoPhillips. The system, which is operated by ConocoPhillips employees, originates from the Billings, Montana refining center and extends to Moses Lake, Washington with delivery points along the way. Shippers on the pipeline include affiliates of the owners and non-affiliated customers. Tariff rates are regulated by the FERC for interstate shipments and the Montana Public Service Commission for intrastate shipments in Montana. The Partnership and its affiliates do not ship on the pipeline.

 

In 1997, the Yellowstone board of directors established a dividend policy whereby dividends would not be paid to owners until the debt incurred to finance a multi-year pipeline upgrade program was repaid. The last payment on the debt was made in 2004, and the Partnership received a quarterly cash dividend from Yellowstone of $0.3 million in January 2005, proportionate with its ownership interest.

 

Terminal Facilities

 

Sunoco R&M accounted for approximately 67 percent of the Terminal Facilities segment’s total revenues for the year ended December 31, 2004.

 

Refined Product Terminals

 

The Partnership’s 35 inland refined product terminals receive refined products from pipelines and distribute them to Sunoco R&M and to third parties, who in turn deliver them to end-users and retail outlets. Terminals play a key role in moving product to the end-user market by providing the following services: storage and inventory management; distribution; blending to achieve specified grades of gasoline; and other ancillary services that include the injection of additives and the filtering of jet fuel. Typically, the Partnership’s terminal facilities consist of multiple storage tanks and are equipped with automated truck loading equipment that is available 24 hours a day. This automated system provides for control of allocations, credit and carrier certification.

 

The Partnership’s refined product terminals derive most of their revenues from terminalling fees paid by customers. A fee is charged for receiving refined products into the terminal and delivering them to trucks, barges, or pipelines. In addition to terminalling fees, the Partnership’s revenues are generated by charging customers fees for blending, injecting additives, and filtering jet fuel. Refined product terminals generate the balance of their revenues from the handling of other hydrocarbons for Sunoco R&M at Vanport, Pennsylvania and Toledo, Ohio and from lubricants handled for Sunoco R&M at Cleveland, Ohio. Sunoco R&M accounts for substantially all of the Partnership’s refined product terminal revenues. The Eastern Pipeline System supplies the majority of the Partnership’s refined product terminals, with third-party pipelines supplying the remainder.

 

The table below sets forth the total average daily throughput for the inland refined product terminals in each of the years presented:

 

     Year Ended December 31,

     2002

   2003

   2004

Refined products throughput (bpd)

   272,784    283,071    340,675

 

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The following table outlines the number of terminals and storage capacity in barrels (“bbls”) by state:

 

State


   Number of
Terminals


   Storage
Capacity


          (bbls)

Indiana

   1    207,000

Maryland

   1    646,000

Michigan

   2    408,000

New Jersey

   4    751,200

New York(1)

   3    623,600

Ohio

   7    916,500

Pennsylvania

   16    2,043,700

Virginia

   1    277,000
    
  

Total

   35    5,873,000
    
  

(1) The Partnership has a 45 percent ownership interest in a terminal at Inwood, New York. The storage capacity included in the table represents the proportionate share of capacity attributable to the Partnership’s ownership interest.

 

Nederland Terminal

 

The Nederland Terminal, which is located on the Sabine-Neches waterway between Beaumont and Port Arthur, Texas, is a large marine terminal that provides inventory management, storage, and distribution services for refiners and other large end-users of crude oil. The terminal receives, stores, and distributes crude oil, feedstocks, lubricants, petrochemicals, and bunker oils (used for fueling ships and other marine vessels). In addition, it also blends lubricants and is equipped with petroleum laboratory facilities. The terminal currently has a total shell storage capacity of approximately 12.5 million barrels in 128 aboveground storage tanks with individual capacities of up to 660,000 barrels. During 2003, construction of two new tanks was completed, which added approximately 1.3 million barrels of storage capacity to the terminal.

 

The Nederland Terminal can receive crude oil at each of its five ship docks and three barge berths, which can accommodate any vessel capable of navigating the 40-foot freshwater draft of the Sabine-Neches Ship Channel. The five ship docks are capable of receiving over 1.0 million bpd of crude oil. The terminal can also receive crude oil through a number of pipelines, including the Shell pipeline from Louisiana, the Department of Energy (“DOE”) Big Hill pipeline, the DOE West Hackberry pipeline, and the Partnership’s Western Pipeline System. The DOE pipelines connect the terminal to the United States Strategic Petroleum Reserve’s West Hackberry caverns at Hackberry, Louisiana and Big Hill caverns near Winnie, Texas, which have an aggregate storage capacity of 370 million barrels. The Nederland Terminal’s pipeline connections to major markets in the Lake Charles, Beaumont, Port Arthur, Houston, and Midwest areas provide customers with flexibility. During the second half of 2004, the Nederland Terminal was one of two facilities connected to the Cameron Highway pipeline, a new 390-mile, 24-inch to 30-inch pipeline that has the capacity to deliver up to 500,000 barrels per day of crude oil from off-shore production developments in the Gulf of Mexico. Crude oil deliveries through the Cameron Highway pipeline began in February 2005.

 

The Nederland Terminal can deliver crude oil and other petroleum products via pipeline, barge, ship, rail, or truck. In the aggregate, the terminal is capable of delivering over 1.0 million bpd of crude oil to 12 connecting pipelines. The connecting pipelines include the ExxonMobil pipelines to Wichita Falls, Texas and to its Beaumont, Texas refinery, the DOE pipelines to the Big Hill and West Hackberry Strategic Petroleum Reserve caverns, the Premcor pipeline to its Port Arthur, Texas refinery, the TotalFinaElf pipelines to its Port Arthur, Texas refinery, the Shell pipeline to Houston, Texas refineries, the West Texas Gulf and the Partnership’s pipelines to the Mid-Valley pipeline at Longview, Texas and to the Citgo pipeline at Sour Lake, Texas, the Partnership’s pipeline to Seabreeze, Texas, and the Alon pipeline to its Big Spring, Texas refinery.

 

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The table below sets forth the total average daily throughput for the Nederland Terminal in each of the years presented:

 

     Year Ended December 31,

     2002

   2003

   2004

Crude oil and refined products throughput (bpd)

   437,381    441,701    487,828

 

Revenues are generated at the Nederland Terminal primarily by providing long-term and short-term, or spot, storage services and throughput capability to a number of customers. Most of the terminal’s total revenues in 2004 were from unaffiliated third parties.

 

Fort Mifflin Terminal Complex

 

The Fort Mifflin Terminal Complex is located on the Delaware River in Philadelphia and supplies Sunoco R&M’s Philadelphia refinery with all of its crude oil. These assets include the Fort Mifflin Terminal, the Hog Island Wharf, the Darby Creek Tank Farm and connecting pipelines. Revenues are generated from the Fort Mifflin Terminal Complex by charging fees based on tank capacity and throughput. Substantially all of the revenues from the Fort Mifflin Terminal Complex are derived from Sunoco R&M.

 

The Fort Mifflin Terminal consists of two ship docks with 40-foot freshwater drafts and nine tanks with a total storage capacity of 570,000 barrels. Two of the 80,000-barrel tanks can be used to store refined products. This terminal also has a connection from the Colonial Pipeline System. Crude oil and some refined products enter the Fort Mifflin Terminal primarily from marine vessels on the Delaware River. One Fort Mifflin dock is designed to handle crude oil from very large crude carrier-class tankers and smaller crude oil vessels. The other dock can accommodate only smaller crude oil vessels.

 

The Hog Island Wharf is located next to the Fort Mifflin Terminal on the Delaware River and receives crude oil via two ship docks, one of which can accommodate crude oil tankers and smaller crude oil vessels and the other of which can accommodate some smaller crude oil vessels. Hog Island Wharf supplies the Partnership’s Darby Creek Tank Farm and Fort Mifflin Terminal with crude oil.

 

The Darby Creek Tank Farm is a primary crude oil storage terminal for Sunoco R&M’s Philadelphia refinery. This facility has 26 tanks with a total storage capacity of 2.9 million barrels. Darby Creek receives crude oil from the Fort Mifflin Terminal and Hog Island Wharf via the Partnership’s pipelines. The tank farm then stores the crude oil and pumps it to the Philadelphia refinery via the Partnership’s pipelines.

 

The table below sets forth the average daily number of barrels of crude oil and refined products delivered to Sunoco R&M’s Philadelphia refinery in each of the years presented:

 

     Year Ended December 31,

     2002

   2003

   2004

Crude oil throughput (bpd)

   310,980    311,455    330,022

Refined products throughput (bpd)

   11,631    10,934    6,533
    
  
  

Total (bpd)

   322,611    322,389    336,555
    
  
  

 

Marcus Hook Tank Farm

 

The Marcus Hook Tank Farm stores substantially all of the gasoline and middle distillates that Sunoco R&M ships from its Marcus Hook refinery. This facility has 16 tanks with a total storage capacity of approximately 2.0 million barrels. After receipt of refined products from the Marcus Hook refinery, the tank farm

 

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either stores or delivers them to the Partnership’s Twin Oaks terminal or to the Twin Oaks pump station, which supplies the Eastern Pipeline System.

 

The table below sets forth the total average daily throughput for the Marcus Hook Tank Farm in each of the years presented:

 

     Year Ended December 31,

     2002

   2003

   2004

Refined products throughput (bpd)

   150,008    157,233    144,724

 

Eagle Point Dock

 

On March 30, 2004, the Partnership acquired the Eagle Point logistics assets from Sunoco R&M (see “Acquisitions” for further description), including a ship and barge dock connected to the Sunoco R&M Eagle Point refinery. This dock, located on the Delaware River, can accommodate four ships or barges and supplies the Eagle Point refinery with all of its crude oil. The dock can also receive and deliver intermediate products and refined products to outbound ships and barges. For the period from the date of acquisition to December 31, 2004, the average daily number of barrels through the Eagle Point dock was 204,105 bpd, consisting of 136,888 bpd of crude oil and 67,217 bpd of refined products.

 

Inkster Terminal

 

The Inkster Terminal, located near Detroit, Michigan, consists of eight salt caverns with a total storage capacity of 975,000 barrels. The Partnership uses the Inkster Terminal’s storage in connection with its Toledo, Ohio to Sarnia, Canada pipeline system and for the storage of LPGs from Sunoco R&M’s Toledo refinery and from Canada. The terminal can receive and ship LPGs in both directions at the same time and has a propane truck loading rack.

 

Western Pipeline System

 

Sunoco R&M accounted for approximately 49 percent of the Western Pipeline System segment’s total revenues for the year ended December 31, 2004.

 

Crude Oil Pipelines

 

The Partnership owns and operates approximately 1,930 miles of crude oil trunk pipelines and approximately 520 miles of crude oil gathering pipelines in three primary geographic regions—Oklahoma, West Texas, and the Texas Gulf Coast and East Texas region. The Partnership is the primary shipper on the Western Pipeline System. The Partnership also delivers crude oil for Sunoco R&M and for various third parties from points in Texas and Oklahoma. Refineries directly connected to the Western Pipeline System include Sunoco R&M’s and Sinclair’s Tulsa, Oklahoma refineries and the Gary-Williams refinery in Wynnewood, Oklahoma.

 

The Partnership’s pipelines also access several trading hubs, including the largest and most significant trading hub for crude oil in the United States located in Cushing, Oklahoma (“Cushing”), as well as other trading hubs located in Colorado City and Longview, Texas. The Partnership’s crude oil pipelines also connect with other pipelines that deliver crude oil to a number of third-party refineries. In each geographic region, the Partnership has major crude oil trunk line systems that ship crude oil across a number of different-sized trunk pipeline segments. The Partnership transports most of the crude oil to, and lube extracted feedstock from, Sunoco R&M’s Tulsa, Oklahoma refinery.

 

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The table below sets forth the average daily number of barrels of crude oil transported on the Partnership’s crude oil pipelines in each of the years presented:

 

     Year Ended December 31,

     2002

   2003

   2004

Crude oil throughput (bpd)(1)

   286,912    304,471    298,797

(1) Includes lube extracted feedstocks transported from Sunoco R&M’s Tulsa, Oklahoma refinery.

 

Oklahoma

 

The Partnership owns and operates a large crude oil pipeline and gathering system in Oklahoma. This system contains approximately 800 miles of crude oil trunk pipelines and approximately 180 miles of crude oil gathering pipelines. The Partnership has the ability to deliver substantially all of the crude oil gathered on its Oklahoma system to Cushing. Additionally, deliveries are made on the Oklahoma system to:

 

    Sunoco R&M’s and Sinclair’s Tulsa refineries;

 

    Gary-Williams’ Wynnewood refinery; and

 

    ConocoPhillips’ pipeline, which is connected to its Ponca City refinery.

 

Revenues are generated on the Partnership’s Oklahoma system from tariffs paid by shippers utilizing the Partnership’s transportation services. The Partnership files these tariffs with the Oklahoma Corporation Commission and the FERC. The Partnership is one of the largest purchasers of crude oil from producers in the state, and is the primary shipper on its Oklahoma system.

 

West Texas

 

The Partnership owns and operates approximately 760 miles of crude oil trunk pipelines and approximately 190 miles of crude oil gathering pipelines in West and North Central Texas. Deliveries are made on the West Texas system to:

 

    a Valero, L.P. pipeline at Dixon, Texas that delivers crude oil to Valero Energy Corporation’s refinery in McKee, Texas;

 

    a ConocoPhillips’ pipeline at South Bend, Texas that makes deliveries to ConocoPhillips’s Ponca City refinery;

 

    a TEPPCO pipeline at South Bend that makes deliveries to Gary-Williams’ Wynnewood refinery;

 

    the West Texas Gulf pipeline, which is 43.8 percent owned by the Partnership, at Tye and Colorado City, Texas that connects to the Mid-Valley pipeline in Longview, Texas, which is 55.3 percent owned by Sunoco and makes deliveries to Sunoco R&M’s Toledo refinery and other Midwest refineries; and

 

    other third-party pipelines at Colorado City that deliver crude oil to Cushing.

 

The Partnership is the shipper of substantially all the volume on this system. Revenues are generated in West Texas from tariffs paid by shippers utilizing the Partnership’s transportation services. These tariffs are filed with the Texas Railroad Commission.

 

Texas Gulf Coast and East Texas

 

The Partnership owns and operates approximately 370 miles of crude oil trunk pipelines and approximately 150 miles of crude oil gathering pipelines that extend between the Texas Gulf Coast region near Beaumont and Baytown, Texas and the East Texas field near Longview, Texas. The Partnership transports multiple grades of

 

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crude oil, including foreign imports, and other refinery and petrochemical feedstocks, such as condensate and naphtha, on these pipelines. Crude oil is received for these systems from other pipelines, the Nederland Terminal, the Partnership’s trucks, third-party trucks, and the Partnership’s pipeline gathering systems. This system provides access to major delivery points with interconnecting pipelines in Texas at Longview, Sour Lake, and Nederland.

 

Revenues are generated from tariffs paid by shippers utilizing the Partnership’s transportation services. These tariffs are filed with the Texas Railroad Commission and the FERC. The Partnership is the primary shipper on the Texas Gulf Coast and East Texas system. Sunoco R&M ships on the Nederland to Longview segment, which connects with the Mid-Valley pipeline for deliveries to Sunoco R&M’s Toledo refinery.

 

West Texas Gulf Pipe Line

 

On November 15, 2002, the Partnership acquired a 43.8 percent interest in West Texas Gulf Pipe Line Company (“West Texas Gulf”), a joint venture that owns and operates a 579-mile common carrier crude oil pipeline. Other owners of West Texas Gulf are ChevronTexaco, BP, and Citgo. The system, which was operated by ChevronTexaco during 2004, originates from the West Texas oil fields at Colorado City and the Nederland crude oil import terminals and extends to Longview, Texas where deliveries are made to several pipelines, including the Mid-Valley pipeline. On January 1, 2005, the Partnership became the operator of this system. Shippers on the pipeline are the Partnership, Sunoco R&M, an affiliate of one other owner and several unaffiliated customers. The Partnership receives a quarterly cash dividend from West Texas Gulf that is proportionate with its ownership interest.

 

Crude Oil Acquisition and Marketing

 

In addition to receiving tariff revenues for transporting crude oil on the Western Pipeline System, the Partnership generates most of its revenues through its crude oil acquisition and marketing operations, primarily in Oklahoma and Texas. These activities include: purchasing crude oil at the wellhead from producers and in bulk from aggregators at major pipeline interconnections and trading locations; transporting crude oil on the Partnership’s pipelines and trucks or, when necessary or cost effective, pipelines or trucks owned and operated by third parties; and marketing crude oil to refiners or resellers.

 

The marketing of crude oil is complex and requires detailed knowledge of the crude oil market and a familiarity with a number of factors, including types of crude oil, individual refinery demand for specific grades of crude oil, area market price structures for different grades of crude oil, location of customers, availability of transportation facilities, timing, and customers’ costs (including storage). The Partnership sells crude oil to major integrated oil companies, independent refiners, including Sunoco R&M for its Tulsa and Toledo refineries, and resellers in various types of sale and exchange transactions, at market prices for terms generally ranging from one month to one year.

 

The Partnership mitigates most of its pricing risk on purchase contracts by selling crude oil for an equal term on a similar pricing basis. The Partnership also mitigates most of its volume risk by entering into sales agreements, generally at the same time that purchase agreements are executed, at similar volumes. As a result, volumes sold are generally equal to volumes purchased.

 

The Partnership enters into contracts with producers at market prices generally for a term of one year or less, with a majority of the transactions on a 30-day renewable basis. For the year ended December 31, 2004, the Partnership purchased 186,827 bpd from approximately 3,400 producers and from approximately 34,000 leases, and undertook approximately 282,500 bpd of exchanges and bulk purchases during the same period.

 

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Crude Oil Purchases and Exchanges

 

In a typical producer’s operation, crude oil flows from the wellhead to a separator where the petroleum gases are removed. After separation, the producer treats the crude oil to remove water, sand, and other contaminants and then moves it to an on-site storage tank. When the tank is full, the producer contacts the Partnership’s field personnel to purchase and transport the crude oil to market. The crude oil in producers’ tanks is then either delivered directly or transported via truck to the Partnership’s pipeline or to a third party’s pipeline. The trucking services are performed either by the Partnership’s truck fleet or a third-party trucking operation.

 

The Partnership also enters into exchange agreements to enhance margins throughout the acquisition and marketing process. When opportunities arise to increase its margin or to acquire a grade of crude oil that more nearly matches its delivery requirement or the preferences of its refinery customers, the Partnership’s physical crude oil is exchanged with third parties. Generally, the Partnership enters into exchanges to acquire crude oil of a desired quality in exchange for a common grade crude oil or to acquire crude oil at locations that are closer to the Partnership’s end-markets, thereby reducing transportation costs.

 

The following table shows the Partnership’s average daily volume for crude oil lease purchases and other exchanges and bulk purchases for the years presented:

 

     Year Ended December 31,

     2002

   2003

   2004

     (in thousands of bpd)

Lease purchases:

              

Available for sale

   157    167    164

Exchanged

   32    26    23

Other exchanges and bulk purchases

   215    300    282
    
  
  

Total

   404    493    469
    
  
  

 

The Partnership’s business practice is generally to purchase only crude oil for which there is a corresponding sale agreement for physical delivery of crude oil to a third party or a Sunoco R&M refinery. Through this process, the Partnership seeks to maintain a position that is substantially balanced between crude oil purchases and future delivery obligations. The Partnership does not acquire and hold crude oil futures contracts or enter into other commodity derivative contracts.

 

The following table shows the average daily sales and exchange volume of crude oil for the years presented:

 

     Year Ended December 31,

     2002

   2003

   2004

     (in thousands of bpd)

Sunoco R&M refineries:

              

Toledo

   35    26    24

Tulsa

   73    80    80

Third parties

   63    79    85

Exchanges:

              

Purchased at the lease

   32    26    23

Other

   202    282    257
    
  
  

Total

   405    493    469
    
  
  

 

Market Conditions

 

Market conditions impact the Partnership’s sales and marketing strategies. During periods when demand for crude oil is weak, the market for crude oil is often in contango, meaning that the price of crude oil in a given

 

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month is less than the price of crude oil for delivery in a subsequent month. In a contango market, storing crude oil is favorable because storage owners at major trading locations can simultaneously purchase production at low current prices for storage and sell at higher prices for future delivery. When there is a higher demand than supply of crude oil in the near term, the market is backwardated, meaning that the price of crude oil in a given month exceeds the price of crude oil for delivery in a subsequent month. A backwardated market has a positive impact on marketing margins because crude oil marketers can continue to purchase crude oil from producers at a fixed premium to posted prices while selling crude oil at a higher premium to such prices.

 

Producer Services

 

Crude oil purchasers who buy from producers compete on the basis of competitive prices and highly responsive services. Through its team of crude oil purchasing representatives, the Partnership maintains ongoing relationships with more than 3,400 producers. Management of the Partnership believes that its ability to offer competitive pricing and high-quality field and administrative services to producers is a key factor in its ability to maintain its volume of lease purchased crude oil and to obtain new volume. Field services include efficient gathering capabilities, availability of trucks, willingness to construct gathering pipelines where economically justified, timely pickup of crude oil from storage tanks at the lease or production point, accurate measurement of crude oil volume received, avoidance of spills, and effective management of pipeline deliveries. Accounting and other administrative services include securing division orders (statements from interest owners affirming the division of ownership in crude oil purchased by the Partnership), providing statements of the crude oil purchased each month, disbursing production proceeds to interest owners, and calculating and paying production taxes on behalf of interest owners. In order to compete effectively, records of title and division order interests must be maintained by the Partnership in an accurate and timely manner for purposes of making prompt and correct payment of crude oil production proceeds, together with the correct payment of all production taxes associated with these proceeds.

 

Credit with Customers

 

When crude oil is marketed, the Partnership must determine the amount of any line of credit to be extended to a customer. Since typical sales transactions can involve tens of thousands of barrels of crude oil, the risk of nonpayment and nonperformance by customers is a major consideration in this business. Management of the Partnership believes that its sales are made to creditworthy entities or entities with adequate credit support. Credit review and analysis are also integral to the Partnership’s lease purchases. Payment for substantially all of the monthly lease production is sometimes made to the operator of the lease. The operator, in turn, is responsible for the correct payment and distribution of such production proceeds to the proper parties. In these situations, it must be determined by the Partnership whether the operator has sufficient financial resources to make such payments and distributions and to indemnify and defend the Partnership in the event a third party brings a protest, action, or complaint in connection with the ultimate distribution of production proceeds by the operator.

 

Crude Oil Trucking

 

The Partnership owns approximately 130 crude oil truck unloading facilities in Oklahoma, Texas, and New Mexico, the majority of which are located on the Partnership’s pipeline system. Approximately 270 crude oil truck drivers are employed by the general partner of the Partnership and approximately 120 crude oil transport trucks are owned. The crude oil truck drivers pick up crude oil at production lease sites and transport it to various truck unloading facilities on the Partnership’s pipelines and third-party pipelines. Third-party trucking firms are also retained to transport crude oil to certain facilities.

 

Pipeline and Terminal Control Operations

 

Almost all of the Partnership’s refined products and crude oil pipelines are operated via satellite, microwave, and frame relay communication systems from central control rooms located in Montello,

 

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Pennsylvania and Tulsa, Oklahoma. The Montello control center primarily monitors and controls the Partnership’s Eastern Pipeline System, and the Tulsa control center primarily monitors and controls the Western Pipeline System. The Nederland Terminal has its own control center.

 

The control centers operate with System Control and Data Acquisition, or SCADA, systems that continuously monitor real time operational data, including refined product and crude oil throughput, flow rates, and pressures. In addition, the control centers monitor alarms and throughput balances. The control centers operate remote pumps, motors, engines, and valves associated with the delivery of refined products and crude oil. The computer systems are designed to enhance leak-detection capabilities, sound automatic alarms if operational conditions outside of pre-established parameters occur, and provide for remote-controlled shutdown of pump stations on the Partnership’s pipelines. Pump stations and meter-measurement points along the Partnership’s pipelines are linked by satellite or telephone communication systems for remote monitoring and control, which reduces the requirement for full-time on-site personnel at most of these locations.

 

Acquisitions

 

Columbus Terminal Acquisition. On November 30, 2004, the Partnership acquired a refined products terminal located in Columbus, Ohio for approximately $8.0 million. The terminal is connected to a third-party, refined product, common carrier pipeline and includes 6 refined product tanks with approximately 160,000 barrels of working storage capacity, located on 13 acres; two truck racks for shipping gasoline, distillate fuels, and ethanol via tanker truck; and rail siding access for 4 rail cars for ethanol handling.

 

Harbor Pipeline Interest Acquisition. On June 28, 2004, the Partnership purchased an additional 33.3 percent undivided interest in the Harbor pipeline for $7.3 million. The Harbor pipeline is an 80-mile, 180,000 bpd refined product, common carrier pipeline originating near Woodbury, New Jersey and terminating in Linden, New Jersey. As a result of this transaction, the Partnership increased its undivided ownership interest to 66.7 percent and will continue to be the operator of the pipeline.

 

Baltimore and Manassas Terminals Acquisition. On April 28, 2004, the Partnership purchased two refined product terminals located in Baltimore, Maryland and Manassas, Virginia for $12.0 million. The Baltimore terminal is connected to a third-party, refined product, common carrier pipeline and includes 13 refined product tanks with approximately 646,000 barrels of working storage capacity, located on 35 acres; one truck rack for shipping gasoline and distillate fuels via tanker truck; and one marine dock with two berths for receiving refined products. The Manassas terminal is connected to a third-party, refined product, common carrier pipeline and includes 7 refined product tanks with approximately 277,000 barrels of working storage capacity, located on 11 acres, and one truck rack for shipping gasoline and distillate fuels via tanker truck.

 

Eagle Point Logistics Assets Acquisition. On March 30, 2004, the Partnership acquired the Eagle Point refinery logistics assets from Sunoco R&M for $20 million. The Eagle Point logistics assets consist of a crude oil and refined product ship and barge dock, a refined product truck rack, and a 4.5 mile, refined product pipeline from the Eagle Point refinery to the origin of the Harbor pipeline. In connection with the acquisition, the Partnership entered into a throughput agreement with Sunoco R&M whereby they have agreed to minimum volumes on the truck rack upon completion of certain capital improvements, which were completed during the fourth quarter of 2004.

 

Wolverine, West Shore and Yellowstone Pipe Line Interest Acquisitions. On November 15, 2002, the Partnership acquired an entity whose assets included a 31.5 percent interest in Wolverine, a joint venture that owns a 721-mile refined product pipeline; a 9.2 percent interest in West Shore, a joint venture that owns a 652-mile refined product pipeline; and a 14.0 percent interest in Yellowstone, a joint venture that owns a 655-mile refined product pipeline, for $54 million in cash. On September 30, 2003, the Partnership acquired an additional 3.1 percent interest in West Shore for $3.7 million, increasing its overall ownership percentage to 12.3 percent.

 

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West Texas Gulf Pipe Line Interest Acquisition. On November 15, 2002, the Partnership acquired a 43.8 percent interest in West Texas Gulf, a joint venture that owns a 579-mile crude oil pipeline, from an affiliate of Sunoco, Inc. for $10.6 million, including the issuance of 4,515 Partnership common units with a fair value at the date of issuance of $0.1 million. On January 1, 2005, the Partnership became the operator of this system.

 

The Partnership and its equity interests are principally engaged in the transport, terminalling and storage of refined products and crude oil and in the purchasing and sale of crude oil. Although the Partnership does not currently engage in business unrelated to the transportation or storage of crude oil and refined products and the other businesses described above, management of the Partnership may, in the future, consider and make acquisitions in other business areas.

 

Competition

 

As a result of the physical integration with Sunoco R&M’s refineries and the contractual relationship with Sunoco pursuant to the Omnibus Agreement and Sunoco R&M pursuant to agreements such as the pipelines and terminals storage and throughput agreement, management of the Partnership believes that it will not face significant competition for crude oil transported to the Philadelphia, Toledo, Tulsa, and Eagle Point refineries, or refined products transported from the Philadelphia, Marcus Hook, Toledo, and Eagle Point refineries, particularly during the term of the pipelines and terminals storage and throughput agreement with Sunoco R&M. For further information on this agreement, see Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations-Agreements with Sunoco R&M and Sunoco, Inc.” For the year ended December 31, 2004, Sunoco R&M accounted for approximately 51 percent of the Partnership’s total revenues.

 

Eastern Pipeline System

 

Nearly all of the Eastern Pipeline System is directly linked to Sunoco R&M’s refineries. Sunoco R&M constructed or acquired these assets as the most cost-effective means to access raw materials and distribute refined products. Generally, pipelines are the lowest cost method for long-haul, overland movement of refined products. Therefore, the most significant competitors for large volume shipments in the area served by the Eastern Pipeline System are other pipelines. Management of the Partnership believes that high capital requirements, environmental considerations, and the difficulty in acquiring rights-of-way and related permits make it difficult for other companies to build competing pipelines in areas served by the Partnership’s pipelines. As a result, competing pipelines are likely to be built only in those cases in which strong market demand and attractive tariff rates support additional capacity in an area.

 

Although it is unlikely that a pipeline system comparable in size and scope to the Eastern Pipeline System will be built in the foreseeable future, new pipelines (including pipeline segments that connect with existing pipeline systems) could be built to effectively compete with it in particular locations.

 

In addition, the Partnership, including its interests in corporate joint ventures, faces competition from trucks that deliver refined products in a number of areas that it serves. While their costs may not be competitive for longer hauls or large volume shipments, trucks compete effectively for incremental and marginal volume in many areas that are served. The availability of truck transportation places a significant competitive constraint on the Partnership’s ability to increase tariff rates.

 

Terminal Facilities

 

Historically, except for the Nederland Terminal, essentially all of the throughput at the Terminal Facilities segment has come from Sunoco R&M. Under the terms of the pipelines and terminals storage and throughput agreement and other agreements, the Partnership will continue to receive a significant portion of the throughput at these facilities from Sunoco R&M.

 

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The 35 inland refined product terminals compete with other independent terminals regarding price, versatility, and services provided. The competition primarily comes from integrated petroleum companies, refining and marketing companies, independent terminal companies, and distribution companies with marketing and trading activities.

 

The primary competitors for the Nederland Terminal are its refinery customers’ docks and other terminal facilities, located in the Beaumont, Texas area.

 

The Inkster Terminal’s primary competition comes from other nearby facilities located in Michigan and Windsor, Canada.

 

Western Pipeline System

 

The Western Pipeline System, including the equity interest in West Texas Gulf pipeline, faces competition from a number of major oil companies and smaller entities. Competition among common carrier pipelines is based primarily on transportation charges, access to producing areas, and demand for the crude oil by end users. Management of the Partnership believes that high capital costs make it unlikely that other companies will build new competing crude oil pipeline systems in areas served by the Western Pipeline System. Crude oil purchasing and marketing competitive factors include price and contract flexibility, quantity and quality of services, and accessibility to end markets.

 

Partnership’s Option to Purchase Pipelines from Sunoco

 

Sunoco has transferred to the Partnership most of its pipeline, terminalling, storage, and related assets that support Sunoco R&M’s refinery operations. Sunoco has retained the assets described below:

 

    Mid-Valley Pipeline. A subsidiary of Sunoco owns a 55 percent interest in the Mid-Valley Pipeline Company (a 50 percent voting interest), which owns and operates a 1,087-mile crude oil pipeline from Longview, Texas to Samaria, Michigan. The Mid-Valley pipeline serves a number of refineries in the Midwest United States.

 

    Mesa Pipeline. A subsidiary of Sunoco owns an undivided 6 percent interest in the Mesa pipeline, an 80-mile crude oil pipeline from Midland, Texas to Colorado City, Texas. Mesa Pipeline connects to West Texas Gulf’s pipeline, which supplies crude oil to Mid-Valley.

 

    Inland Pipeline. A subsidiary of Sunoco owns a 10 percent interest in Inland Corporation, which owns and operates a 611-mile refined products pipeline from Lima and Toledo, Ohio to Canton, Cleveland, Columbus, and Dayton, Ohio. This pipeline transports refined products for Sunoco R&M from its Toledo, Ohio refinery and for the other owners.

 

Sunoco has granted the Partnership a ten-year option, which expires in 2012, to purchase its interest in any of the preceding assets for fair market value at the date of purchase. Sunoco’s interests in these assets are subject to agreements with the other interest owners that include, among other things, consent requirements and rights of first refusal that may be triggered upon certain transfers. The exercise of the option with respect to any of these assets is subject to the terms and conditions of those agreements, which may or may not require consents or trigger rights of first refusal, depending on the facts and circumstances existing at the time of the option exercise. The Partnership has no current intention to purchase the retained assets noted above.

 

Sunoco has also granted the Partnership a ten-year option, which expires in 2012, to purchase an idled 370-mile 6-inch refined product pipeline from Icedale, Pennsylvania to Cleveland, Ohio for fair market value at the date of purchase. The Partnership has no current intention to purchase this pipeline.

 

Both of the ten-year option agreements described above are contained in the Omnibus Agreement that was entered into with Sunoco, Sunoco R&M and the general partner. See Item 7. “Management’s Discussion and

 

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Analysis of Financial Condition and Results of Operations—Agreements with Sunoco R&M and Sunoco, Inc.” In accordance with this agreement, if the Partnership decides to exercise the option to purchase any of the assets described above, written notice must be provided to Sunoco setting forth the fair market value the Partnership proposes to pay for the asset. If Sunoco does not agree with the proposed fair market value, the Partnership and Sunoco will appoint a mutually agreed-upon, nationally recognized investment banking firm to determine the fair market value of the asset. Once the investment bank submits its valuation of the asset, the Partnership will have the right, but not the obligation, to purchase the asset at the price determined by the investment banking firm.

 

Safety Regulation

 

A majority of the Partnership’s pipelines are subject to United States Department of Transportation (“DOT”) regulations under the Hazardous Liquid Pipeline Safety Act of 1979 (“HLPSA”), and to regulation under comparable state statutes relating to the design, installation, testing, construction, operation, replacement and management of pipeline facilities. In addition, the Partnership must permit access to and copying of records and must prepare certain reports and provide information required by the Secretary of Transportation.

 

New DOT regulations, adopted in December 2000, require operators of hazardous liquid interstate pipelines to develop and follow a program to assess the integrity of all pipeline segments that could affect designated “high consequence areas”, including high population areas, drinking water and ecological resource areas that are unusually sensitive to environmental damage from a pipeline release, and commercially navigable waterways. The Partnership has prepared its own written Risk Based Integrity Management Program, identified the line segments that could impact high consequence areas and developed Baseline Assessment Plans. Management has completed the assessment of the highest risk 50 percent of line segments as of September 30, 2004, and expects that it will complete the full assessment of the remaining segments by March 31, 2008, the timeframe prescribed by the regulations.

 

The Pipeline Safety Improvement Act of 2002, effective December 17, 2002, mandates, among other things, the delivery to the DOT of data that can be used in a national pipeline mapping system, the implementation of operator examinations and other qualification programs, periodic pipeline safety inspections, and increased civil penalties for violators. It also includes whistleblower protection provisions for employees who reveal safety violations or operational flaws.

 

Management of the Partnership believes that its pipeline operations are in substantial compliance with applicable DOT regulations and comparable state requirements. However, an increase in expenditures may be needed in the future to comply with higher industry and regulatory safety standards. Such expenditures cannot be estimated accurately at this time, but management of the Partnership does not believe they would likely have a material adverse effect relative to its financial position.

 

Employee Safety

 

The Partnership is subject to the requirements of the United States Federal Occupational Safety and Health Act (“OSHA”) and comparable state statutes that regulate worker health and safety. Management believes the Partnership is in substantial compliance with Federal OSHA requirements and comparable state statutes, including general industry standards, recordkeeping requirements and monitoring of occupational exposure to hazardous substances.

 

Environmental Regulation

 

General

 

The Partnership’s operations are subject to complex federal, state, and local laws and regulations relating to the protection of health and the environment, including laws and regulations which govern the handling and release of crude oil and other liquid hydrocarbon materials, some of which are discussed below. Violations of

 

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environmental laws or regulations can result in the imposition of significant administrative, civil and criminal fines and penalties and, in some instances, injunctions banning or delaying certain activities. Management of the Partnership believes it is in substantial compliance with applicable environmental laws and regulations. However, these laws and regulations are subject to frequent change at the federal, state and local levels, and the clear trend is to place increasingly stringent limitations on activities that may affect the environment.

 

There are also risks of accidental releases into the environment associated with the Partnership’s operations, such as releases of crude oil or hazardous substances from its pipelines or storage facilities. To the extent not insured, such accidental releases could subject the Partnership to substantial liabilities arising from environmental cleanup and restoration costs, claims made by neighboring landowners and other third parties for personal injury and property damage, and fines or penalties for any related violations of environmental laws or regulations.

 

In connection with the February 2002 IPO, and the contribution of pipeline and terminalling assets to the Partnership by affiliates of Sunoco, Inc., Sunoco agreed to indemnify the Partnership for 100 percent of all losses from environmental liabilities related to the transferred assets arising prior to, and asserted within 21 years of, February 8, 2002. There is no monetary cap on this indemnification from Sunoco. Sunoco’s share of liability for claims asserted thereafter will decrease by 10 percent each year through the thirtieth year following the February 8, 2002 date. Any remediation liabilities not covered by this indemnity will be the Partnership’s responsibility. The Partnership has agreed to indemnify Sunoco, Inc. and its affiliates for events and conditions associated with the operation of the transferred assets occurring after February 8, 2002, and for environmental and toxic tort liabilities related to these assets to the extent Sunoco, Inc. is not required to indemnify the Partnership. Total future costs for environmental remediation activities will depend upon, among other things the extent of impact at each site, the timing and nature of required remedial actions, the technology available, and the determination of the Partnership’s liability at multi-party sites. As of December 31, 2004, all material environmental liabilities incurred by, and known to, the Partnership have been either covered by the environmental indemnification or reserved for by the Partnership within its financial statements.

 

Air Emissions

 

The Partnership’s operations are subject to the Clean Air Act, as amended, and comparable state and local statutes. The Partnership will be required to incur certain capital expenditures in the next several years for air pollution control equipment in connection with maintaining or obtaining permits and approvals addressing air emission related issues. Although no assurances can be given, management of the Partnership believes implementation of the 1990 Clean Air Act Amendments will not have a material adverse effect on its financial condition or results of operations.

 

The Partnership’s customers, including Sunoco R&M, are also subject to, and affected by, environmental regulations. As a result of these regulations, Sunoco R&M could be required to make significant capital expenditures, operate these refineries at reduced levels, and pay significant penalties. It is uncertain what Sunoco, Inc.’s or Sunoco R&M’s responses to these emerging issues will be. Those responses could reduce Sunoco R&M’s obligations under the pipelines and terminals storage and throughput agreement, thereby reducing the Partnership’s throughput in its pipelines and terminals, cash flow, and ability to make distributions or satisfy its debt obligations.

 

Hazardous Substances and Waste

 

In the course of ordinary operations, the Partnership may generate waste that falls within the Comprehensive Environmental Response, Compensation, and Liability Act’s, referred to as CERCLA and also known as Superfund, definition of a “hazardous substance” and, as a result, may be jointly and severally liable under CERCLA for all or part of the costs required to clean up sites at which these hazardous substances have been released into the environment. Costs for any such remedial actions, as well as any related claims, could have a

 

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material adverse effect on the Partnership’s maintenance capital expenditures and operating expenses to the extent not all are covered by the indemnity from Sunoco. For more information, please see “Environmental Remediation”.

 

The Partnership also generates solid wastes, including hazardous wastes that are subject to the requirements of the Federal Resource Conservation and Recovery Act, referred to as RCRA, and comparable state statutes. The Partnership is not currently required to comply with a substantial portion of the RCRA requirements because its operations generate minimal quantities of hazardous wastes. However, it is possible that additional wastes, which could include wastes currently generated during the Partnership’s operating activities, will in the future be designated as “hazardous wastes.” Hazardous wastes are subject to more rigorous and costly disposal requirements than are non-hazardous wastes. Any changes in the regulations could have a material adverse effect on the Partnership’s maintenance capital expenditures and operating expenses.

 

The Partnership currently owns or leases, and the Partnership’s predecessor has in the past owned or leased, properties where hydrocarbons are being or have been handled for many years. These properties and wastes disposed thereon may be subject to CERCLA, RCRA, and analogous state laws. Under these laws, the Partnership could be required to remove or remediate previously disposed wastes (including wastes disposed of or released by prior owners or operators), to clean up contaminated property (including contaminated groundwater), or to perform remedial operations to prevent future contamination.

 

The Partnership has not been identified by any state or federal agency as a potentially responsible party in connection with the transport and/or disposal of any waste products to third party disposal sites.

 

Water

 

The Partnership’s operations can result in the discharge of regulated substances, including crude oil. The Federal Water Pollution Control Act of 1972, also known as the Clean Water Act, and analogous state laws impose restrictions and strict controls regarding the discharge of regulated substances into state waters or waters of the United States.

 

The Oil Pollution Act subjects owners of covered facilities to strict, joint, and potentially unlimited liability for removal costs and other consequences of a release of oil, where the release is into navigable waters, along shorelines or in the exclusive economic zone of the United States. Spill prevention control and countermeasure requirements of the Clean Water Act and some state laws require diking and similar structures to help prevent the impact on navigable waters in the event of a release. The Office of Pipeline Safety of the DOT, the EPA, or various state regulatory agencies have approved the Partnership’s oil spill emergency response plans, and management of the Partnership believes it is in substantial compliance with these laws.

 

In addition, some states maintain groundwater protection programs that require permits for discharges or operations that may impact groundwater conditions. Management of the Partnership believes that compliance with existing permits and compliance with foreseeable new permit requirements will not have a material adverse effect on its financial condition or results of operations.

 

Environmental Remediation

 

Contamination resulting from releases of refined products and crude oil is not unusual within the petroleum pipeline industry. Historic releases along the Partnership’s pipelines, gathering systems, and terminals as a result of past operations have resulted in impacts to the environment, including soils and groundwater. Site conditions, including soils and groundwater, are being evaluated at a number of properties where operations may have resulted in releases of hydrocarbons and other wastes. Sunoco has agreed to indemnify the Partnership from environmental and toxic tort liabilities related to the assets transferred to the extent such liabilities exist or arise from operation of these assets prior to the closing of the February 2002 IPO and are asserted within 30 years after

 

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the closing of the IPO. This indemnity will cover the costs associated with performance of the assessment, monitoring, and remediation programs, as well as any related claims and penalties. See “Environmental Regulation—General.”

 

The Partnership has experienced several petroleum releases for which it is not covered by an indemnity from Sunoco, Inc., and for which it is responsible for necessary assessment, remediation, and/or monitoring activities. Management of the Partnership estimates that the total aggregate cost of performing the currently anticipated assessment, monitoring, and remediation activities at these sites is not material in relation to its financial position at December 31, 2004. The Partnership has implemented an extensive inspection program to prevent releases of refined products or crude oil into the environment from its pipelines, gathering systems, and terminals. Any damages and liabilities incurred due to future environmental releases from the Partnership’s assets have the potential to substantially affect its business.

 

Rate Regulation

 

General Interstate Regulation. Interstate common carrier pipeline operations are subject to rate regulation by the FERC under the Interstate Commerce Act, the Energy Policy Act of 1992, and rules and orders promulgated pursuant thereto. The Interstate Commerce Act requires that tariff rates for petroleum pipelines be “just and reasonable” and not unduly discriminatory. This statute also permits interested persons to challenge proposed new or changed rates and authorizes the FERC to suspend the effectiveness of such rates for up to seven months and to investigate such rates. If, upon completion of an investigation, the FERC finds that the new or changed rate is unlawful, it is authorized to require the carrier to refund revenues in excess of the prior tariff during the term of the investigation. The FERC also may investigate, upon complaint or on its own motion, rates that are already in effect and may order a carrier to change its rates prospectively. Upon an appropriate showing, a shipper may obtain reparations for damages sustained for a period of up to two years prior to the filing of a complaint.

 

The FERC generally has not investigated interstate rates on its own initiative when those rates, like the Partnership’s, have not been the subject of a protest or a complaint by a shipper. However, the FERC could investigate the Partnership’s rates at the urging of a third party if the third party is either a current shipper or has a substantial economic interest in the tariff rate level. Although no assurance can be given that the tariffs charged by the Partnership ultimately will be upheld if challenged, management believes that the tariffs now in effect for the Partnership’s pipelines are within the maximum rates allowed under current FERC guidelines.

 

Sunoco R&M and its subsidiaries are the only current shippers on many of the pipelines. Sunoco R&M has agreed not to challenge, cause others to challenge, or assist others in challenging, the tariff rates for the term of the pipelines and terminals storage and throughput agreement. Since most of the pipelines are common carrier pipelines, the Partnership may be required to accept new shippers who wish to transport on the pipelines. It is possible that any new shippers, current shippers, or other interested parties, may decide to challenge the tariff rates. If any rate challenge or challenges were successful, revenues, cash flows, and the cash available for distribution could be materially reduced.

 

Intrastate Regulation. Some of the Partnership’s pipeline operations are subject to regulation by the Texas Railroad Commission, the PA PUC, the Ohio Public Utility Commission, the Oklahoma Corporation Commission and the Montana Public Service Commission. The applicable state statutes require that pipeline rates be nondiscriminatory and provide no more than a fair return on the aggregate value of the pipeline property used to render services. State commissions generally have not been aggressive in regulating common carrier pipelines or investigating rates or practices of petroleum pipelines in the absence of shipper complaints. Complaints to state agencies have been infrequent and are usually resolved informally. Although management cannot be certain that the Partnership’s intrastate rates ultimately would be upheld if challenged, it believes that, given this history, the tariffs now in effect are not likely to be challenged or, if challenged, are not likely to be ordered to be reduced.

 

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Title to Properties

 

Substantially all of the Partnership’s pipelines were constructed on rights-of-way granted by the apparent record owners of the property and in some instances these rights-of-way are revocable at the election of the grantor. Several rights-of-way for the pipelines and other real property assets are shared with other pipelines and other assets owned by affiliates of Sunoco, Inc. and by third parties. In many instances, lands over which rights-of-way have been obtained are subject to prior liens that have not been subordinated to the right-of-way grants. The Partnership has obtained permits from public authorities to cross over or under, or to lay facilities in or along, watercourses, county roads, municipal streets, and state highways and, in some instances, these permits are revocable at the election of the grantor. The Partnership has also obtained permits from railroad companies to cross over or under lands or rights-of-way, many of which are also revocable at the grantor’s election. In some cases, property for pipeline purposes was purchased in fee. In some states and under some circumstances, the Partnership has the right of eminent domain to acquire rights-of-way and lands necessary for the common carrier pipelines. The previous owners of the applicable pipelines may not have commenced or concluded eminent domain proceedings for some rights-of-way.

 

Some of the leases, easements, rights-of-way, permits, and licenses transferred to the Partnership upon the closing of the February 2002 IPO required the consent of the grantor to transfer these rights, which in some instances is a governmental entity. The Partnership has obtained or is in the process of obtaining third-party consents, permits, and authorizations sufficient for the transfer of the assets necessary to operate the business in all material respects. In management’s opinion, with respect to any consents, permits, or authorizations that have not been obtained, the failure to obtain them will not have a material adverse effect on the operation of the business.

 

The Partnership has satisfactory title to all of the assets contributed to it in connection with the February 2002 IPO, or is entitled to indemnification from Sunoco, Inc. under the Omnibus Agreement for title defects to these assets and for failures to obtain certain consents and permits necessary to conduct its business that arise within ten years after the closing of the February 2002 IPO. Record title to some of the assets may continue to be held by affiliates of Sunoco, Inc. until the Partnership has made the appropriate filings in the jurisdictions in which such assets are located and obtained any consents and approvals that were not obtained prior to the closing of the February 2002 IPO. Although title to these properties is subject to encumbrances in some cases, such as customary interests generally retained in connection with acquisition of real property, liens that can be imposed in some jurisdictions for government-initiated action to clean up environmental contamination, liens for current taxes and other burdens, and easements, restrictions, and other encumbrances to which the underlying properties were subject at the time of acquisition by the predecessor or the Partnership, in management’s opinion, none of these burdens should materially detract from the value of these properties or from the Partnership’s interest in these properties or should materially interfere with their use in the operation of its business. Further, the Partnership has satisfactory title to all assets acquired subsequent to the February 2002 IPO.

 

Employees

 

To carry out the Partnership’s operations, the general partner and its affiliates employed approximately 1,150 people at December 31, 2004 who provide direct support to the operations. Labor unions or associations represent approximately 650 of these employees at December 31, 2004. The general partner considers its employee relations to be good. The Partnership has no employees.

 

(d) Financial Information about Geographical Areas

 

The Partnership has no significant amount of revenue or segment profit or loss attributable to international activities.

 

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(e) Available Information

 

The Partnership makes available, free of charge on its website, www.sunocologistics.com, all materials that it files electronically with the Securities Exchange Commission, including its annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to those reports as soon as reasonably practicable after such materials are electronically filed with, or furnished to, the SEC.

 

ITEM 2. PROPERTIES

 

See Item 1.(c) for a description of the locations and general character of the Partnership’s material properties.

 

ITEM 3. LEGAL PROCEEDINGS

 

There are certain legal and administrative proceedings arising prior to the February 2002 IPO pending against the Partnership’s Sunoco-affiliated predecessors and the Partnership (as successor to certain liabilities of those predecessors). Although the ultimate outcome of these proceedings cannot be ascertained at this time, it is reasonably possible that some of them may be resolved unfavorably. Sunoco, Inc. has agreed to indemnify the Partnership for any losses it may suffer as a result of these pending legal actions.

 

There are certain other pending legal proceedings related to matters arising after the February 2002 IPO that are not indemnified by Sunoco, Inc. Management believes that any liabilities that may arise from these legal proceedings will not be material to the Partnership’s financial position at December 31, 2004.

 

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITYHOLDERS

 

No matters were submitted to a vote of the securityholders, through solicitation of proxies or otherwise, during fiscal 2004.

 

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PART II

 

ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED SECURITYHOLDER MATTERS AND PURCHASES OF EQUITY SECURITIES

 

The Partnership’s common units were listed on the New York Stock Exchange under the symbol “SXL” beginning on February 5, 2002. Prior to February 5, 2002, the Partnership’s equity securities were not traded on any public trading market. At the close of business on February 8, 2005, there were 74 holders of record of the Partnership’s common units. These holders of record included the general partner with 3,455,095 common units registered in its name, and Cede & Co. with 9,237,543 common units registered to it.

 

The high and low closing sales price ranges (composite transactions) and distributions declared by quarter for 2003 and 2004 were as follows:

 

     2003

   2004

     Unit Price

   Declared
Distributions(1)


   Unit Price

   Declared
Distributions(1)


     High

   Low

      High

   Low

  

1st

   $ 25.95    $ 22.85    $ 0.4875    $ 42.20    $ 34.48    $ 0.5700

2nd

   $ 30.75    $ 26.20    $ 0.5000    $ 39.75    $ 31.47    $ 0.5875

3rd

   $ 32.45    $ 28.35    $ 0.5125    $ 39.36    $ 36.00    $ 0.6125

4th

   $ 37.11    $ 30.80    $ 0.5500    $ 43.05    $ 38.75    $ 0.6250

(1) Distributions were declared and paid within 45 days following the close of each quarter.

 

The Partnership distributes all cash on hand within 45 days after the end of each quarter, less reserves established by the general partner in its discretion. This is defined as “available cash” in the partnership agreement. The general partner has broad discretion to establish cash reserves that it determines are necessary or appropriate to properly conduct the Partnership’s business. The Partnership will make minimum quarterly distributions of $0.45 per common unit, to the extent there is sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to the general partner.

 

The Partnership also had 11,383,639 subordinated units issued as of December 31, 2004, all of which are held by the general partner and for which there is no established public trading market. During the subordination period the Partnership will, in general, pay cash distributions each quarter in the following manner:

 

    First, 98 percent to the holders of common units and 2 percent to the general partner, until each common unit has received a minimum quarterly distribution of $0.45, plus any arrearages from prior quarters;

 

    Second, 98 percent to the holders of subordinated units and 2 percent to the general partner, until each subordinated unit has received a minimum quarterly distribution of $0.45; and

 

    Thereafter, in the manner described in the table below.

 

The subordination period is generally defined as the period that ends on the first day of any quarter beginning after December 31, 2006 if (1) the Partnership has distributed at least the minimum quarterly distribution on all outstanding units with respect to each of the immediately preceding three consecutive, non-overlapping four quarter periods; and (2) the adjusted operating surplus, as defined in the partnership agreement, during such periods equals or exceeds the amount that would have been sufficient to enable the Partnership to distribute the minimum quarterly distribution on all outstanding units on a fully diluted basis and the related distribution on the 2 percent general partner interest during those periods. If the subordination period ends, the rights of the holders of subordinated units will no longer be subordinated to the rights of the holders of common units and the subordinated units may be converted into common units. The Partnership has met the minimum quarterly distribution requirements on all outstanding units for each of the four quarter periods in 2002, 2003 and 2004. In addition, one-quarter of the subordinated units may convert to common units on a one-for-one basis

 

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after December 31, 2004, and one-quarter of the subordinated units may convert to common units on a one-for-one basis after December 31, 2005, if the Partnership meets the tests set forth in the partnership agreement. On February 15, 2005, 2,845,910 subordinated units, equal to one-quarter of the originally issued subordinated units held by the general partner, were converted to common units as the Partnership met the tests set forth in the partnership agreement.

 

After the subordination period, the Partnership will, in general, pay cash distributions each quarter in the following manner:

 

    First, 98 percent to all unitholders, pro rata, and 2 percent to the general partner, until the Partnership distributes for each outstanding unit an amount equal to the minimum quarterly distribution for that quarter; and

 

    Thereafter, as described in the paragraph and table below.

 

As presented in the table below, if cash distributions exceed $0.50 per unit in a quarter, the general partner will receive increasing percentages, up to 50 percent, of the cash distributed in excess of that amount. These distributions are referred to as “incentive distributions”. The amounts shown in the table below under “Percentage of Distributions” are the percentage interests of the general partner and the unitholders in any available cash from operating surplus that is distributed up to and including the corresponding amount in the column “Quarterly Cash Distribution Amount per Unit,” until the available cash that is distributed reaches the next target distribution level, if any. The percentage interests shown for the unitholders and the general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution.

 

Quarterly Cash Distribution Amount per Unit


   Percentage of Distributions

 
   Unitholders

    General Partner

 

Up to minimum quarterly distribution ($0.45 per Unit)

   98 %   2 %

Above $0.45 per Unit up to $0.50 per Unit

   98 %   2 %

Above $0.50 per Unit up to $0.575 per Unit

   85 %   15 %

Above $0.575 per Unit up to $0.70 per Unit

   75 %   25 %

Above $0.70 per Unit

   50 %   50 %

 

There is no guarantee that the Partnership will pay the minimum quarterly distribution on the common units in any quarter, and the Partnership will be prohibited from making any distributions to unitholders if it would cause an event of default, or an event of default is existing, under the credit facility or the senior notes (Please see Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources”).

 

For equity compensation plan information, see Item 12. “Security Ownership of Certain Beneficial Owners and Management and Related Securityholder Information”.

 

ITEM 6. SELECTED FINANCIAL DATA

 

On February 8, 2002, the Partnership completed an IPO and related transactions whereby it became the successor to Sunoco Logistics (Predecessor) (“Predecessor”), which consisted of a substantial portion of the wholly-owned logistics operations of Sunoco, Inc. and its subsidiaries. The selected financial and operating data presented is derived from the audited financial statements of Sunoco Logistics Partners L.P., which reflect the Predecessor for 2000 and 2001, the Partnership and Predecessor for 2002, and the Partnership for 2003 and 2004.

 

For the periods presented, Sunoco R&M was the primary or exclusive user of the refined product terminals, the Fort Mifflin Terminal Complex, and the Marcus Hook Tank Farm. Prior to January 1, 2002, most of the terminalling and throughput services provided by Sunoco Logistics (Predecessor) for Sunoco R&M’s refining

 

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and marketing operations were at fees that enabled the recovery of costs, but not to generate any operating income. Accordingly, historical earnings before interest expense, income tax expense, and depreciation and amortization (“EBITDA”) for those assets was equal to their depreciation and amortization. Sunoco Logistics Partners L.P. began charging Sunoco R&M fees for these services that are comparable to those charged in arm’s length, third-party transactions, generally effective January 1, 2002, using the terms included in a pipelines and terminals storage and throughput agreement entered into at the closing of the February 2002 IPO.

 

Maintenance capital expenditures are capital expenditures made to replace partially or fully depreciated assets in order to maintain the existing operating capacity of the assets and to extend their useful lives. Expansion capital expenditures are capital expenditures made to expand the existing operating capacity of the assets, whether through construction or acquisition. The Partnership treats repair and maintenance expenditures that do not extend the useful life of existing assets as operating expenses as incurred.

 

Throughput is the total number of barrels per day (“bpd”) transported on a pipeline system or through a terminal. Total shipments represent the total average daily pipeline throughput multiplied by the number of miles of pipeline through which each barrel has been shipped. Management of the Partnership believes that total shipments is a better performance indicator for the Eastern Pipeline System than throughput as certain refined product pipelines, including interrefinery and transfer pipelines, transport large volumes over short distances and generate minimal revenues.

 

The following table should be read together with, and is qualified in its entirety by reference to, the financial statements and the accompanying notes of Sunoco Logistics Partners L.P. included in Item 8. “Financial Statements and Supplementary Data”. The table also should be read together with Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations”.

 

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SUNOCO LOGISTICS PARTNERS L.P.

 

     Predecessor

    Partnership
and
Predecessor


    Partnership

 
     Year Ended December 31,

 
     2000

    2001

    2002(1)

    2003(2)

    2004(3)

 
     (in thousands, except per unit and operating data)  

Income Statement Data:

                                        

Revenues:

                                        

Sales and other operating revenue:

                                        

Affiliates

   $ 1,301,079     $ 1,067,182     $ 1,147,721     $ 1,383,090     $ 1,751,612  

Unaffiliated customers

     507,532       545,822       676,307       1,274,383       1,699,673  

Other income(4)

     5,574       4,774       6,904       16,730       13,932  
    


 


 


 


 


Total revenues

     1,814,185       1,617,778       1,830,932       2,674,203       3,465,217  
    


 


 


 


 


Costs and expenses:

                                        

Cost of products sold and operating expenses

     1,699,541       1,503,156       1,690,896       2,519,160       3,307,480  

Depreciation and amortization

     20,654       25,325       31,334       27,157       31,933  

Selling, general and administrative expenses

     34,683       35,956       43,073       48,412       48,449  
    


 


 


 


 


Total costs and expenses

     1,754,878       1,564,437       1,765,303       2,594,729       3,387,862  
    


 


 


 


 


Operating income

     59,307       53,341       65,629       79,474       77,355  

Net interest cost and debt expense

     10,304       10,980       17,299       20,040       20,324  
    


 


 


 


 


Income before income tax expense

     49,003       42,361       48,330       59,434       57,031  

Income tax expense

     18,483       15,594       1,555       —         —    
    


 


 


 


 


Net Income

   $ 30,520     $ 26,767     $ 46,775     $ 59,434     $ 57,031  
    


 


 


 


 


Net Income per limited partner unit:

                                        

Basic

                   $ 1.87 (5)   $ 2.55     $ 2.29  
                    


 


 


Diluted

                   $ 1.86 (5)   $ 2.53     $ 2.27  
                    


 


 


Cash distributions per unit to limited partners:(6)

                                        

Paid

                   $ 1.16     $ 1.9875     $ 2.32  
                    


 


 


Declared

                   $ 1.6475     $ 2.05     $ 2.395  
                    


 


 


Cash Flow Data:

                                        

Net cash provided by operating activities

   $ 79,116     $ 27,238     $ 2,211     $ 97,212     $ 106,622  

Net cash used in investing activities

   $ (77,292 )   $ (73,079 )   $ (85,273 )   $ (39,008 )   $ (95,583 )

Net cash provided by/(used in) financing activities

   $ (1,824 )   $ 45,841     $ 116,902     $ (41,963 )   $ (8,460 )

Capital expenditures:

                                        

Maintenance

   $ 39,067     $ 53,628     $ 27,934     $ 30,850     $ 30,829  

Expansion

     18,854       19,055       77,439 (1)     10,226 (2)     64,754 (3)
    


 


 


 


 


Total capital expenditures

   $ 57,921     $ 72,683     $ 105,373 (1)   $ 41,076 (2)   $ 95,583 (3)
    


 


 


 


 


EBITDA(7)

   $ 79,961     $ 78,666     $ 96,963     $ 106,631     $ 109,288  

Distributable Cash Flow(7)

   $ 30,590     $ 14,058     $ 55,415     $ 61,055     $ 65,182  

Balance Sheet Data (at period end):

                                        

Net properties, plants and equipment

   $ 518,605     $ 566,359     $ 573,514     $ 583,164     $ 647,200  

Total assets

   $ 845,956     $ 789,201     $ 1,093,880     $ 1,181,006     $ 1,368,786  

Total debt

   $ 190,043     $ 144,781     $ 317,445     $ 313,136     $ 313,305  

Total Partners’ Capital/ Net parent investment

   $ 157,023     $ 274,893     $ 383,033     $ 403,758     $ 460,594  

Operating Data (bpd):

                                        

Eastern Pipeline System total shipments (in thousands of barrel miles per day)(8)

     54,911       55,198       56,768       55,324       59,173  

Terminal Facilities throughput (bpd)

     1,281,231       1,156,927       1,182,784       1,204,394       1,464,254  

Western Pipeline System throughput(8) (bpd)

     295,991       287,237       286,912       304,471       298,797  

Crude oil purchases at wellhead (bpd)

     172,839       174,182       189,277       193,176       186,827  

 

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(1) On November 15, 2002, the Partnership acquired a company whose assets included equity interests in three products pipeline companies, consisting of a 31.5 percent interest in Wolverine Pipe Line Company, a 9.2 percent interest in West Shore Pipe Line Company, and a 14.0 percent interest in Yellowstone Pipe Line Company for $54.0 million. On November 15, 2002, the Partnership also acquired a 43.8 percent equity interest in West Texas Gulf Pipe Line Company for $10.6 million. The aggregate purchase price for these acquisitions has been included within the 2002 expansion capital expenditures. The equity income from these acquisitions has been included in the Partnership’s statements of income from the dates of their acquisition.
(2) On September 30, 2003, the Partnership acquired an additional 3.1 percent ownership interest in West Shore for $3.7 million, increasing its overall ownership percentage to 12.3 percent. The purchase price for this acquisition has been included within the 2003 expansion capital expenditures, and the equity income has been included in the Partnership’s statements of income from the date of acquisition.
(3) During the year ended December 31, 2004, the Partnership completed the following acquisitions: the Eagle Point logistics assets, which were purchased for $20.0 million on March 30, 2004; two refined product terminals located in Baltimore, Maryland and Manassas, Virginia, which were purchased for $12.0 million on April 28, 2004; an additional 33.3 percent undivided interest in the Harbor pipeline, which was acquired on June 28, 2004 for $7.3 million; and a refined product terminal located in Columbus, Ohio, which was purchased for $8.0 million on November 30, 2004. The aggregate purchase price for these acquisitions has been included within the 2004 expansion capital expenditures, and their results of operations have been included from their dates of acquisition.
(4) Includes equity income from the investments in the following joint ventures: 9.4 percent in Explorer Pipeline Company and, from November 15, 2002, 31.5 percent in Wolverine Pipe Line Company, 9.2 percent in West Shore Pipe Line Company, 14.0 percent in Yellowstone Pipe Line Company, and 43.8 percent in West Texas Gulf Pipe Line Company. On September 30, 2003, the Partnership acquired an additional 3.1 percent ownership interest in West Shore, increasing the Partnership’s ownership percentage to 12.3 percent. Equity income from this investment has been included at this increased ownership percentage from this date forward.
(5) Based on the portion of net income for 2002 applicable to the period from February 8, 2002 (the date of the IPO) through December 31, 2002, after deduction of the general partner’s interest in net income. Net income for the period from January 1, 2002 to February 7, 2002 totaled $3.4 million.
(6) Cash distributions paid per unit to limited partners include payments made per unit during the period stated. Cash distributions declared per unit to limited partners include distributions declared per unit related to the quarters within the period stated. Declared distributions were paid within 45 days following the close of each quarter. The distributions for 2002 include a $0.26 per limited partner unit distribution for the first quarter, which represents the pro-rata portion of the $0.45 minimum quarterly distribution for the 52-day period from the date of the IPO, February 8, 2002, through March 31, 2002.
(7) EBITDA and distributable cash flow provides additional information for evaluating the Partnership’s ability to make distributions to its unitholders and the general partner. The following table reconciles the difference between operating income, as determined under United States generally accepted accounting principles, and EBITDA and distributable cash flow (in thousands):

 

     Year Ended December 31,

 
     2000

    2001

    2002

    2003

    2004

 

Operating income

   $ 59,307     $ 53,341     $ 65,629     $ 79,474     $ 77,355  

Depreciation and amortization

     20,654       25,325       31,334       27,157       31,933  
    


 


 


 


 


EBITDA

     79,961       78,666       96,963       106,631       109,288  

Interest expense, net

     (10,304 )     (10,980 )     (17,299 )     (20,040 )     (20,324 )

Maintenance capital expenditures

     (39,067 )     (53,628 )     (27,934 )     (30,850 )     (30,829 )

Sunoco reimbursements

     —         —         3,685       5,314       7,047  
    


 


 


 


 


Distributable cash flow

   $ 30,590     $ 14,058     $ 55,415     $ 61,055     $ 65,182  
    


 


 


 


 


 

Management of the Partnership believes EBITDA and distributable cash flow information enhances an investor’s understanding of a business’s ability to generate cash for payment of distributions and other purposes. In addition, EBITDA is also used as a measure in the Partnership’s $250 million revolving credit facility in determining its compliance with certain covenants. However, there may be contractual, legal, economic or other reasons which may prevent the Partnership from satisfying principal and interest obligations with respect to indebtedness and may require the Partnership to allocate funds for other purposes. EBITDA and distributable cash flow do not represent and should not be considered alternatives to net income, operating income or cash flows from operating activities as determined under United States generally accepted accounting principles and may not be comparable to other similarly titled measures of other businesses.

(8) Excludes amounts attributable to the equity ownership interests in corporate joint ventures.

 

 

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

 

The following discussion should be read in conjunction with the financial statements of Sunoco Logistics Partners L.P. Among other things, those financial statements include more detailed information regarding the basis of presentation for the following information.

 

Introduction

 

The Partnership is a Delaware limited partnership formed on October 15, 2001 to acquire, own, and operate, through its wholly-owned entities, refined product pipelines, terminalling and storage assets, crude oil pipelines, and crude oil acquisition and marketing assets. The Partnership’s assets are located in the Northeast, Midwest and South Central United States. Most of these assets support Sunoco R&M, a wholly-owned refining and marketing subsidiary of Sunoco, Inc.

 

General

 

The Partnership conducts its business through three segments: the Eastern Pipeline System, the Terminal Facilities, and the Western Pipeline System. The Eastern Pipeline System primarily transports refined products in the Northeast and Midwest United States largely for four of Sunoco R&M’s refineries and transports crude oil in Ohio and Michigan. This system also includes the interrefinery pipeline between Sunoco R&M’s Marcus Hook and Philadelphia refineries and ownership interests in four refined product pipeline joint ventures located in the West and Midwest United States: 9.4 percent in Explorer Pipeline Company (“Explorer”), 31.5 percent in Wolverine Pipe Line Company (“Wolverine”), 12.3 percent in West Shore Pipe Line Company (“West Shore”), and 14.0 percent in Yellowstone Pipe Line Company (“Yellowstone”). The Terminal Facilities business includes a network of 35 refined product terminals in the Northeast and Midwest United States that distribute products primarily to Sunoco R&M’s retail outlets, the Nederland marine crude oil terminal on the Texas Gulf Coast, and a liquefied petroleum gas (“LPG”) storage facility in the Midwest. The Terminal Facilities business also owns and operates refinery-related assets, including one inland and two marine crude oil terminals and related pipelines that supply all of the crude oil processed by Sunoco R&M’s Philadelphia refinery, a refined product storage terminal used by Sunoco R&M’s Marcus Hook refinery, and a ship and barge dock through which Sunoco R&M’s Eagle Point refinery receives all of its crude oil and ships certain quantities of refined product. The Western Pipeline System owns and operates crude oil trunk and gathering pipelines and purchases and markets crude oil primarily in Oklahoma and Texas for Sunoco R&M’s Tulsa, Oklahoma and Toledo, Ohio refineries and for other customers. The Western Pipeline System also has a 43.8 percent equity ownership interest in West Texas Gulf Pipe Line Company (“West Texas Gulf”), a joint venture that owns a crude oil pipeline in Texas.

 

Eastern Pipeline System

 

Revenues for the Eastern Pipeline System are generated by charging shippers tariffs for transporting refined products and crude oil through the Partnership’s pipelines. The amount of revenue generated depends on the level of these tariffs and the throughput in the pipelines. When transporting barrels, a tariff is charged based on the point of origin and the ultimate destination, even if the barrel moves through more than one pipeline segment to reach its destination. For example, on the Philadelphia, Pennsylvania to Buffalo, New York pipeline segment, there are separate tariffs depending on whether the ultimate destination from Philadelphia is Rochester, New York or Buffalo, New York.

 

The tariffs for the Partnership’s interstate common carrier pipelines are regulated by the Federal Energy Regulatory Commission (“FERC”). The rate making methodology for these pipelines is price indexing. This methodology provides for increases in tariff rates based upon changes in the producer price index. Competition, however, may constrain the tariffs charged. The Partnership also leases to Sunoco R&M, for a fixed amount

 

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escalating annually at 1.67 percent, three pipelines between Sunoco R&M’s Marcus Hook and Philadelphia refineries, as well as a pipeline from the Partnership’s Paulsboro terminal to the Philadelphia International Airport for the delivery of jet fuel.

 

The crude oil and refined product throughput in the Eastern Pipeline System’s pipelines is directly affected by the level of supply and demand for crude oil and refined products in the markets served directly or indirectly by the pipelines. Demand for gasoline in most markets peaks during the summer driving season, which extends from April to September, and declines during the fall and winter months. Demand for heating oil and other distillate fuels tends to peak during the winter heating season, and declines during the spring and summer months. The supply of crude oil to the Eastern Pipeline System depends upon the level of crude oil production in Canada, which has increased in recent years. Demand for crude oil transported to refineries for processing is driven by refining margins (the price of refined products compared to the price of crude oil and refining costs), unscheduled downtime at refineries and the amount of turnaround activity, which is when refiners shut down selected portions of the refinery for scheduled maintenance.

 

The operating income generated by the Eastern Pipeline System depends not only on the volume transported on its pipelines and the level of the tariff charged, but also on the fixed costs and, to a much lesser extent, the variable costs of operating the pipelines. Fixed costs are typically related to maintenance, insurance, control rooms, telecommunications, pipeline field and support personnel and depreciation. Variable costs, such as fuel and power costs to run pump stations along the pipelines, fluctuate with throughput.

 

Terminal Facilities

 

Revenues for the Terminal Facilities are primarily generated by charging customers fees for terminalling and throughput services. The Partnership is charging Sunoco R&M fees for these services that are comparable to those charged in arm’s-length, third-party transactions using the terms included in a pipelines and terminals storage and throughput agreement with Sunoco R&M entered into at the closing of the February 2002 initial public offering (“IPO”). Under this agreement, Sunoco R&M pays the Partnership a minimum level of revenues for terminalling refined products and crude oil and agrees to certain minimum throughputs at the Inkster Terminal, Fort Mifflin Terminal Complex, and Marcus Hook Tank Farm. (See “Agreements with Sunoco R&M and Sunoco, Inc.” and Item 13. “Certain Relationships and Related Transactions”.)

 

The Partnership generates revenue at the Nederland Terminal by charging storage and throughput fees for crude oil and other petroleum products. The absolute price level of crude oil and refined products does not directly affect terminalling and storage fees, although they are affected by the absolute levels of supply and demand for these products.

 

Western Pipeline System

 

The Western Pipeline System consists of crude oil pipelines and gathering systems as well as the crude oil acquisition and marketing operations.

 

The factors affecting the operating results of the crude oil pipelines and gathering systems are substantially similar to the factors affecting the operating results of the pipelines in the Eastern Pipeline System described above. The operating results of the crude oil acquisition and marketing operations are dependent on its ability to sell crude oil at a price in excess of the aggregate cost. Management of the Partnership believes gross margin, which is equal to sales and other operating revenue less cost of products sold and operating expenses and depreciation and amortization, is a key measure of financial performance for the Western Pipeline System.

 

The crude oil acquisition and marketing operations generate substantial revenue and cost of products sold because they reflect the sales price and cost of the significant volume of crude oil bought and sold. However, the absolute price levels for crude oil normally do not bear a relationship to gross margin, although these price levels

 

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significantly impact revenue and cost of products sold. As a result, period-to-period variations in revenue and cost of products sold are not generally meaningful in analyzing the variation in gross margin for the crude oil acquisition and marketing operations.

 

In general, crude oil is purchased at the wellhead from local producers and in bulk at major pipeline connection and marketing points. The Partnership also enters into transactions with third parties in which one grade of crude oil is exchanged for another grade that more nearly matches the delivery requirement or the preferences of customers. Bulk purchases and sales and exchange transactions are characterized by large volume and much smaller margins than are sales of crude oil purchased at the wellhead. As crude oil is purchased, the Partnership establishes a margin by selling or exchanging the crude oil for physical delivery of other crude oil to Sunoco R&M and third-party customers, such as independent refiners or major oil companies, thereby reducing exposure to price fluctuations. This margin is determined by the difference between the price of crude oil at the point of purchase and the price of crude oil at the point of sale, minus the associated costs related to acquisition and transportation. Changes in the absolute price level for crude oil do not materially impact the margin, as attempts are made to maintain positions that are substantially balanced between crude oil purchases and sales.

 

Because attempts are made to maintain balanced positions, the Partnership is able to minimize basis risk, which occurs when crude oil is purchased based on a crude oil specification that is different from the countervailing sales arrangement. Specification differences include grades or types of crude oil, variability in lease crude oil barrels produced, individual refinery demand for specific grades of crude oil, relative market prices for the different grades of crude oil, customer location, availability of transportation facilities, timing, and costs (including storage) involved in delivering crude oil to the customer. The Partnership’s policy is only to purchase crude oil for which there is a market and to structure the sales contracts so that crude oil price fluctuations do not materially affect the margin received. The Partnership does not acquire and hold any futures contracts or other derivative products for any purpose.

 

The Partnership operates the crude oil acquisition and marketing activities differently as market conditions change. During periods when there is a higher demand than supply of crude oil in the near term, the market is in backwardation, meaning that the price of crude oil in a given month exceeds the price of crude oil for delivery in subsequent months. A backwardated market has a positive impact on marketing margins because crude oil marketers can continue to purchase crude oil from producers at a fixed premium to posted prices while selling crude oil at a higher premium to such prices. In backwardated markets, crude oil is purchased and contracted for its sale as soon as possible. When the demand for crude oil is weak, the market for crude oil is often in contango, meaning that the price of crude oil in a given month is less than the price of crude oil for delivery in subsequent months. In a contango market, marketing margins are adversely impacted, as crude oil marketers are unable to capture the premium to posted prices described above. However, this unfavorable market condition can be mitigated by storing crude oil because storage owners at major trading locations can simultaneously purchase production at current prices for storage and sell at higher prices for future delivery. As a result, in a contango market, crude oil will be purchased and contracted for its delivery in future months to capture the price difference.

 

Agreements with Sunoco R&M and Sunoco, Inc.

 

The Partnership has entered into several agreements with Sunoco, Inc., Sunoco R&M, and their affiliates as described below.

 

Pipelines and Terminals Storage and Throughput Agreement

 

Under this agreement, entered into upon the closing of the February 2002 IPO, Sunoco R&M is paying the Partnership fees generally comparable to those charged by third parties to:

 

   

transport on the refined product pipelines or throughput in the inland refined product terminals existing at the time of the agreement an amount of refined products that will produce at least $77.5 million of

 

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revenue for the contract year from March 1, 2004 to February 28, 2005, escalating at 1.67 percent each March 1 for the next two contract years. In addition, Sunoco R&M will pay the Partnership to transport on those refined product pipelines or throughput in those refined product terminals an amount of refined products that will produce at least $54.3 million of revenue in the contract year commencing March 1, 2007, and at least $55.2 million of revenue in the contract year commencing March 1, 2008. Sunoco R&M will pay the published tariffs on the pipelines and contractually agreed upon fees at the terminals. Based upon the prorated minimum amount noted, Sunoco R&M has exceeded the minimum revenue amount through December 31, 2004 and management of the Partnership expects Sunoco R&M to exceed the minimum amount under the agreement for the contract year from March 1, 2004 through February 28, 2005;

 

    receive and deliver at least 130,000 bpd of refined products per year at the Marcus Hook Tank Farm for five years ending February 28, 2007. This throughput is an annual amount for the contract period from March 1 to February 28 for the term of the agreement. For the calendar year ended December 31, 2004, the Partnership received a fee of $0.1682 per barrel for the first 130,000 bpd and $0.0841 per barrel for volume in excess of 130,000 bpd. These fees escalate at the rate of 1.67 percent each January 1 for the term of the agreement. Based upon the prorated minimum throughput amount noted, Sunoco R&M has exceeded the minimum throughput amount through December 31, 2004 and management of the Partnership expects Sunoco R&M to exceed the minimum throughput amount under the agreement for the contract year from March 1, 2004 through February 28, 2005;

 

    store 975,734 barrels of LPG per contract year at the Inkster Terminal, which represents all of the LPG storage capacity at this facility. This storage is an annual amount for the contract period from April 1 to March 31 for the seven-year term of the agreement ending March 31, 2009. For the calendar year ended December 31, 2004, the Partnership received a fee of $2.117 per barrel of committed storage, a fee of $0.212 per barrel for receipts greater than 975,734 barrels per contract year and a fee of $0.212 per barrel for deliveries greater than 975,734 barrels per contract year. These fees will escalate at the rate of 1.875 percent each January 1 for the term of the agreement. Based upon the prorated minimum storage amount noted, Sunoco R&M has exceeded the minimum storage amount through December 31, 2004 and management of the Partnership expects Sunoco R&M to exceed the minimum storage amount under the agreement for the contract year from April 1, 2004 through March 31, 2005;

 

    receive and deliver at least 290,000 bpd of crude oil or refined products per contract year at the Fort Mifflin Terminal Complex for seven years ending February 28, 2009. This throughput is an annual amount for the contract period from March 1 to February 28 for the term of the agreement. For the year ended December 31, 2004, the Partnership received a fee of $0.1682 per barrel for the first 180,000 bpd and $0.0841 per barrel for volume in excess of 180,000 bpd. These fees will escalate at the rate of 1.67 percent each January 1 for the term of the agreement. Based upon the prorated minimum throughput amount noted, Sunoco R&M has exceeded the minimum throughput amount through December 31, 2004 and management of the Partnership expects Sunoco R&M to exceed the minimum throughput amount under the agreement for the contract year from March 1, 2004 through February 29, 2005; and

 

    transport or cause to be transported an aggregate of at least 140,000 bpd of crude oil per contract year on the Marysville to Toledo, Nederland to Longview, Cushing to Tulsa, Barnsdall to Tulsa, and Bad Creek to Tulsa crude oil pipelines at the published tariffs for a term of seven years ending February 28, 2009. This throughput is an annual amount for the contract period from March 1 to February 28 for the term of the agreement. Based upon the prorated minimum throughput amount noted, Sunoco R&M has exceeded the minimum throughput amount through December 31, 2004 and management of the Partnership expects Sunoco R&M to exceed the minimum throughput amount under the agreement for the contract year from March 1, 2004 through February 28, 2005.

 

If Sunoco R&M fails to meet its minimum obligations pursuant to the contract terms set forth above, it will be required to pay in cash the amount of any shortfall, which may be applied as a credit in the following year after Sunoco R&M’s minimum obligations for that year are met.

 

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Sunoco R&M’s obligations under this agreement may be permanently reduced or suspended if Sunoco R&M (1) shuts down or reconfigures one of its refineries (other than planned maintenance turnarounds), or is prohibited from using MTBE in the gasoline it produces, and (2) reasonably believes in good faith that such event will jeopardize its ability to satisfy these obligations. Although New York and Connecticut began enforcing state-imposed MTBE bans on January 1, 2004, this has not currently affected Sunoco R&M’s obligations under the agreement.

 

From time to time, Sunoco, Inc. may be presented with opportunities by third parties with respect to its refinery assets. These opportunities may include offers to purchase and joint venture propositions. Sunoco, Inc. is also continually considering changes to its refineries. Those changes may involve new facilities, reduction in certain operations or modifications of facilities or operations. Changes may be considered to meet market demands, to satisfy regulatory requirements or environmental and safety objectives, to improve operational efficiency or for other reasons. Sunoco, Inc. has advised the Partnership that although it continually considers the types of matters referred to above, it is not currently proceeding with any transaction or plan that it believes will likely result in any reconfigurations or other operational changes in any of its refineries served by the Partnership’s assets that would have a material effect on Sunoco R&M’s business relationship with the Partnership. Further, Sunoco, Inc. has also advised the management of the Partnership that it is not considering a shutdown of any of its refineries served by the Partnership’s assets. Sunoco, Inc. is, however, actively managing its assets and operations and, therefore, changes of some nature, possibly material to its business relationship with the Partnership, are likely to occur at some point in the future.

 

There can be no assurance that Sunoco R&M will renew the pipelines and terminals storage and throughput agreement, or that, if renewed, the rates will be at or above the current rates. If Sunoco R&M does not extend or renew the pipelines and terminals storage and throughput agreement, the Partnership’s financial condition and results of operations may be adversely affected. The Partnership’s assets were constructed or purchased to service Sunoco R&M’s refining and marketing supply chain and are well-situated to suit Sunoco R&M’s needs. As a result, management of the Partnership would expect that even if this agreement is not renewed, Sunoco R&M would continue to use the pipelines and terminals. However, management cannot assure investors and other interested parties that Sunoco R&M will continue to use the Partnership’s facilities or that additional revenues can be generated from third parties.

 

Sunoco R&M’s obligations under this agreement do not terminate if Sunoco, Inc. and its affiliates no longer own the general partner. This agreement may be assigned by Sunoco R&M only with the consent of the Audit/Conflicts Committee of the general partner’s board of directors.

 

Omnibus Agreement

 

Coincident with the closing of the IPO on February 8, 2002, the Partnership entered into an Omnibus Agreement with Sunoco, Inc., Sunoco R&M, and the general partner that addresses the following matters:

 

    Sunoco R&M’s obligation to reimburse the Partnership for specified operating expenses and capital expenditures or otherwise to complete certain tank maintenance and inspection projects;

 

    the Partnership’s obligation to pay the general partner or Sunoco, Inc. an annual administrative fee, $8.4 million for the year ended December 31, 2004, for the provision by Sunoco, Inc. of certain general and administrative services;

 

    Sunoco, Inc.’s and its affiliates’ agreement not to compete with the Partnership under certain circumstances;

 

    the Partnership’s agreement to undertake to develop and construct or acquire an asset if requested by Sunoco, Inc.;

 

    an indemnity by Sunoco, Inc. for certain environmental, toxic tort and other liabilities;

 

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    the Partnership’s obligation to indemnify Sunoco, Inc. and its affiliates for events and conditions associated with the operation of the assets that occur on or after the closing of the initial public offering and for environmental and toxic tort liabilities related to the assets to the extent Sunoco, Inc. is not required to indemnify the Partnership; and

 

    the Partnership’s option to purchase certain pipeline, terminalling, and storage assets retained by Sunoco, Inc. or its affiliates.

 

Reimbursement of Expenses and Completion of Certain Projects by Sunoco R&M. The Omnibus Agreement requires Sunoco R&M to:

 

    reimburse the Partnership for any operating expenses and capital expenditures in excess of $8.0 million per year in each calendar year from 2002 to 2006 that are made to comply with the DOT’s pipeline integrity management rule, subject to a maximum aggregate reimbursement of $15.0 million over the five-year period ending December 31, 2006;

 

    complete, at its expense, certain tank maintenance and inspection projects at the Darby Creek Tank Farm; and

 

    reimburse the Partnership for up to $10.0 million of required expenditures at the Marcus Hook Tank Farm and the Darby Creek Tank Farm to maintain compliance with existing industry standards and regulatory requirements, including: cathodic protection upgrades at these facilities; raising tank farm pipelines above ground level at these facilities; and repairing or demolishing two riveted tanks at the Marcus Hook Tank Farm.

 

The Partnership is reflecting outlays for these programs as operating expenses or capital expenditures, as appropriate. Capital expenditures are depreciated over their useful lives. Reimbursements by Sunoco R&M are reflected as capital contributions to Partners’ Capital within the Partnership’s balance sheets.

 

For the years ended December 31, 2002, 2003 and 2004, the Partnership was reimbursed $0.7 million, $1.9 million and $2.1 million, respectively, by Sunoco R&M for maintenance capital expenditures and operating expenses incurred in excess of $8.0 million to comply with the DOT’s pipeline integrity management rule. At December 31, 2004, the Partnership has received a cumulative reimbursement of $4.7 million in regard to the $15.0 million maximum reimbursement over the five-year period for compliance expenditures related to the DOT’s pipeline integrity management rule. For the year ended December 31, 2002, the Partnership was also reimbursed $2.1 million by Sunoco R&M for certain tank maintenance and inspection capital expenditures at the Darby Creek Tank Farm. There were no amounts expended for these tank maintenance and inspection projects at the Darby Creek Tank Farm during 2003 or 2004. For the years ended December 31, 2002, 2003 and 2004, the Partnership was reimbursed by Sunoco R&M for expenditures at the Marcus Hook Tank Farm and the Darby Creek Tank Farm to maintain compliance with existing industry standards and regulatory requirements. These expenditures, which were recorded as maintenance capital and operating expenses, were as follows:

 

     Partnership
and
Predecessor


   Partnership

     Year Ended December 31,

     2002

   2003

   2004

     (in thousands of dollars)

Maintenance capital

   $ 534    $ 2,982    $ 4,140

Operating expenses

     351      467      540
    

  

  

     $ 885    $ 3,449    $ 4,680
    

  

  

 

At December 31, 2004, the Partnership has received a cumulative reimbursement of $9.0 million relative to the $10.0 million maximum reimbursement for compliance expenditures at the Marcus Hook Tank Farm and the

 

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Darby Creek Tank Farm. The aggregate amounts reimbursed related to all of the previously mentioned provisions of the Omnibus Agreement were $3.7 million, $5.3 million and $6.8 million for the years ended December 31, 2002, 2003 and 2004, respectively.

 

General and Administrative Services Fee. Prior to the February 2002 IPO, Sunoco allocated a portion of its general and administrative expenses to its pipeline, terminalling, and storage operations to cover costs of certain corporate services. Prior to the IPO, such expenses were based on amounts negotiated between the parties, which approximated Sunoco’s cost of providing such services. Under the Omnibus Agreement, the Partnership pays Sunoco, Inc. or the general partner an annual administrative fee that includes expenses incurred by Sunoco, Inc. and its affiliates to perform centralized corporate functions, such as legal, accounting, treasury, engineering, information technology, insurance, and other corporate services, including the administration of employee benefit plans. This fee does not include the costs of shared insurance programs (which are allocated to the Partnership based upon its share of the cash premiums incurred), the salaries of pipeline and terminal personnel or other employees of the general partner (including senior executives), or the cost of their employee benefits. The Partnership has no employees, and reimburses Sunoco, Inc. and its affiliates for these costs and other direct expenses incurred on the Partnership’s behalf. In addition, the Partnership has incurred additional general and administrative costs, including costs related to operating as a separate publicly held entity, such as costs for tax return preparation, annual and quarterly reports to unitholders, and investor relations and registrar and transfer agent fees, as well as incremental insurance costs.

 

Selling, general and administrative expenses in the statements of income include costs related to the provision of these centralized corporate functions and allocation of shared insurance costs of $10.2 million, $10.9 million, and $10.9 million for the years ended December 31, 2002, 2003 and 2004, respectively. The Partnership’s and Predecessor’s share of allocated Sunoco employee benefit plan expenses, including non-contributory defined benefit retirement plans, defined contribution 401(k) plans, employee and retiree medical, dental and life insurance plans, incentive compensation plans and other such benefits, was $19.6 million, $20.6 million, and $21.0 million for the years ended December 31, 2002, 2003 and 2004, respectively. The Partnership also began incurring additional general and administrative costs from the date of the IPO, including costs for tax registrar and transfer agent fees, and other costs related to operating as a separate publicly held entity.

 

Under the terms of the agreement, the amount of the general and administrative services fee was increased in the second and third years following the initial public offering by the lesser of 2.5 percent or the consumer price index for the applicable year. The fee for the annual period ended December 31, 2004 was $8.4 million. These costs could have been increased if the Partnership consummated an acquisition or constructed additional assets that required an increase in the level of general and administrative services received by the Partnership from the general partner or Sunoco, Inc. The general partner, with the approval and consent of its Audit/Conflicts Committee, also has the right to agree to further increases in connection with expansion of the operations through the acquisition or construction of new assets or businesses that require an increase in the level of general and administrative services received by the Partnership. After this three-year period, the general partner will determine the general and administrative expenses to be allocated to the Partnership. In January 2005, the parties extended the term of Section 4.1 of the Omnibus Agreement (which concerns the Partnership’s obligation to pay the annual fee for provision of certain general and administrative services) by one year. The annual Administrative Fee applicable to this one-year extension is $8.4 million. There can be no assurance that Section 4.1 of the Omnibus Agreement will be extended beyond 2005, or that, if extended, the administrative fee charged by Sunoco will be at or below the current administrative fee. In the event that the Partnership is unable to obtain such services from Sunoco or other third parties at or below the current cost, the Partnership’s financial condition and results of operations may be adversely impacted.

 

Development or Acquisition of an Asset by the Partnership. The Omnibus Agreement contains a provision pursuant to which Sunoco, Inc. may at any time propose to the Partnership that it undertake a project to develop and construct or acquire an asset. If the general partner determines in its good faith judgment, with the concurrence of its Audit/Conflicts Committee, that the project, including the terms on which Sunoco, Inc. would

 

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agree to use such asset, will be beneficial on the whole and that proceeding with the project will not effectively preclude the Partnership from undertaking another project that will be more beneficial to the Partnership, the Partnership will be required to use commercially reasonable efforts to finance, develop, and construct or acquire the asset.

 

Noncompetition. Sunoco, Inc. agreed, and will cause its affiliates to agree, for so long as Sunoco, Inc. controls the general partner, not to engage in, whether by acquisition or otherwise, the business of purchasing crude oil at the wellhead or operating crude oil pipelines or terminals, refined products pipelines or terminals, or LPG terminals in the continental United States. This restriction does not apply to:

 

    any business operated by Sunoco, Inc. or any of its subsidiaries at the closing of the initial public offering;

 

    any logistics asset constructed by Sunoco, Inc. or any of its subsidiaries within a manufacturing or refining facility in connection with the operation of that facility;

 

    any business that Sunoco, Inc. or any of its subsidiaries acquires or constructs that has a fair market value of less than $5.0 million; and

 

    any business that Sunoco, Inc. or any of its subsidiaries acquires or constructs that has a fair market value of $5.0 million or more if the Partnership has been offered the opportunity to purchase the business for fair market value not later than six months after completion of such acquisition or construction, and the Partnership declines to do so with the concurrence of the Audit/Conflicts Committee.

 

In addition, the limitations on the ability of Sunoco, Inc. and its affiliates to compete with the Partnership will terminate upon a change of control of Sunoco, Inc.

 

Options to Purchase Assets Retained by Sunoco, Inc. The Omnibus Agreement also contains the terms under which the Partnership has the option to purchase Sunoco, Inc.’s direct or indirect interests in Mid-Valley Pipeline Company, Mesa Pipeline and Inland Corporation, as well as the Icedale pipeline, as described under “Business – Pipeline, Terminalling, and Storage Assets Retained by Sunoco, Inc.”

 

Indemnification. Under the Omnibus Agreement, Sunoco, Inc. has agreed to indemnify the Partnership for 30 years after the closing of the February 2002 IPO against certain environmental and toxic tort liabilities associated with the operation of the assets and occurring before the closing date of the February 2002 IPO. This indemnity obligation will be reduced by 10 percent per year beginning with the 22nd year after the closing of the February 2002 IPO. The Partnership has agreed to indemnify Sunoco, Inc. and its affiliates for events and conditions associated with the operation of the assets that occur on or after the closing of the February 2002 IPO and for environmental and toxic tort liabilities related to the assets to the extent Sunoco, Inc. is not required to indemnify the Partnership. Please read “Environmental Matters” and “Business—Environmental Regulation—Environmental Remediation” for a further description of these provisions.

 

Sunoco, Inc. has also agreed to indemnify the Partnership for liabilities relating to:

 

    the assets contributed, other than environmental and toxic tort liabilities, that arise out of the operation of the assets prior to the closing of the February 2002 IPO and that are asserted within ten years after the closing of the IPO;

 

    certain defects in title to the assets contributed and failure to obtain certain consents and permits necessary to conduct the business that arise within ten years after the closing of the February 2002 IPO;

 

    legal actions related to the period prior to the February 2002 IPO currently pending against Sunoco, Inc. or its affiliates; and

 

    events and conditions associated with any assets retained by Sunoco, Inc. or its affiliates.

 

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Interrefinery Lease Agreement

 

Under a 20-year lease agreement entered into by the Partnership and Sunoco R&M upon the closing of the February 2002 IPO, Sunoco R&M leases the Partnership’s 58 miles of interrefinery pipelines between Sunoco R&M’s Philadelphia and Marcus Hook refineries for an annual fee which escalates at 1.67 percent each January 1st for the term of the agreement. The annual fee for the year ended December 31, 2004 was $5.3 million. These fees are recorded as revenue within the Partnership’s statements of income.

 

The lease agreement also requires Sunoco R&M to reimburse the Partnership for any non-routine maintenance expenditures, as defined, incurred during the term of the agreement. For the year ended December 31, 2004, the Partnership incurred maintenance capital expenditures of $0.1 million under this provision within the agreement and was reimbursed by Sunoco R&M. The reimbursement was recorded as a capital contribution to Partners’ Capital within the Partnership’s balance sheet.

 

Crude Oil Purchase Agreement

 

The Partnership has agreements with Sunoco R&M whereby Sunoco R&M purchases from the Partnership, at market-based rates, particular grades of crude oil that are purchased by the crude oil acquisition and marketing business. These agreements automatically renew on a monthly basis unless terminated by either party on 30 days’ written notice. For the years ended December 31, 2002, 2003 and 2004, Sunoco R&M has purchased all the barrels offered pursuant to these agreements and has not indicated that it intends to terminate these agreements.

 

License Agreement

 

The Partnership has granted to Sunoco, Inc. and certain of its affiliates, including the general partner, a license to its intellectual property so that the general partner can manage its operations and create new intellectual property using the Partnership’s intellectual property. The general partner will assign to the Partnership the new intellectual property it creates in operating the Partnership’s business. The general partner has also licensed to the Partnership certain of its own intellectual property for use in the conduct of the Partnership’s business and the Partnership has licensed to the general partner certain intellectual property for use in the conduct of its business. The license agreement has also granted to the Partnership a license to use the trademarks, trade names, and service marks of Sunoco in the conduct of its business.

 

Treasury Services Agreement

 

The Partnership has a treasury services agreement with Sunoco, Inc. pursuant to which, among other things, it is participating in Sunoco, Inc.’s centralized cash management program. Under this program, all of the cash receipts and cash disbursements are processed, together with those of Sunoco, Inc. and its other subsidiaries, through Sunoco, Inc.’s cash accounts with a corresponding credit or charge to an intercompany account. The intercompany balance will be settled periodically, but no less frequently than monthly. Amounts due from Sunoco, Inc. and its subsidiaries earn interest at a rate equal to the average rate of the Partnership’s third-party money market investments, while amounts due to Sunoco, Inc. and its subsidiaries bear interest at a rate equal to the interest rate provided in the revolving credit facility (the “Credit Facility”).

 

Subsequent to the closing of the February 2002 IPO, the Partnership entered into the following significant agreements with Sunoco R&M and Sunoco, Inc.:

 

Eagle Point Logistics Assets Purchase and Throughput Agreements

 

On March 30, 2004, the Partnership entered into a purchase agreement with Sunoco R&M to acquire the Eagle Point refinery logistics assets for $20 million. The purchase agreement requires Sunoco R&M to reimburse the Partnership for certain maintenance capital and expense expenditures incurred regarding the assets acquired,

 

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as defined, up to $5.0 million within the first 10 years of the closing of the transaction. For the year ended December 31, 2004, the Partnership incurred maintenance capital expenditures of $0.1 million under this provision within the agreement and was reimbursed by Sunoco R&M. The reimbursement was recorded as a capital contribution to Partners’ Capital within the Partnership’s balance sheet.

 

In connection with the acquisition, the Partnership also entered into a throughput agreement with Sunoco R&M under which the Partnership is charging Sunoco R&M fees for services provided under this agreement that are comparable to those charged in arm’s length, third-party transactions. The throughput agreement requires Sunoco R&M to maintain minimum volumes on the truck rack acquired in this transaction upon completion of certain capital improvements that were completed during the fourth quarter of 2004.

 

Unit Redemption and Equity Offering Cost-Sharing Agreements

 

In April 2004, the Partnership sold 3.4 million common units in a public offering as described under “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Equity Offerings”. In connection with this common unit offering, the Partnership entered into an agreement with Sunoco whereby the Partnership would utilize a partial amount of the offering proceeds to redeem common units held by Sunoco at a price per unit equal to the public offering price per unit after the underwriters’ commissions. As a result, the Partnership redeemed approximately 2.2 million common units from Sunoco for $82.7 million. The Partnership and Sunoco also entered into an agreement whereby Sunoco agreed to reimburse the Partnership for transaction costs it incurred based upon the percentage that Sunoco’s net redemption proceeds received represented of the total gross proceeds of the Partnership’s offering (64.2 percent). Reimbursement of these costs of $0.4 million occurred during the fourth quarter of 2004 when the transaction costs were finalized and was accounted for as an increase to Partners’ Capital within the Partnership’s balance sheet.

 

Other Agreements

 

The Partnership has also entered into various other agreements with Sunoco, Inc., Sunoco R&M and their affiliates, including throughput agreements regarding certain acquired assets or improvements or expansions at existing assets which are not covered within the pipelines and terminals storage and throughput agreement. Although these agreements did not result from arm’s-length negotiations, management of the Partnership believes the terms of these agreements to be comparable to those that could be negotiated with an unrelated third party.

 

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Table of Contents

Results of Operations

 

     Partnership
and
Predecessor


    Partnership

     Year Ended December 31,

     2002

    2003

   2004

     (in thousands)

Statements of Income

                     

Sales and other operating revenue:

                     

Affiliates

   $ 1,147,721     $ 1,383,090    $ 1,751,612

Unaffiliated customers

     676,307       1,274,383      1,699,673

Other income

     6,904       16,730      13,932
    


 

  

Total revenues

     1,830,932       2,674,203      3,465,217
    


 

  

Cost of products sold and operating expenses

     1,690,896       2,519,160      3,307,480

Depreciation and amortization

     31,334       27,157      31,933

Selling, general and administrative expenses

     43,073       48,412      48,449
    


 

  

Total costs and expenses

     1,765,303       2,594,729      3,387,862
    


 

  

Operating income

     65,629       79,474      77,355

Net interest expense

     17,299       20,040      20,324

Income before income tax expense

     48,330       59,434      57,031

Income tax expense

     1,555       —        —  
    


 

  

Net income

   $ 46,775     $ 59,434    $ 57,031
    


 

  

Segment Operating Income:

                     

Eastern Pipeline System

                     

Sales and other operating revenue:

                     

Affiliate

   $ 72,173     $ 72,533    $ 72,500

Unaffiliated customers

     22,865       21,628      24,939

Other income

     6,925       12,147      11,701
    


 

  

Total revenues

     101,963       106,308      109,140
    


 

  

Operating expenses

     42,982       40,000      45,769

Depreciation and amortization

     15,051       10,630      11,005

Selling, general and administrative expenses

     16,772       18,560      18,077
    


 

  

Total costs and expenses

     74,805       69,190      74,851
    


 

  

Operating income

   $ 27,158     $ 37,118    $ 34,289
    


 

  

Terminal Facilities

                     

Sales and other operating revenue:

                     

Affiliates

   $ 55,971     $ 60,060    $ 71,203

Unaffiliated customers

     31,914       31,608      34,749

Other income

     2       1,146      16
    


 

  

Total revenues

     87,887       92,814      105,968
    


 

  

Operating expenses

     35,568       38,521      45,011

Depreciation and amortization

     11,113       10,925      15,115

Selling, general and administrative expenses

     12,367       12,913      13,036
    


 

  

Total costs and expenses

     59,048       62,359      73,162
    


 

  

Operating income

   $ 28,839     $ 30,455    $ 32,806
    


 

  

Western Pipeline System

                     

Sales and other operating revenue:

                     

Affiliates

   $ 1,019,577     $ 1,250,497    $ 1,607,909

Unaffiliated customers

     621,528       1,221,147      1,639,985

Other income/(loss)

     (23 )     3,437      2,215
    


 

  

Total revenues

     1,641,082       2,475,081      3,250,109
    


 

  

Cost of products sold and operating expenses

     1,612,346       2,440,639      3,216,700

Depreciation and amortization

     5,170       5,602      5,813

Selling, general and administrative expenses

     13,934       16,939      17,336
    


 

  

Total costs and expenses

     1,631,450       2,463,180      3,239,849
    


 

  

Operating income

   $ 9,632     $ 11,901    $ 10,260
    


 

  

 

36


Table of Contents

Operating Highlights

 

     Partnership
and
Predecessor


   Partnership

     Year Ended December 31,

     2002

   2003

   2004

Eastern Pipeline System(1):

              

Total shipments (barrel miles per day)(2)

   56,768,267    55,323,880    59,173,047

Revenue per barrel mile (cents)

   0.459    0.466    0.450

Terminal Facilities:

              

Terminal throughput (bpd):

              

Refined product terminals

   272,784    283,071    340,675

Nederland Terminal

   437,381    441,701    487,828

Fort Mifflin Terminal Complex

   322,611    322,389    336,555

Marcus Hook Tank Farm

   150,008    157,233    144,724

Eagle Point Dock(3)

   —      —      204,105

Western Pipeline System(1):

              

Crude oil pipeline throughput (bpd)

   286,912    304,471    298,797

Crude oil purchases at wellhead (bpd)

   189,277    193,176    186,827

Gross margin per barrel of pipeline throughput (cents)(4)

   22.5    22.9    23.2

(1) Excludes amounts attributable to equity ownership interests in the corporate joint ventures.
(2) Represents total average daily pipeline throughput multiplied by the number of miles of pipeline through which each barrel has been shipped.
(3) Acquired on March 30, 2004. Amount for 2004 represents throughput for the period from the date of acquisition through December 31, 2004, divided by the number of days in that period.
(4) Represents total segment sales and other operating revenue minus cost of products sold and operating expenses and depreciation and amortization divided by crude oil pipeline throughput.

 

Year Ended December 31, 2004 versus Year Ended December 31, 2003

 

Analysis of Statements of Income

 

Net income was $57.0 million for the year ended December 31, 2004 as compared with $59.4 million for the prior year, a decrease of $2.4 million. This decrease was primarily the result of higher Eastern Pipeline System and Terminal Facilities operating and maintenance expenses, lower volumes at the Eastern Pipeline System as a result of turnarounds at Sunoco, Inc.’s Toledo refinery in March 2004 and Marcus Hook refinery in September 2004, higher depreciation and amortization due to accelerating depreciation expense related to certain refined product terminal system assets, the absence in the current period of a gain on settlement of a claim at the Nederland Terminal, lower equity income from the corporate joint venture interests, and costs related to complying with Sarbanes-Oxley. Partially offsetting these items were higher revenues from the Terminal Facilities and Eastern Pipeline System and the operating results from the acquisitions completed during 2004 (see Item 1. “Business—Acquisitions”).

 

Sales and other operating revenue totaled $3,451.3 million for the year ended December 31, 2004 as compared with $2,657.5 million for the prior year, an increase of $793.8 million. This increase was largely attributable to an increase in crude oil prices, partially offset by a decline in lease acquisition and bulk volumes. The average price of West Texas Intermediate crude oil at Cushing, Oklahoma, the benchmark crude oil in the United States, increased to an average price of $41.34 per barrel for 2004 from $31.02 per barrel for the prior year. Other income decreased $2.8 million from the prior year to $13.9 million for 2004 due principally to lower equity income from the corporate joint venture interests and the absence in the current period of a gain on settlement of a claim at the Nederland Terminal.

 

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Table of Contents

Total costs of products sold and operating expenses increased $788.3 million to $3,307.5 million for the year ended December 31, 2004 from $2,519.2 million for the prior year due primarily to the increase in crude oil prices, partially offset by a decline in lease acquisition and bulk volumes described previously. Depreciation and amortization increased $4.8 million to $31.9 million for 2004 due primarily to $1.8 million of accelerating depreciation related to certain refined product terminal system assets related to an equipment upgrade program and depreciation expense on the assets acquired during 2004. The refined product terminal equipment upgrade program will enhance the services provided by the Partnership to existing customers and will facilitate obtaining additional third-party business.

 

Net interest expense was $20.3 million for the year ended December 31, 2004, a $0.3 million increase from the prior year due principally to a decrease in capitalized interest.

 

Analysis of Segment Operating Income

 

Eastern Pipeline System

 

Operating income for the Eastern Pipeline System was $34.3 million for the year ended December 31, 2004 compared with $37.1 million for the prior year. The $2.8 million decrease was the result of a $5.7 million increase in total costs and expenses and a $0.4 million decrease in other income, partially offset by a $3.3 million increase in sales and other operating revenue. Sales and other operating revenue increased to $97.4 million for 2004 as a result of an increase in total shipments, partially offset by lower revenue per barrel mile. The increase in shipments was primarily the result of higher refined product throughput on the Harbor pipeline due to the acquisition of the additional one-third ownership interest and higher crude oil throughput on the Marysville to Toledo pipeline, partially offset by a decline in volumes as a result of planned turnarounds at Sunoco, Inc.’s Toledo refinery in March 2004 and Marcus Hook refinery in September 2004. The decrease in other income to $11.7 million for 2004 was due to lower equity income from the interests in corporate joint ventures. The increase in total costs and expenses to $74.9 million for 2004 from $69.2 million for the prior year was principally due to an increase in scheduled maintenance costs, the inclusion of an additional one-third ownership interest in the Harbor pipeline, and higher fuel and power costs associated with the increase in volumes.

 

Terminal Facilities

 

The Terminal Facilities business segment experienced a $2.3 million increase in operating income to $32.8 million for the year ended December 31, 2004 compared with $30.5 million for the prior year. This increase was due mainly to a $14.3 million increase in sales and other operating revenue, partially offset by a $10.8 million increase in total costs and expenses and a $1.1 million decrease in other income. The increase in sales and other operating revenue to $106.0 million for 2004 compared with $91.7 million for the prior year was principally due to the acquisitions completed during 2004, an increase in the Nederland Terminal’s volumes, and higher volumes at the refined product terminals and the Fort Mifflin Terminal Complex. The Nederland Terminal’s volumes increased from the prior year due to a full year’s utilization in 2004 of two new tanks constructed in 2003 and higher utilization of tankage caused by improved market conditions for crude oil imports. Other income decreased $1.1 million from the prior year due mainly to the prior year gain recognized on the settlement of a claim at the Nederland Terminal.

 

The increase in total costs and expenses was due mainly to a $6.5 million increase in operating expenses and a $4.2 million increase in depreciation and amortization. Operating expenses increased to $45.0 million for 2004 from $38.5 million for the prior year due principally to expenses associated with the acquired assets, non-routine dredging activity on the Delaware River at the Fort Mifflin Terminal docks, and an increase in scheduled tank maintenance costs at the Nederland Terminal and the refined product terminals. Depreciation and amortization increased to $15.1 million for 2004 due primarily to accelerating depreciation of certain refined product terminal assets mentioned previously and depreciation on the assets acquired.

 

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Table of Contents

Western Pipeline System

 

Operating income for the Western Pipeline System was $10.3 million for the year ended December 31, 2004 compared with $11.9 million for the prior year. The $1.6 million decrease was primarily the result of a $1.2 million decrease in other income. Sales and other operating revenue and cost of products sold and operating expenses increased for the year ended December 31, 2004 compared with the prior year due principally to an increase in crude oil prices, partially offset by a decline in lease acquisition and bulk volumes mentioned previously. Other income decreased to $2.2 million for 2004 due mainly to lower equity income from the interest in West Texas Gulf Pipe Line due to a decline in demand for domestic crude oil transported on this pipeline from the prior year and the temporary shutdown of a significant connecting pipeline due to planned refinery turnarounds during the first half of 2004.

 

Year Ended December 31, 2003 versus Year Ended December 31, 2002

 

Analysis of Statements of Income

 

Net income was $59.4 million for the year ended December 31, 2003 as compared with $46.8 million for the prior year, an increase of $12.6 million. This increase was primarily the result of a $13.8 million increase in operating income and a $1.6 million decrease in income tax expense, partially offset by a $2.7 million increase in net interest expense. The increase in operating income was principally due to the effect of special items such as the absence in the current year of a $6.3 million write-down of an idled refined product pipeline at the Eastern Pipeline System and a related terminal and a $1.2 million gain in the current year relating to the settlement of a claim at the Nederland Terminal resulting from assets damaged by the May 2003 third-party natural gas pipeline release. The cash received relating to this claim was primarily used to replace or repair damaged assets. The increase in operating income also includes equity income for a full year from the corporate joint ventures acquired in November 2002, higher trunk and gathering pipeline volumes and an increase in gross margins at the Western Pipeline System, and a decline in operating expenses at the Eastern Pipeline System. Partially offsetting these items were increases in selling, general and administrative expenses and operating expenses at the Western Pipeline System and Terminal Facilities.

 

Sales and other operating revenue totaled $2,657.5 million for the year ended December 31, 2003 as compared with $1,824.0 million for the prior year, an increase of $833.5 million. This increase was largely attributable to an increase in crude oil prices and higher lease acquisition and bulk volumes. The average price of West Texas Intermediate crude oil at Cushing, Oklahoma, the benchmark crude oil in the United States, increased to an average price of $31.02 per barrel for 2003 from $26.11 per barrel for the prior year. Other income increased $9.8 million from the prior year to $16.7 million for 2003 due principally to equity income from the interests in corporate joint ventures acquired in November 2002.

 

Total costs of products sold and operating expenses increased $828.3 million to $2,519.2 million for the year ended December 31, 2003 from $1,690.9 million for the prior year due primarily to the increase in crude oil prices and higher lease acquisition and bulk volumes described previously. Selling, general and administrative expenses increased $5.3 million to $48.4 million for 2003 compared with $43.1 million for the prior year due mainly to higher administrative costs, including employee-related expenses. Depreciation and amortization decreased $4.2 million to $27.2 million for 2003 due to the write-down in 2002 described previously.

 

Net interest expense increased $2.7 million to $20.0 million for the year ended December 31, 2003 compared with $17.3 million for the prior year due principally to a decrease in capitalized interest and the interest on the Credit Facility borrowings as a result of the November 2002 acquisitions.

 

Income tax expense for the year ended December 31, 2003 decreased $1.6 million from the prior year to nil in the current year as the Partnership was not subject to income taxes from its inception on February 8, 2002.

 

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Table of Contents

Analysis of Segment Operating Income

 

Eastern Pipeline System

 

Operating income for the Eastern Pipeline System was $37.1 million for the year ended December 31, 2003 compared with $27.1 million for the prior year. The $10.0 million increase was the result of a $5.2 million increase in other income and a $5.6 million decrease in total costs and expenses, partially offset by a $0.9 million decrease in sales and other operating revenue. Sales and other operating revenue decreased to $94.2 million for 2003 from $95.0 million in the prior year as a result of a decrease in total shipments, partially offset by higher revenue per barrel mile. The increase in other income to $12.1 million for 2003 was due to equity income from the interests in corporate joint ventures acquired in November 2002, partially offset by a decline in equity income from Explorer Pipeline Company (“Explorer) due to lower volumes.

 

The decrease in total costs and expenses from the prior year was due to a $4.4 million decrease in depreciation and amortization and a $3.0 million decrease in operating expenses, partially offset by a $1.8 million increase in selling, general and administrative expenses. The decrease in depreciation and amortization from $15.1 million for 2002 to $10.6 million for 2003 was principally due to the absence of the write-down previously mentioned. The decrease in operating expenses from $43.0 million for 2002 to $40.0 million for 2003 was primarily due to the absence of costs in the current year associated with a pipeline release in January 2002 and lower pipeline maintenance expenses. As this pipeline release occurred prior to the February 2002 IPO and the Partnership is indemnified by Sunoco, Inc. and its subsidiaries (collectively, “Sunoco”) for liabilities associated with this incident, there was no impact on the Partnership’s post-IPO results. The increase in selling, general and administrative expenses to $18.6 million for 2003 from $16.8 million for 2002 was due to higher allocated administrative expenses.

 

Terminal Facilities

 

The Terminal Facilities business segment experienced a $1.6 million increase in operating income to $30.5 million for the year ended December 31, 2003 compared with $28.9 million for the prior year. This increase was due mainly to a $3.8 million increase in sales and other operating revenue and a $1.1 million increase in other income, partially offset by a $3.3 million increase in total costs and expenses. The increase in sales and other operating revenue to $91.7 million for 2003 compared with $87.9 million for the prior year was principally due to higher throughput volumes at the refined product terminals and the Marcus Hook Tank Farm, partially offset by lower tank rental revenues at the Nederland Terminal. Other income increased to $1.1 million for 2003 due primarily to the gain recognized related to the settlement of a claim at the Nederland Terminal noted previously.

 

The increase in total costs and expenses was due mainly to a $3.0 million increase in operating expenses and a $0.5 million increase in selling, general and administrative expenses. Operating expenses increased to $38.5 million for 2003 from $35.5 million for the prior year due principally to higher maintenance expenses at the refined product terminals, the Fort Mifflin Terminal Complex, and the Marcus Hook Tank Farm. Selling, general and administrative expenses increased to $12.9 million due to higher allocated administrative expenses.

 

Western Pipeline System

 

Operating income for the Western Pipeline System was $11.9 million for the year ended December 31, 2003 compared with $9.6 million for the prior year. This $2.3 million increase was primarily the result of a $3.5 million increase in other income and a $1.8 million increase in gross margin, partially offset by a $3.0 million increase in selling, general and administrative expenses.

 

Sales and other operating revenue and cost of products sold and operating expenses increased for the year ended December 31, 2003 compared with the prior year due principally to an increase in crude oil prices and an increase in lease acquisition and bulk volumes previously mentioned. The increase in gross margin was due mainly to an increase in lease acquisition volumes and margins and higher trunk and gathering pipeline volumes

 

40


Table of Contents

compared with the prior year. These amounts were partially offset by higher pipeline integrity management and maintenance expenses. Other income increased to $3.4 million for 2003 due mainly to the equity income from the interest in West Texas Gulf Pipe Line acquired in November 2002. Selling, general and administrative expenses increased to $16.9 million for 2003 compared with $13.9 million in the prior year due to higher allocated administrative expenses.

 

Liquidity and Capital Resources

 

General

 

Cash generated from operations and borrowings under the Credit Facility are the Partnership’s primary sources of liquidity. At December 31, 2004, the Partnership had working capital of $34.9 million and available borrowing capacity under the Credit Facility of $185.5 million (see “Credit Facility”). The Partnership’s working capital position also reflects crude oil inventories based on historical costs under the LIFO method of accounting. If the inventories had been valued at their current replacement cost, the Partnership would have had working capital of $94.5 million at December 31, 2004.

 

On April 7, 2004, the Partnership sold 3.4 million common units in a public offering for total gross proceeds of $135.1 million. The units were issued under the Partnership’s previously filed $500 million universal shelf registration statement, of which approximately $364.9 million remains available. The sale of the units resulted in net proceeds of $128.7 million, after underwriters’ commissions and legal, accounting, and other transaction expenses. Net proceeds from the sale were used to (a) redeem approximately 2.2 million common units from Sunoco for $82.7 million, (b) replenish cash utilized to acquire the Eagle Point logistics assets for $20.0 million, (c) finance the acquisition of two refined product terminals for $12.0 million, (d) finance the acquisition of an additional 33.3 percent undivided interest in the Harbor pipeline for $7.3 million, and (e) for general partnership purposes, including to replenish cash used for past acquisitions and capital improvements, and for other expansion, capital improvements or acquisition projects. As a result of this net issuance of 1.2 million common units, the Partnership also received $1.0 million from its general partner as a capital contribution to maintain its 2.0 percent general partner interest. After the redemption of its units, Sunoco’s ownership interest in the Partnership decreased from 75.3 percent to 62.6 percent, including its 2.0 percent general partner interest.

 

On November 22, 2004, the Partnership entered into a new five-year, $250 million Revolving Credit Facility. This Credit Facility replaces the previous credit agreement, which was scheduled to mature on January 31, 2005. At December 31, 2004, there was $64.5 million drawn under the Credit Facility.

 

Management believes that the Partnership has sufficient liquid assets, cash from operations and borrowing capacity to meet its financial commitments, debt service obligations, unitholder distributions, contingencies and anticipated capital expenditures. However, the Partnership is subject to business and operational risks that could adversely effect its cashflow. The Partnership may supplement its cash generation with proceeds from financing activities, including borrowings under the Credit Facility and other borrowings and the issuance of additional common units.

 

Cash Flows and Capital Expenditures

 

Net cash provided by operating activities for the years ended December 31, 2002, 2003 and 2004 was $2.2 million, $97.2 million, and $106.6 million, respectively. Net cash provided by operating activities for 2004 was primarily generated by net income of $57.0 million, depreciation and amortization of $31.9 million, and a decrease in working capital of $13.5 million. Net cash provided by operating activities for 2003 was primarily generated by net income of $59.4 million, depreciation and amortization of $27.2 million, and a decrease in working capital of $5.3 million. Net cash provided by operating activities for 2002 principally includes net income of $46.8 million and depreciation and amortization of $31.3 million, partially offset by an increase in working capital of $74.1 million. The increase in net cash provided by operating activities of $9.4 million from

 

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Table of Contents

2004 to 2003 was primarily attributable to an increase in cash provided by working capital mainly due to an increase in the price of crude oil. The increase in net cash provided by operating activities of $95.0 million from 2002 to 2003 was primarily attributable to an increase in cash provided by working capital and an increase in net income. The change in working capital between 2002 and 2003 was due mainly to an increase in working capital in 2002 related to the replacement of working capital that was not contributed by Sunoco to the Partnership upon formation. The net proceeds of the IPO were used to replenish this working capital. The working capital not contributed consisted principally of $81.0 million of affiliated-company accounts receivable and $13.5 million of crude oil inventory.

 

Net cash used in investing activities for the years ended December 31, 2002, 2003, and 2004 was $85.3 million, $39.0 million and $95.6 million, respectively. Capital expenditures were $40.8 million in 2002, $37.4 million in 2003, and $46.4 million in 2004. During 2004, the Partnership completed the following acquisitions: the Eagle Point logistics assets, which were purchased for $20.0 million; two refined product terminals located in Baltimore, Maryland and Manassas, Virginia, which were purchased for $12.0 million; an additional 33.3 percent undivided interest in the Harbor pipeline, which was acquired for $7.3 million; and a refined product terminal located in Columbus, Ohio, which was purchased for approximately $8.0 million. During 2003, the Partnership acquired an additional 3.1 percent corporate joint venture interest in West Shore for $3.7 million. During 2002, the Partnership acquired equity ownership interests in four corporate joint venture pipeline companies for an aggregate purchase price of $64.5 million in cash and $0.1 million in Partnership common units, consisting of $54.0 million for a 31.5 percent interest in Wolverine, a 9.2 percent interest in West Shore, and a 14.0 percent interest in Yellowstone and $10.6 million for a 43.8 percent interest in West Texas Gulf. The only other significant investing transaction in the three-year period was the repayment of a loan to The Claymont Investment Company, a wholly-owned subsidiary of Sunoco, for $20.0 million in 2002.

 

Net cash provided by/(used in) financing activities for the years ended December 31, 2002, 2003, and 2004 was $116.9 million, ($42.0) million and ($8.5) million, respectively. For the year ended December 31, 2004, the $8.5 million of net cash used in financing activities was due to the $82.7 million redemption of approximately 2.2 million common units from Sunoco, $57.5 million of cash distributions paid to the limited partners and general partner, and net advances to affiliate of $5.1 million, partially offset by $128.7 million of net proceeds from the sale of 3.4 million common units in April 2004, $7.0 million of capital contributions from an affiliate, and a $1.0 million net contribution from the general partner to maintain its 2.0 percent ownership interest after the sale of common units. For the year ended December 31, 2003, the $42.0 million of net cash used in financing activities was primarily due to $46.2 million of distributions paid to limited partners and the general partner and $4.5 million of repayments of long-term debt related to a note payable to a third party, partially offset by net collections of $3.4 million of advances to affiliate and $5.3 million of capital contributions from Sunoco. For the year ended December 31, 2002, the $116.9 million of net cash provided by financing activities was due to net proceeds of $96.5 million from the IPO, $64.5 million of borrowings under the Credit Facility to fund the acquisitions noted earlier, and $43.9 million of capital contributions from Sunoco, partially offset by a $50.0 million repayment of long-term debt due an affiliate, $26.9 million of distributions paid to limited partners and the general partner and net advances to affiliates of $10.7 million. In addition, net proceeds of $244.8 million from the issuance of the Senior Notes in conjunction with the IPO were distributed to Sunoco. For a more detailed discussion of the IPO and related transactions, see “Initial Public Offering” and “Senior Notes” in this section.

 

Under a treasury services agreement with Sunoco, the Partnership participates in Sunoco’s centralized cash management program. Advances to affiliates in the Partnership’s balance sheets at December 31, 2003 and 2004 represent amounts due from Sunoco under this agreement.

 

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Table of Contents

Capital Requirements

 

The pipeline, terminalling, and crude oil storage operations are capital intensive, requiring significant investment to upgrade or enhance existing operations and to meet environmental and operational regulations. The capital requirements have consisted, and are expected to continue to consist, primarily of:

 

    Maintenance capital expenditures, such as those required to maintain equipment reliability, tankage, and pipeline integrity and safety, and to address environmental regulations; and

 

    Expansion capital expenditures to acquire complementary assets to grow the business and to expand existing and construct new facilities, such as projects that increase storage or throughput volume.

 

The following table summarizes maintenance and expansion capital expenditures, including amounts paid for acquisitions, for the years presented:

 

     Partnership
and
Predecessor


    Partnership

 
     Year Ended December 31,

 
     2002

    2003

    2004

 
     (in thousands of dollars)  

Maintenance

   $ 27,934     $ 30,850     $ 30,829  

Expansion

     77,439 (1)     10,226 (2)     64,754 (3)
    


 


 


Total

   $ 105,373     $ 41,076     $ 95,583  
    


 


 



(1) Includes the acquisition of the interests in four corporate joint venture pipeline companies for an aggregate purchase price of $64.6 million, including the issuance of $0.1 million in Partnership common units.
(2) Includes the acquisition of an additional interest in one of its corporate joint venture pipeline interests for $3.7 million.
(3) Includes the following acquisitions: $20.0 million for the Eagle Point logistics assets; $12.0 million for two refined product terminals located in Baltimore, Maryland and Manassas, Virginia; $7.3 million for an additional 33.3 percent undivided joint venture interest in the Harbor pipeline; and $8.0 million for a refined product terminal located in Columbus, Ohio.

 

Maintenance capital expenditures for the years ended December 31, 2002, 2003 and 2004 were $27.9 million, $30.9 million, and $30.8 million, respectively. Maintenance capital expenditures primarily consist of recurring expenditures at each of the business segments such as pipeline integrity costs, pipeline relocations, repair and upgrade of field instrumentation, including measurement devices, repair and replacement of tank floors and roofs, upgrades of cathodic protection systems, crude trucks and related equipment, and the upgrade of pump stations. In addition to these recurring projects, maintenance capital includes certain expenditures for which the Partnership received reimbursement from Sunoco R&M under the terms of agreements between the parties discussed below. The year ended December 31, 2003 also includes $1.8 million of expenditures for the replacement of assets at the Nederland Terminal related to the May 2003 third-party natural gas pipeline release. The Partnership received reimbursement in 2003 for these costs and other expenses as settlement of the claim related to this incident. Management expects maintenance capital expenditures to be approximately $27.5 million in 2005, excluding amounts management expects to receive as reimbursement from Sunoco R&M in accordance with the terms of certain agreements.

 

Expansion capital expenditures for the years ended December 31, 2002, 2003 and 2004 were $77.4 million, $10.2 million and $64.8 million, respectively. Expansion capital expenditures for the year ended December 31, 2004 principally includes the following acquisitions: the Eagle Point logistics assets, which were purchased for $20.0 million on March 30, 2004; two refined product terminals located in Baltimore, Maryland and Manassas, Virginia, which were purchased for $12 million on April 28, 2004; an additional 33.3 percent undivided interest in the Harbor pipeline, which was acquired on June 28, 2004 for $7.3 million; and a refined product terminal

 

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located in Columbus, Ohio, which was purchased for $8.0 million on November 30, 2004. Expansion capital expenditures for 2004 also includes multiple pipeline connections and new truck stations. Expansion capital expenditures for the year ended December 31, 2003 includes the purchase of an additional 3.1 percent interest in West Shore Pipe Line Company for $3.7 million, increasing the Partnership’s overall ownership interest to 12.3 percent, and the completion of the construction of two new tanks and a new pump station at the Nederland Terminal. The new tanks added approximately 1.3 million barrels of storage capacity to the terminal. Expansion capital expenditures for the year ended December 31, 2002 includes the acquisition of the four corporate joint venture pipeline interests for an aggregate purchase price of $64.6 million, the construction of the two Nederland tanks previously mentioned, the construction of multiple vapor combustion units at the Nederland Terminal, and pipeline meter modifications at the Eastern Pipeline System to improve throughput efficiency. Management of the Partnership anticipates pursuing both further acquisitions and growth projects similar to those mentioned in the future.

 

Omnibus Agreement Expenditures

 

Under the terms of the Omnibus Agreement, Sunoco R&M is required, among other things, to: reimburse the Partnership for any operating expenses and capital expenditures in excess of $8.0 million per year in each calendar year from 2002 to 2006 that are made to comply with the DOT’s pipeline integrity management rule, subject to a maximum aggregate reimbursement of $15.0 million over the five-year period ending December 31, 2006; complete, at its expense, certain tank maintenance and inspection projects at the Darby Creek Tank Farm; and reimburse the Partnership for up to $10.0 million of expenditures required at the Marcus Hook Tank Farm and the Darby Creek Tank Farm to maintain compliance with existing industry standards and regulatory requirements.

 

For the years ended December 31, 2002, 2003 and 2004, the Partnership was reimbursed $0.7 million, $1.9 million and $2.1 million, respectively, by Sunoco R&M for maintenance capital expenditures and operating expenses incurred in excess of $8.0 million to comply with DOT’s pipeline integrity management rule. At December 31, 2004, the Partnership has received a cumulative reimbursement of $4.7 million in regard to the $15.0 million maximum reimbursement over the five-year period for compliance expenditures related to the DOT’s pipeline integrity management rule. For the year ended December 31, 2002, the Partnership also was reimbursed $2.1 million by Sunoco R&M for certain tank maintenance and inspection capital expenditures at the Darby Creek Tank Farm. There were no amounts expended for these tank maintenance and inspection projects at the Darby Creek Tank Farm during 2003 and 2004. For the years ended December 31, 2002, 2003 and 2004, the Partnership was reimbursed by Sunoco R&M for expenditures at the Marcus Hook Tank Farm and the Darby Creek Farm to maintain compliance with existing industry standards and regulatory requirements. These expenditures, which were recorded as maintenance capital and operating expenses, were as follows:

 

     Partnership
and
Predecessor


   Partnership

     Year Ended December 31,

     2002

   2003

   2004

     (in thousands of dollars)

Maintenance capital

   $ 534    $ 2,982    $ 4,140

Operating expenses

     351      467      540
    

  

  

     $ 885    $ 3,449    $ 4,680
    

  

  

 

At December 31, 2004, the Partnership has received a cumulative reimbursement of $9.0 million relative to the $10 million maximum reimbursement for compliance expenditures at the Marcus Hook Tank Farm and the Darby Creek Tank Farm. The aggregate amounts reimbursed related to all of the previously mentioned provisions of the Omnibus Agreement of $3.7 million, $5.3 million and $6.8 million for the years ended December 31, 2002, 2003 and 2004, respectively, by Sunoco R&M related to these projects were recorded as capital contributions to Partners’ Capital within the Partnership’s balance sheets.

 

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Interrefinery Lease Agreement and Eagle Point Purchase Agreement Expenditures

 

Under the terms of the Interrefinery Lease Agreement, Sunoco R&M is required to reimburse the Partnership for any non-routine maintenance expenditures, as defined, incurred during the term of the agreement. The Eagle Point purchase agreement requires Sunoco R&M to reimburse the Partnership for certain maintenance capital and expense expenditures incurred regarding the assets acquired, as defined, up to $5.0 million within the first 10 years of closing of the transaction. For the year ended December 31, 2004, the Partnership incurred maintenance capital expenditures of $0.2 million under provisions within these agreements and was reimbursed by Sunoco R&M. The reimbursements were recorded as capital contributions to Partners’ Capital within the Partnership’s balance sheet.

 

The Partnership expects to fund capital expenditures, including any acquisitions, from cash provided by operations and, to the extent necessary, from the proceeds of:

 

    borrowing under the Credit Facility discussed below and other borrowings; and

 

    issuance of additional common units.

 

Contractual Obligations

 

The following table sets forth the aggregate amount of long-term debt maturities (including interest commitments based upon the interest rate in effect at December 31, 2004), annual rentals applicable to noncancellable operating leases, and purchase commitments related to future periods at December 31, 2004 (in thousands of dollars):

 

     Year Ended December 31,

  

Thereafter


  

Total


     2005

   2006

   2007

   2008

   2009

     

Long-term debt:

                                                

Principal

   $ —      $ —      $ —      $ —      $ 64,500    $ 250,000    $ 314,500

Interest

     20,018      20,018      20,018      20,018      19,816      45,313      145,201

Operating leases

     2,692      2,351      2,077      1,722      1,417      4,218      14,477

Purchase obligations

     737,474      —        —        —        —        —        737,474
    

  

  

  

  

  

  

     $ 760,184    $ 22,369    $ 22,095    $ 21,740    $ 85,733    $ 299,531    $ 1,211,652
    

  

  

  

  

  

  

 

The Partnership’s operating leases include leases of third-party pipeline capacity, office space, and other property and equipment. Operating leases included above have initial or remaining noncancelable terms in excess of one year.

 

A purchase obligation is an enforceable and legally binding agreement to purchase goods and services that specifies significant terms, including: fixed or expected quantities to be purchased; market-related pricing provisions; and a specified term. The Partnership’s purchase obligations consist of noncancellable contracts to purchase crude oil for terms of one year or less by its Crude Oil Acquisition and Marketing group. The majority of the above purchase obligations include actual crude oil purchases for the month of January 2005. The remaining crude oil purchase obligation amounts are based on the quantities expected to be purchased for the remainder of the year, at December 31, 2004 crude oil prices. Actual amounts to be paid in regards to these obligations will be based upon market prices or formula-based market prices during the period of purchase. For further discussion of the Partnership’s Crude Oil and Marketing activities, see Item 1. “Business—Western Pipeline System—Crude Oil Acquisition and Marketing”.

 

Equity Offerings

 

On February 8, 2002, the Partnership issued 5.75 million common units (including 750,000 units issued pursuant to the underwriters’ over-allotment option), representing a 24.8 percent limited partnership interest, in

 

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an IPO at a price of $20.25 per unit. Proceeds from this offering, which totaled approximately $96.5 million net of underwriting discounts and offering expenses, were used to replace working capital that was not contributed by Sunoco.

 

On April 7, 2004, the Partnership sold 3.4 million common units in a public offering for total gross proceeds of $135.1 million. The units were issued under the Partnership’s previously filed Form S-3 shelf registration statement. The sale of the units resulted in net proceeds of $128.7 million, after underwriters’ commissions and legal, accounting, and other transaction expenses. Net proceeds from the sale were used to (a) redeem approximately 2.2 million common units from Sunoco for $82.7 million, (b) replenish cash utilized to acquire the Eagle Point logistics assets for $20.0 million, (c) finance the acquisition of two refined product terminals for $12.0 million, (d) finance the acquisition of an additional 33.3 percent undivided interest in the Harbor pipeline for $7.3 million, and (e) for general partnership purposes, including to replenish cash used for past acquisitions and capital improvements, and for other expansion, capital improvements or acquisition projects. As a result of this net issuance of 1.2 million common units, the Partnership also received $1.0 million from its general partner as a capital contribution to maintain its 2.0 percent general partner interest. After the redemption of its units, Sunoco’s ownership interest in the Partnership decreased from 75.3 percent to 62.6 percent, including its 2.0 percent general partner interest.

 

Shelf Registration Statement

 

On March 14, 2003, the Partnership and Operating Partnership, as co-registrants, filed a shelf registration statement with the Securities and Exchange Commission and became effective. This shelf registration permits the periodic offering and sale of equity securities by the Partnership and debt securities of the Operating Partnership (guaranteed by the Partnership). Subsequent to the Partnership’s sale of 3.4 million common units on April 7, 2004 (see Equity Offerings) and at December 31, 2004, $364.9 million remains available for issuance. However, the amount, type and timing of any offerings will depend upon, among other things, the funding requirements of the Partnership, prevailing market conditions, and compliance with covenants in applicable debt obligations of the Operating Partnership (including the Credit Facility).

 

Credit Facility

 

On November 22, 2004, Sunoco Logistics Partners Operations L.P., a wholly-owned entity of the Partnership (the “Operating Partnership”), entered into a new, five-year $250 million Credit Facility. This Credit Facility replaced the Operating Partnership’s previous credit agreement, which was scheduled to mature on January 31, 2005. At December 31, 2004, there was $64.5 million drawn under the Credit Facility. The Credit Facility is available to fund working capital requirements, to finance future acquisitions, and for general partnership purposes. It also includes a $20.0 million distribution sublimit that is available for distributions, and may be used to fund the quarterly distributions, provided the total outstanding borrowings for distributions do not at any time exceed $20.0 million. The Partnership will be required to reduce to zero all borrowings under the distribution sublimit under the Credit Facility each year for 15 days.

 

Obligations under the Credit Facility are unsecured. Indebtedness under the Credit Facility will rank equally with all the outstanding unsecured and unsubordinated debt of the Operating Partnership. All loans may be prepaid at any time without penalty subject to reimbursement of breakage and redeployment costs in the case of prepayment of LIBOR borrowings.

 

Indebtedness under the Credit Facility will bear interest, at the Partnership’s option, at either (i) LIBOR plus an applicable margin or (ii) the higher of the federal funds rate plus 0.50 percent or the Citibank prime rate (each plus the applicable margin). The interest rate on the borrowings outstanding under the Credit Facility as of December 31, 2004 was 2.94 percent. Fees are incurred in connection with the Credit Facility. The Credit Facility will mature on November 22, 2009.

 

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The credit agreement prohibits the Partnership from declaring distributions to unitholders if any event of default, as defined in the credit agreement, occurs or would result from the declaration of distributions. In addition, the Credit Facility contains various covenants limiting the Operating Partnership’s ability to:

 

    incur indebtedness;

 

    grant certain liens;

 

    make certain loans, acquisitions, and investments;

 

    make any material change to the nature of the business;

 

    acquire another company; or

 

    enter into a merger or sale of assets, including the sale or transfer of interests in the subsidiaries.

 

The Credit Facility also contains covenants requiring the maintenance, on a rolling-four-quarter basis, of:

 

    a maximum ratio of 4.5 to 1 of consolidated total debt to consolidated EBITDA (each as defined in the credit agreement), which can be increased to 5.0 to 1 during an acquisition period (as defined in the credit agreement); and

 

    an interest coverage ratio (as defined in the credit agreement) of at least 3.0 to 1.

 

For the year ended December 31, 2004, the Partnership’s ratio of total debt to EBITDA was 2.8 to 1 and the interest coverage ratio was 5.4 to 1.

 

Each of the following will be an event of default under the Credit Facility:

 

    failure to pay any principal, interest, fees, or other amounts when due;

 

    failure of any representation or warranty to be true and correct;

 

    termination of any material agreement, including the pipelines and terminals storage and throughput agreement and the Omnibus Agreement;

 

    default under any material agreement if such default could have a material adverse effect on the Partnership;

 

    bankruptcy or insolvency events involving the Partnership, the general partner, or the subsidiaries;

 

    the entry of monetary judgments, not covered or funded by insurance, against the Partnership, the general partner, or any of its subsidiaries in excess of $20.0 million in the aggregate, or any non-monetary judgment having a material adverse effect;

 

    the sale by Sunoco of a material portion of its refinery assets or other assets related to its agreements with the Partnership unless the purchaser of those assets has a minimum credit rating and fully assumes the rights and obligations of Sunoco under those agreements; and

 

    failure by Sunoco to own, directly or indirectly, 51 percent of the general partnership interest in the Partnership or to control its management and that of the Operating Partnership.

 

Senior Notes

 

In connection with the February 2002 IPO, the Operating Partnership issued $250 million of Senior Notes, the net proceeds of which were distributed to Sunoco as additional consideration for its contribution of assets to the Partnership. The Senior Notes were issued pursuant to an indenture, and the obligations under the Senior Notes are unsecured. Indebtedness under the Senior Notes rank equally with the Credit Facility and all the outstanding unsecured and unsubordinated debt of the Operating Partnership. The Senior Notes and Credit Facility have been guaranteed by the Partnership and the Operating Partnership’s subsidiaries. The Senior Notes

 

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will mature on February 15, 2012 and bears interest at a rate of 7.25 percent per annum, payable semi-annually on February 15 and August 15. The Senior Notes are redeemable, at the Partnership’s option, at a make-whole premium calculated on the basis of a discount rate equal to the yield on United States treasury notes having a constant maturity comparable to the remaining term of the Senior Notes, plus 25 basis points. The Senior Notes are not subject to any sinking fund provisions.

 

In addition, the Senior Notes contain various covenants limiting the Operating Partnership’s ability to:

 

    incur certain liens;

 

    engage in sale/leaseback transactions; or

 

    merge, consolidate, or sell substantially all of its assets.

 

Each of the following is an event of default under the indenture governing the Senior Notes:

 

    failure to pay interest on any note for 30 days;

 

    failure to pay the principal or any premium on any note when due;

 

    failure to perform any other covenant in the indenture that continues for 60 days after being given written notice;

 

    the acceleration of the maturity of any other debt of the Partnership or any of the subsidiaries or a default in the payment of any principal or interest in respect of any other indebtedness of the Partnership or any of the subsidiaries having an outstanding principal amount of $10.0 million or more individually or in the aggregate and such default shall be continuing for a period of 30 days; or

 

    the bankruptcy, insolvency, or reorganization of the Operating Partnership.

 

Upon the occurrence of a change of control to a non-investment grade entity, the Operating Partnership must offer to purchase the Senior Notes at a price equal to 100 percent of their principal amount plus accrued and unpaid interest, if any, to the date of purchase. The initial offering of the Senior Notes was not registered under the Securities Act. A registration statement was subsequently filed and declared effective on June 28, 2002, and an exchange offer was completed on August 2, 2002, with all $250 million aggregate principal amount of the Senior Notes being exchanged for a like principal amount of new publicly tradable notes having substantially identical terms issued pursuant to the exchange offer registration statement filed under the Securities Act of 1933, as amended.

 

Environmental Matters

 

Operation of the pipelines, terminals, and associated facilities are subject to stringent and complex federal, state, and local laws and regulations governing the discharge of materials into the environment or otherwise relating to protection of the environment. As a result of compliance with these laws and regulations, liabilities have been accrued for estimated site restoration costs to be incurred in the future at the facilities and properties, including liabilities for environmental remediation obligations. Under the Partnership’s accounting policies, liabilities are recorded when site restoration and environmental remediation and cleanup obligations are either known or considered probable and can be reasonably estimated. For a discussion of the accrued liabilities and charges against income related to these activities, see Note 11 to the financial statements included in Item 8. “Financial Statements and Supplementary Data.”

 

Under the terms of the Omnibus Agreement and in connection with the contribution of assets by affiliates of Sunoco, Sunoco has agreed to indemnify the Partnership for 30 years from environmental and toxic tort liabilities related to the assets contributed that arise from the operation of such assets prior to closing of the February 2002 IPO. Sunoco is obligated to indemnify the Partnership for 100 percent of all losses asserted within the first 21 years of closing of the February 2002 IPO. Sunoco’s share of liability for claims asserted thereafter will decrease

 

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by 10 percent a year. For example, for a claim asserted during the twenty-third year after closing of the February 2002 IPO, Sunoco would be required to indemnify the Partnership for 80 percent of the loss. There is no monetary cap on the amount of indemnity coverage provided by Sunoco. Any environmental and toxic tort liabilities not covered by this indemnity will be the Partnership’s responsibility. Total future costs for environmental remediation activities will depend upon, among other things, the identification of any additional sites, the determination of the extent of the contamination at each site, the timing and nature of required remedial actions, the technology available and needed to meet the various existing legal requirements, the nature and extent of future environmental laws, inflation rates, and the determination of the liability at multiparty sites, if any, in light of the number, participation levels, and financial viability of other parties. The Partnership has agreed to indemnify Sunoco and its affiliates for events and conditions associated with the operation of the assets that occur on or after the closing of the February 2002 IPO and for environmental and toxic tort liabilities to the extent Sunoco is not required to indemnify the Partnership.

 

The use of MTBE continues to be the focus of federal and state government attention due to public health and environmental issues that have been raised by the use of MTBE in gasoline, and specifically the discovery of MTBE in water supplies. MTBE is the primary oxygenate used by Sunoco R&M and other petroleum refiners to meet reformulated gasoline requirements under the Clean Air Act. Several states, including New York and Connecticut, began enforcing state-imposed MTBE bans on January 1, 2004 in response to concerns about MTBE’s adverse impact on ground or surface water. Other states are considering bans or restrictions on MTBE or opting out of the EPA’s reformulated gasoline program, either of which events would reduce the use of MTBE. Any ban or restriction on the use of MTBE may lead to the greater use of ethanol. Unlike MTBE, which can be blended in gasoline at the refinery, ethanol is blended at the terminal and is not transported by the pipelines. While many of the inland-refined product terminals currently blend ethanol, any revenues the Partnership would receive for blending ethanol might not offset the loss of revenues that would be suffered from the reduced volume transported on the Eastern refined product pipelines.

 

Sunoco has disclosed that new rules under the Clean Air Act affecting fuel specifications may have a significant impact on its operations (primarily with respect to the capital and operating expenditures at Sunoco R&M’s refineries), but that such impact ultimately may be affected by technology selection, timing uncertainties related to construction or permitting schedules, any effect on prices due to changes in the levels of gasoline or diesel production, and other factors. The Partnership cannot assure investors that the impact of these new rules, and Sunoco’s responses to them, will not reduce Sunoco R&M’s obligations under the pipelines and terminals storage and throughput agreement, thereby reducing the throughput in the pipelines and the cash flow.

 

For more information concerning environmental matters, please see Item 1. “Business—Environmental Regulation.”

 

Impact of Inflation

 

Although the impact of inflation has slowed in recent years, it is still a factor in the United States economy and may increase the cost to acquire or replace property, plant, and equipment and may increase the costs of labor and supplies. To the extent permitted by competition, regulation, and existing agreements, the Partnership has and will continue to pass along increased costs to customers in the form of higher fees.

 

Critical Accounting Policies

 

A summary of the Partnership’s significant accounting policies is included in Note 1 to the financial statements included in Item 8 “Financial Statements and Supplementary Data.” Management believes that the application of these policies on a consistent basis enables it to provide the users of the financial statements with useful and reliable information about the Partnership’s operating results and financial condition. The preparation of the Partnership’s financial statements requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosures of contingent assets and

 

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liabilities. Significant items that are subject to such estimates and assumptions include long-lived assets and environmental remediation activities. Although management bases its estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances, actual results may differ from the estimates on which the Partnership’s financial statements are prepared at any given point in time. Despite these inherent limitations, management believes the Partnership’s Management’s Discussion and Analysis and financial statements provide a meaningful and fair perspective of the Partnership. Management has reviewed the estimates affecting its critical accounting policies with the Audit/Conflicts Committee of Sunoco Partners LLC’s Board of Directors.

 

Long-Lived Assets. The cost of properties, plants and equipment, less estimated salvage value, is generally depreciated on a straight-line basis over the estimated useful lives of the assets. Useful lives are based on historical experience and are adjusted when changes in planned use, technological advances or other factors indicate that a different life would be more appropriate. Changes in useful lives that do not result in the impairment of an asset are recognized prospectively. During 2004, the Partnership accelerated the depreciation of certain refined product terminal system assets related to an equipment upgrade program based upon the estimated remaining useful lives of these assets until their replacement. This acceleration resulted in $1.8 million of additional depreciation expense recognized in 2004, and will result in an additional $0.3 million being recognized in 2005 and $0.2 million being recognized in 2006. There have been no other significant changes in the useful lives of the Partnership’s plants and equipment to be recognized prospectively during the 2002-2004 period.

 

Long-lived assets, other than those held for sale, are reviewed for impairment whenever events or circumstances indicate that the carrying amount of the assets may not be recoverable. Such events and circumstances include, among other factors: operating losses; unused capacity; market value declines; technological developments resulting in obsolescence; changes in demand for products manufactured by others utilizing the Partnership’s services or for the Partnership’s products; changes in competition and competitive practices; uncertainties associated with the United States and world economies; changes in the expected level of environmental capital, operating or remediation expenditures; and changes in governmental regulations or actions. Additional factors impacting the economic viability of long-lived assets are described under “Forward Looking Statements”, which can be found after the Table of Contents at the front of this document.

 

A long-lived asset is considered to be impaired when the undiscounted net cash flows expected to be generated by the asset are less than its carrying amount. Such estimated future cash flows are highly subjective and are based on numerous assumptions about future operations and market conditions. The impairment recognized is the amount by which the carrying amount exceeds the fair market value of the impaired asset. It is also difficult to precisely estimate fair market value because quoted market prices for the Partnership’s long-lived assets may not be readily available. Therefore, fair market value is generally based on the present values of estimated future cash flows using discount rates commensurate with the risks associated with the assets being reviewed for impairment.

 

The Partnership had an asset impairment of $6.3 million for the year ended December 31, 2002. There were no asset impairments for the years ended December 31, 2003 and 2004. During 2002, the Partnership recorded a $6.3 million provision to write-down an idled refined product pipeline in the Eastern Pipeline System and a related terminal. These assets were idled as a result of a long-term agreement entered into by the Partnership in December 2002 to lease throughput capacity on a third-party refined product pipeline which allows it to provide substantially the same service as existed on the idled pipeline while reducing operating expenses. These provisions were recorded within depreciation and amortization in the statements of income in the financial statements. For further discussion of these asset impairments, see Note 4 to the financial statements included in Item 8 “Financial Statements and Supplementary Data.”

 

Environmental Remediation. The operation of the Partnership’s pipelines, terminals and associated facilities are subject to numerous federal, state and local laws and regulations which regulate the discharge of materials

 

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into the environment or that otherwise relate to the protection of the environment. As a result of compliance with these laws and regulations, site restoration costs have been and will be incurred in the future at the Partnership’s facilities and properties, including liabilities for environmental remediation obligations.

 

At December 31, 2003 and 2004, the Partnership’s accrual for environmental remediation activities was $0.5 million and $0.8 million, respectively. These accruals are for work at identified sites where an assessment has indicated that cleanup costs are probable and reasonably estimable. The accrual is undiscounted and is based on currently available information, estimated timing of remedial actions and related inflation assumptions, existing technology and presently enacted laws and regulations. It is often extremely difficult to develop reasonable estimates of future site remediation costs due to changing regulations, changing technologies and their associated costs, and changes in the economic environment. In the above instances, if a range of probable environmental cleanup costs exists for an identified site, FASB Interpretation No. 14, “Reasonable Estimation of the Amount of a Loss” requires that the minimum of the range be accrued unless some other point or points in the range are more likely, in which case the most likely amount in the range is accrued. Engineering studies, historical experience and other factors are used to identify and evaluate remediation alternatives and their related costs in determining the estimated accruals for environmental remediation activities. Losses attributable to unasserted claims are also reflected in the accruals to the extent their occurrence is probable and reasonably estimable.

 

Management believes that none of the current remediation locations are material, individually or in the aggregate, to the Partnership’s financial position at December 31, 2004. As a result, the Partnership’s exposure to adverse developments with respect to any individual site is not expected to be material. However, if changes in environmental regulations occur, such changes could impact several of the Partnership’s facilities. As a result, from time to time, significant charges against income for environmental remediation may occur.

 

Under the terms of the Omnibus Agreement and in connection with the contribution of the Predecessor to the Partnership by affiliates of Sunoco, Sunoco has retained these liabilities in connection with its agreement to indemnify the Partnership for 30 years from environmental and toxic tort liabilities related to the assets contributed that arise from the operation of such assets prior to closing of the February 2002 IPO. Sunoco is obligated to indemnify the Partnership for 100 percent of all losses asserted within the first 21 years of closing of the February 2002 IPO. Sunoco’s share of liability for claims asserted thereafter will decrease by 10 percent a year. For example, for a claim asserted during the twenty-third year after closing of the February 2002 IPO, Sunoco would be required to indemnify the Partnership for 80 percent of the loss. There is no monetary cap on the amount of indemnity coverage provided by Sunoco. Any environmental and toxic tort liabilities not covered by this indemnity will be the Partnership’s responsibility. The Partnership has agreed to indemnify Sunoco and its affiliates for events and conditions associated with the operation of the assets that occur on or after the closing of the February 2002 IPO and for environmental and toxic tort liabilities to the extent Sunoco is not required to indemnify the Partnership.

 

In summary, total future costs for environmental remediation activities will depend upon, among other things, the identification of any additional sites, the determination of the extent of the contamination at each site, the timing and nature of required remedial actions, the technology available and needed to meet the various existing legal requirements, the nature and terms of cost sharing arrangements with other potentially responsible parties and the nature and extent of future environmental laws, inflation rates and the determination of the Partnership’s liability at the sites, if any, in the light of the number, participation level and financial viability of other parties.

 

New Accounting Pronouncements

 

In December 2004, Statement of Financial Accounting Standards No. 123 (revised 2004), “Share-Based Payment” (“SFAS No. 123R”) was issued, which revised Statement of Financial Accounting Standards No. 123, “Accounting for Stock-Based Compensation” (“SFAS No. 123”). Among other things, SFAS No. 123R requires

 

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a fair-value-based method of accounting for share-based payment transactions, effective for interim periods beginning after June 15, 2005. As the Partnership currently follows the fair value method of accounting prescribed by SFAS No. 123, adoption of SFAS No. 123R is not expected to have a significant impact on the Partnership’s financial statements.

 

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

 

The Partnership is exposed to various market risks, including volatility in crude oil commodity prices and interest rates. To manage such exposure, inventory levels and expectations of future commodity prices and interest rates are monitored when making decisions with respect to risk management. The Partnership has not entered into derivative transactions that would expose it to price risk.

 

The $250 million Credit Facility, with outstanding borrowings at December 31, 2004 of $64.5 million, exposes the Partnership to interest rate risk, since it bears interest at a variable rate (2.94 percent at December 31, 2004). A one percent change in interest rates changes annual interest expense by approximately $645,000.

 

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

 

MANAGEMENT’S REPORT ON INTERNAL CONTROL

OVER FINANCIAL REPORTING

 

Management of Sunoco Logistics Partners L.P. (the “Partnership”) is responsible for establishing and maintaining adequate internal control over financial reporting, as defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934, as amended. The Partnership’s internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements in accordance with generally accepted accounting principles.

 

The Partnership’s management assessed the effectiveness of the Partnership’s internal control over financial reporting as of December 31, 2004. In making this assessment, the Partnership’s management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”) in Internal Control—Integrated Framework.

 

Based on this assessment, management believes that, as of December 31, 2004, the Partnership’s internal control over financial reporting is effective based on those criteria. Ernst & Young LLP, an independent registered public accounting firm, has issued an attestation report on management’s assessment of the Partnership’s internal control over financial reporting, which appears in this section.

 

Deborah M. Fretz

President and Chief Executive Officer

 

Colin A. Oerton

Vice President and Chief Financial Officer

 

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

ON INTERNAL CONTROL OVER FINANCIAL REPORTING

 

To the Board of Directors of

Sunoco Partners LLC:

 

We have audited management’s assessment, included in the accompanying Management’s Report on Internal Control over Financial Reporting, that Sunoco Logistics Partners L.P. (the “Partnership”) maintained effective internal control over financial reporting as of December 31, 2004, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (the COSO criteria). The Partnership’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting. Our responsibility is to express an opinion on management’s assessment and an opinion on the effectiveness of the Partnership’s internal control over financial reporting based on our audit.

 

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, evaluating management’s assessment, testing and evaluating the design and operating effectiveness of internal control, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

 

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

 

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

 

In our opinion, management’s assessment that the Partnership maintained effective internal control over financial reporting as of December 31, 2004, is fairly stated, in all material respects, based on the COSO criteria. Also, in our opinion, the Partnership maintained, in all material respects, effective internal control over financial reporting as of December 31, 2004, based on the COSO criteria.

 

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the 2004 financial statements of the Partnership and our report dated March 2, 2005 expressed an unqualified opinion thereon.

 

ERNST & YOUNG LLP

 

Philadelphia, Pennsylvania

March 2, 2005

 

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Table of Contents

REPORT OF INDEPENDENT REGISTERED

PUBLIC ACCOUNTING FIRM ON FINANCIAL STATEMENTS

 

To the Board of Directors of

Sunoco Partners LLC:

 

We have audited the accompanying balance sheets of Sunoco Logistics Partners L.P. (the “Partnership”) as of December 31, 2003 and 2004 and the related statements of income and partners’ capital/net parent investment and cash flows for each of the three years in the period ended December 31, 2004. These financial statements are the responsibility of the Partnership’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

 

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (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 financial position of Sunoco Logistics Partners L.P. at December 31, 2003 and 2004 and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2004, in conformity with U.S. generally accepted accounting principles.

 

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the effectiveness of the Partnership’s internal control over financial reporting as of December 31, 2004, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated March 2, 2005 expressed an unqualified opinion thereon.

 

ERNST & YOUNG LLP

 

Philadelphia, Pennsylvania

March 2, 2005

 

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SUNOCO LOGISTICS PARTNERS L.P.

 

STATEMENTS OF INCOME

(in thousands, except units and per unit amounts)

 

    Partnership
and
Predecessor


    Partnership

 
    Year Ended December 31,

 
    2002

    2003

    2004

 

Revenues

                       

Sales and other operating revenue:

                       

Affiliates (Note 3)

  $ 1,147,721     $ 1,383,090     $ 1,751,612  

Unaffiliated customers

    676,307       1,274,383       1,699,673  

Other income

    6,904       16,730       13,932  
   


 


 


Total Revenues

    1,830,932       2,674,203       3,465,217  
   


 


 


Costs and Expenses

                       

Cost of products sold and operating expenses

    1,690,896       2,519,160       3,307,480  

Depreciation and amortization (Note 4)

    31,334       27,157       31,933  

Selling, general and administrative expenses

    43,073       48,412       48,449  
   


 


 


Total Costs and Expenses

    1,765,303       2,594,729       3,387,862  
   


 


 


Operating Income

    65,629       79,474       77,355  

Net interest cost paid to affiliates (Note 3)

    1,205       15       439  

Other interest cost and debt expense, net

    17,390       20,518       19,885  

Capitalized interest

    (1,296 )     (493 )     —    
   


 


 


Income before income tax expense

    48,330       59,434       57,031  

Income tax expense (Note 5)

    1,555       —         —    
   


 


 


Net Income

  $ 46,775     $ 59,434     $ 57,031  
   


 


 


Allocation of 2002 Net Income:

                       

Portion applicable to January 1 through February 7, 2002 (period prior to initial public offering)

  $ 3,421                  

Portion applicable to February 8 through December 31, 2002

    43,354                  
   


               

Net Income

  $ 46,775                  
   


               

Calculation of Limited Partners’ interest in Net Income:

                       

Net Income

  $ 43,354     $ 59,434     $ 57,031  

Less: General Partner’s interest in Net Income

    (867 )     (1,423 )     (2,828 )
   


 


 


Limited Partners’ interest in Net Income

  $ 42,487     $ 58,011     $ 54,203  
   


 


 


Net Income per Limited Partner unit (2002 is for the period from February 8, 2002 through December 31, 2002):

                       

Basic

  $ 1.87     $ 2.55     $ 2.29  
   


 


 


Diluted

  $ 1.86     $ 2.53     $ 2.27  
   


 


 


Weighted average Limited Partners’ units outstanding (Note 6):

                       

Basic

    22,767,899       22,771,793       23,666,211  
   


 


 


Diluted

    22,785,407       22,894,520       23,907,151  
   


 


 


 

(See Accompanying Notes)

 

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SUNOCO LOGISTICS PARTNERS L.P.

 

BALANCE SHEETS

(in thousands)

 

     Partnership

     December 31,

     2003

   2004

Assets

             

Current Assets

             

Cash and cash equivalents

   $ 50,081    $ 52,660

Advances to affiliates (Note 3)

     7,288      12,349

Accounts receivable, affiliated companies (Note 3)

     116,936      140,328

Accounts receivable, net

     302,235      396,479

Inventories (Note 7)

     27,268      27,128
    

  

Total Current Assets

     503,808      628,944

Properties, plants and equipment, net (Note 8)

     583,164      647,200

Investment in affiliates (Note 9)

     70,490      69,745

Deferred charges and other assets

     23,544      22,897
    

  

Total Assets

   $ 1,181,006    $ 1,368,786
    

  

Liabilities and Partners’ Capital

             

Current Liabilities

             

Accounts payable

   $ 426,863    $ 553,629

Accrued liabilities

     24,937      25,284

Accrued taxes other than income

     11,312      15,162
    

  

Total Current Liabilities

     463,112      594,075

Long-term debt (Note 10)

     313,136      313,305

Other deferred credits and liabilities

     1,000      812

Commitments and contingent liabilities (Note 11)

             
    

  

Total Liabilities

     777,248      908,192
    

  

Partners’ Capital:

             

Limited partners’ interest

     397,479      452,856

General partner’s interest

     6,279      7,738
    

  

Total Partners’ Capital

     403,758      460,594
    

  

Total Liabilities and Partners’ Capital

   $ 1,181,006    $ 1,368,786
    

  

 

(See Accompanying Notes)

 

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SUNOCO LOGISTICS PARTNERS L.P.

 

STATEMENTS OF CASH FLOWS

(in thousands)

 

     Partnership
and
Predecessor


    Partnership

 
     Year Ended December 31,

 
     2002

    2003

    2004

 

Cash Flows from Operating Activities:

                        

Net Income

   $ 46,775     $ 59,434     $ 57,031  

Adjustments to reconcile net income to net cash provided by operating activities:

                        

Depreciation and amortization

     31,334       27,157       31,933  

Deferred income tax expense

     675       —         —    

Gain on claim settlement

     —         (1,175 )     —    

Restricted unit incentive plan expense

     683       2,204       3,204  

Changes in working capital pertaining to operating activities:

                        

Accounts receivable, affiliated companies

     (99,221 )     (11,470 )     (23,392 )

Accounts receivable, net

     (102,253 )     (51,164 )     (94,244 )

Inventories

     (12,127 )     (1,524 )     140  

Accounts payable and accrued liabilities

     134,561       69,408       127,113  

Accrued taxes other than income

     4,972       39       3,850  

Other

     (3,188 )     4,303       987  
    


 


 


Net cash provided by operating activities

     2,211       97,212       106,622  
    


 


 


Cash Flows from Investing Activities:

                        

Capital expenditures

     (40,782 )     (37,377 )     (46,418 )

Acquisitions

     (64,491 )     (3,699 )     (49,165 )

Collection of loan from affiliate

     20,000       —         —    

Net proceeds from claim settlement

     —         2,068       —    
    


 


 


Net cash used in investing activities

     (85,273 )     (39,008 )     (95,583 )
    


 


 


Cash Flows from Financing Activities:

                        

Distributions paid to Limited Partners and General Partner

     (26,949 )     (46,227 )     (57,483 )

Net proceeds from issuance of Limited Partner units

     96,468       —         128,738  

Redemption of Limited Partner units from Sunoco

     —         —         (82,690 )

Net contribution from General Partner for Limited Partner unit transactions

     —         —         989  

Advances to affiliates, net

     (10,716 )     3,428       (5,061 )

Borrowings under credit facility

     64,500       —         64,500  

Repayments under credit facility

     —         —         (64,500 )

Repayments of long-term debt

     (303 )     (4,478 )     —    

Repayments of long-term debt to affiliate

     (50,000 )     —         —    

Net proceeds from issuance of long-term debt

     244,788       —         —    

Special distribution to affiliate

     (244,788 )     —         —    

Contributions from affiliate

     43,902       5,314       7,047  
    


 


 


Net cash provided by/(used in) financing activities

     116,902       (41,963 )     (8,460 )
    


 


 


Net change in cash and cash equivalents

     33,840       16,241       2,579  

Cash and cash equivalents at beginning of year

     —         33,840       50,081  
    


 


 


Cash and cash equivalents at end of year

   $ 33,840     $ 50,081     $ 52,660  
    


 


 


 

(See Accompanying Notes)

 

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SUNOCO LOGISTICS PARTNERS L.P.

 

STATEMENTS OF PARTNERS’ CAPITAL/NET PARENT INVESTMENT

(in thousands)

 

          Partners’ Capital

   

Total
Partners’
Capital/

Net Parent
Investment


 
   

Net

Parent
Investment


    Limited Partners

    General
Partner


   
      Common

    Subordinated

     
    $

    Units

    $

    Units

  $

    $

    $

 

Balance at January 1, 2002

  $ 274,893     —       $ —       —     $ —       $ —       $ 274,893  

Net income applicable to the period from January 1 through February 7, 2002

    3,421     —         —       —       —         —         3,421  

Contribution from affiliate

    40,217     —         —       —       —         —         40,217  

Adjustment to reflect net liabilities not contributed by affiliate to the Partnership (Note 12)

    190,887     —         —       —       —         —         190,887  

Special distribution to affiliate

    (244,788 )   —         —       —       —         —         (244,788 )
   


 

 


 
 


 


 


Net assets contributed by affiliate

    264,630     —         —       —       —         —         264,630  

Allocation of net assets contributed by affiliate

    (264,630 )   5,634       85,855     11,384     173,482       5,293       —    

Issuance of Limited Partner units to the public (Note 2)

    —       5,750       96,468     —       —         —         96,468  

Issuance of Limited Partner units to affiliate in partial consideration for West Texas Gulf Acquisition (Note 14)

    —       4       100     —       —         2       102  

Contribution from affiliate (Note 3)

    —       —         1,539     —       3,111       95       4,745  

Unissued units under incentive plans (Note 13)

    —       —         683     —       —         —         683  

Net income applicable to the period from February 8 through December 31, 2002

    —       —         21,248     —       21,239       867       43,354  

Cash distributions

    —       —         (13,205 )   —       (13,205 )     (539 )     (26,949 )
   


 

 


 
 


 


 


Balance at December 31, 2002

  $ —       11,388     $ 192,688     11,384   $ 184,627     $ 5,718     $ 383,033  

Contribution from affiliate

    —       —         1,726     —       3,482       106       5,314  

Unissued units under incentive plans (Note 13)

    —       —         2,204     —       —         —         2,204  

Net income

    —       —         29,011     —       29,000       1,423       59,434  

Cash distributions

    —       —         (22,634 )   —       (22,625 )     (968 )     (46,227 )
   


 

 


 
 


 


 


Balance at December 31, 2003

  $ —       11,388     $ 202,995     11,384   $ 194,484     $ 6,279     $ 403,758  

Issuance of Limited Partner units to the public (Note 2)

    —       3,400       128,738     —       —         2,759       131,497  

Redemption of Limited Partner units from affiliate (Note 2)

    —       (2,183 )     (82,690 )   —       —         (1,770 )     (84,460 )

Contribution from affiliate

    —       —         1,608     —       5,298       141       7,047  

Unissued units under incentive plans (Note 13)

    —       —         3,204     —       —         —         3,204  

Net income

    —       —         28,149     —       26,054       2,828       57,031  

Cash distributions

    —       —         (28,574 )   —       (26,410 )     (2,499 )     (57,483 )
   


 

 


 
 


 


 


Balance at December 31, 2004

  $ —       12,605     $ 253,430     11,384   $ 199,426     $ 7,738     $ 460,594  
   


 

 


 
 


 


 


(See Accompanying Notes)

 

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SUNOCO LOGISTICS PARTNERS L.P.

 

NOTES TO FINANCIAL STATEMENTS

 

1. Summary of Significant Accounting Policies

 

Basis of Presentation and Principles of Combination/Consolidation

 

Sunoco Logistics Partners L.P. (the “Partnership”) is a Delaware limited partnership formed by Sunoco, Inc. in October 2001 to acquire, own and operate a substantial portion of Sunoco, Inc.’s logistics business, consisting of refined product pipelines, terminalling and storage assets, crude oil pipelines, and crude oil acquisition and marketing assets located in the Northeast, Midwest and South Central United States (collectively, “Sunoco Logistics (Predecessor)” or the “Predecessor”).

 

The accompanying financial statements reflect the historical cost-basis accounts of the Predecessor for periods prior to February 8, 2002, the closing date of the Partnership’s initial public offering (the “IPO”—see Note 2), and include charges from Sunoco, Inc. and its subsidiaries (collectively, “Sunoco”) for direct costs and allocations of indirect corporate overhead. Management of the Partnership believes that the allocation methods are reasonable, and that the allocations are representative of the costs that would have been incurred on a stand-alone basis. Beginning on February 8, 2002, the financial statements reflect the consolidated financial statements of the Partnership and its subsidiaries. Equity ownership interests in corporate joint ventures, which are not consolidated, are accounted for under the equity method.

 

Description of Business

 

Most of the assets of the Partnership support Sunoco refining and marketing operations which are conducted primarily by Sunoco, Inc. (R&M) (“Sunoco R&M”). The Partnership operates in three principal business segments: Eastern Pipeline System, Terminal Facilities and Western Pipeline System.

 

The Eastern Pipeline System transports refined products in the Northeast and Midwest largely for Sunoco R&M’s Philadelphia, PA, Marcus Hook, PA, Toledo, OH and Eagle Point, NJ refineries and crude oil on a pipeline in Ohio and Michigan that supplies both Sunoco R&M’s Toledo refinery and third-party refineries. This segment also includes an interrefinery pipeline between Sunoco R&M’s Marcus Hook and Philadelphia refineries and equity ownership interests in the following refined product pipeline companies: 9.4 percent of Explorer Pipeline Company (“Explorer”), 31.5 percent of Wolverine Pipe Line Company (“Wolverine”), 12.3 percent of West Shore Pipe Line Company (“West Shore”), and 14.0 percent of Yellowstone Pipe Line Company (“Yellowstone”) (see Note 14).

 

The Terminal Facilities segment includes a network of 35 refined product terminals in the Northeast and Midwest that distribute products primarily to Sunoco R&M’s retail outlets, a 12.5 million-barrel marine crude oil terminal on the Texas Gulf Coast and a one million barrel liquefied petroleum gas (“LPG”) storage facility near Detroit, MI. This segment also owns and operates one inland and two marine crude oil terminals and the related storage facilities and pipelines that supply all of the crude oil processed by Sunoco R&M’s Philadelphia refinery and a two million barrel refined product storage terminal in Marcus Hook, PA that is used by Sunoco R&M’s Marcus Hook refinery to source barrels to the Partnership’s pipelines. Finally, this segment includes a ship and barge dock which serves Sunoco R&M’s Eagle Point refinery which was acquired in March 2004 (see Note 14).

 

The Western Pipeline System acquires, transports and markets crude oil principally in Oklahoma and Texas for Sunoco R&M’s Tulsa, OK and Toledo, OH refineries and also for other customers. This segment also includes a 43.8 percent equity ownership interest in West Texas Gulf Pipe Line Company (“West Texas Gulf”), a crude oil pipeline company located in Texas (see Note 14).

 

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SUNOCO LOGISTICS PARTNERS L.P.

 

NOTES TO FINANCIAL STATEMENTS—(Continued)

 

Use of Estimates

 

The preparation of financial statements in conformity with U.S. generally accepted accounting principles requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. Actual amounts could differ from these estimates.

 

Revenue Recognition

 

Crude oil gathering and marketing revenues are recognized when title to the crude oil is transferred to the customer. Revenues are not recognized for crude oil exchange transactions, which are entered into primarily to acquire crude oil of a desired quality or to reduce transportation costs by taking delivery closer to the Partnership’s end markets. Any net differential for exchange transactions is recorded as an adjustment of inventory costs in the purchases component of cost of products sold and operating expenses in the statements of income based upon the concepts set forth in APB Opinion No. 29, “Accounting for Nonmonetary Transactions.” The Emerging Issues Task Force (the “EITF”) is currently considering the appropriate reporting for exchange transactions in Issue 04-13, “Accounting for Purchases and Sales of Inventory with the Same Counterparty.” In the event the EITF requires reporting on a gross basis, the Partnership’s sales and other operating revenue and cost of products sold and operating expenses would reflect corresponding increases. Terminalling and storage revenues are recognized at the time the services are provided. Pipeline revenues are recognized upon delivery of the barrels to the location designated by the shipper.

 

Affiliated revenues consist of sales of crude oil as well as the provision of crude oil and refined product pipeline transportation, terminalling and storage services to Sunoco R&M. Sales of crude oil to affiliates are computed using the formula-based pricing mechanism of a supply agreement with Sunoco R&M. Management of the Partnership believes these terms to be comparable to those that could be negotiated with an unrelated third party. Pipeline revenues from affiliates are generally determined using posted tariffs. Prior to January 1, 2002, affiliated revenues from terminalling and storage were generally equal to all of the costs incurred for these activities, including operating, maintenance and environmental remediation expenditures. Concurrent with the closing of the February 2002 IPO, the Partnership entered into a pipelines and terminals storage and throughput agreement with Sunoco R&M under which the Partnership is charging Sunoco R&M fees for services provided under these agreements comparable to those charged in arm’s-length, third-party transactions. Under the pipelines and terminals storage and throughput agreement, Sunoco R&M has agreed to pay the Partnership a minimum level of revenue for transporting and terminalling refined products. Sunoco R&M also has agreed to minimum throughputs of refined products and crude oil in the Partnership’s Inkster Terminal, Fort Mifflin Terminal Complex, Marcus Hook Tank Farm and certain crude oil pipelines. Fee arrangements consistent with this contract, generally effective January 1, 2002, were used as the basis for the transfer prices used in the preparation of Sunoco’s segment information. Accordingly, such fees are generally reflected in the financial statements beginning on January 1, 2002.

 

Cash Equivalents

 

The Partnership considers all highly liquid investments with a remaining maturity of three months or less at the time of purchase to be cash equivalents. These cash equivalents consist principally of money market accounts.

 

Accounts Receivable, net

 

Accounts receivable represent valid claims against non-affiliated customers (see Note 3 for affiliated receivables) for products sold or services rendered. The Partnership extends credit terms to certain customers

 

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SUNOCO LOGISTICS PARTNERS L.P.

 

NOTES TO FINANCIAL STATEMENTS—(Continued)

 

after review of various credit indicators, including the customer’s credit rating. Outstanding customer receivable balances are regularly reviewed for possible non-payment indicators and reserves are recorded for doubtful accounts based upon management’s estimate of collectibility at the time of review. The following table provides the activity in the allowance for doubtful accounts for the three-year period ended December 31, 2004:

 

    

Partnership

and

Predecessor


   Partnership

 
     2002

   2003

   2004

 

Balance at January 1

   $ —      $ 500    $ 500  

Amounts charged to expense

     500      —        —    

Deductions

     —        —        (500 )
    

  

  


Balance at December 31

   $ 500    $ 500    $ —    
    

  

  


 

Inventories

 

Inventories are valued at the lower of cost or market. Crude oil inventory cost has been determined using the last-in, first-out method (“LIFO”). Under this methodology, the cost of products sold consists of the actual crude oil acquisition costs of the Partnership. Such costs are adjusted to reflect increases or decreases in crude oil inventory quantities, which are valued based on the changes in the LIFO inventory layers. Prior to February 8, 2002, the IPO date, crude oil inventory amounts reflected an allocation to the Predecessor by Sunoco R&M of the Predecessor’s share of Sunoco R&M’s crude oil inventory, the cost of which has been determined under the LIFO method. The cost of materials, supplies and other inventories is determined using principally the average cost method.

 

Properties, Plants and Equipment

 

Properties, plants and equipment are stated at cost. Additions to properties, plants and equipment, including replacements and improvements, are recorded at cost. Repair and maintenance expenditures are charged to expense as incurred. Depreciation is provided principally using the straight-line method based on the estimated useful lives of the related assets. For certain interstate pipelines, the depreciation rate is applied to the net asset value based on FERC requirements. When FERC-regulated properties, plants and equipment are retired or otherwise disposed of, the cost less net proceeds is charged to accumulated depreciation and amortization, except that gains and losses for those groups are reflected in other income in the statements of income for unusual disposals. Gains and losses on the disposal of non-FERC properties, plants and equipment are reflected in other income in the statements of income.

 

During 2004, the Partnership accelerated the depreciation of certain refined product terminal system assets related to an equipment upgrade program based upon the estimated remaining useful lives of these assets until their replacement. This acceleration resulted in $1.8 million of additional depreciation expense recognized in 2004, and will result in an additional $0.3 million being recognized in 2005 and $0.2 million being recognized in 2006.

 

Capitalized Interest

 

The Partnership capitalizes interest on borrowed funds related to capital projects only for periods that activities are in progress to bring these projects to their intended use. The weighted average rate used to capitalize interest on borrowed funds was 7.3 percent for 2002 and 2003. During the years ended December 31,

 

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SUNOCO LOGISTICS PARTNERS L.P.

 

NOTES TO FINANCIAL STATEMENTS—(Continued)

 

2002 and 2003, the amount of interest capitalized was $1.3 million and $0.5 million, respectively. There were no amounts capitalized for 2004.

 

Impairment of Long-Lived Assets

 

Long-lived assets other than those held for sale are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. An asset is considered to be impaired when the undiscounted estimated net cash flows expected to be generated by the asset are less than its carrying amount. The impairment recognized is the amount by which the carrying amount exceeds the fair market value of the impaired asset. Long-lived assets held for sale are recorded at the lower of their carrying amount or fair market value less cost to sell the assets.

 

Goodwill and Other Intangible Assets

 

Goodwill, which represents the excess of the purchase price over fair value of net assets acquired, is presented net of accumulated amortization within deferred charges and other assets on the balance sheets. At December 31, 2003 and 2004, the Partnership had $16.2 million of unamortized goodwill. Goodwill and indefinite-lived intangible assets are tested for impairment at least annually. The Partnership determined during 2002, 2003 and 2004 that such assets were not impaired.

 

Deferred financing fees of $2.7 million, net of accumulated amortization of $1.0 million, as of December 31, 2003 and $2.6 million, net of accumulated amortization of $0.8 million, as of December 31, 2004 have been included within deferred charges and other assets on the balance sheets. Amortization expense of $0.4 million, $0.6 million and $0.7 million for the years ended December 31, 2002, 2003 and 2004, respectively, has been included within other interest cost and debt expense on the statements of income. The Partnership amortizes deferred financing fees over the life of the respective debt agreement.

 

Investment in Affiliates

 

Investments in affiliates, which consist of corporate joint ventures, are accounted for under the equity method of accounting as required by Accounting Principles Board Opinion 18, “The Equity Method of Accounting for Investments in Common Stock” (“APB 18”). Under this method, an investment is carried at acquisition cost, increased for the equity in income or decreased for the equity in loss from the date of acquisition, and reduced for dividends received. The Partnership had $0.7 million of undistributed earnings from its investments in corporate joint ventures within Partners’ Capital on its December 31, 2004 balance sheet.

 

The Partnership allocates its excess investment cost over its equity in the net assets of affiliates to the underlying tangible and intangible assets of the corporate joint ventures. Other than land and indefinite-lived intangible assets, all amounts allocated, principally to pipeline and related assets, were amortized using the straight-line method over their estimated useful life of 40 years. The amortization of these amounts are included within depreciation and amortization in the statements of income.

 

Environmental Remediation

 

The Partnership accrues environmental remediation costs for work at identified sites where an assessment has indicated that cleanup costs are probable and reasonably estimable. Such accruals are undiscounted and are based on currently available information, estimated timing of remedial actions and related inflation assumptions, existing technology and presently enacted laws and regulations. If a range of probable environmental cleanup

 

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costs exists for an identified site, the minimum of the range is accrued unless some other point or points in the range are more likely, in which case the most likely amount in this range is accrued.

 

Income Taxes

 

For the period prior to the IPO, the Predecessor was included in the consolidated federal income tax return filed by Sunoco. However, the provision for federal income taxes included in the statement of income for the year ended December 31, 2002 was determined on a separate-return basis. Any current federal income tax amounts due on a separate-return basis were settled with Sunoco through the net parent investment account. Effective upon the closing date of the IPO, substantially all income taxes are the responsibility of the unitholders and not the Partnership.

 

Long-Term Incentive Plan

 

In December 2004, Statement of Financial Accounting Standards No. 123 (revised 2004), “Share-Based Payment” (“SFAS No. 123R”) was issued, which revised Statement of Financial Accounting Standards No. 123, “Accounting for Stock-Based Compensation” (“SFAS No. 123”). Among other things, SFAS No. 123R requires a fair-value-based method of accounting for share-based payment transactions, effective for interim periods beginning after June 15, 2005. As the Partnership currently follows the fair value method of accounting prescribed by SFAS No. 123, adoption of SFAS No. 123R is not expected to have a significant impact on the Partnership’s financial statements.

 

Asset Retirement Obligations

 

Effective January 1, 2003, the Partnership adopted the provisions of Statement of Financial Accounting Standards No. 143, “Accounting for Asset Retirement Obligations” (“SFAS No. 143”). This statement significantly changed the method of accruing for costs that an entity is legally obligated to incur associated with the retirement of fixed assets. Under SFAS No. 143, the fair value of a liability for an asset retirement obligation is recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. The associated asset retirement costs are capitalized as part of the carrying amount of the fixed asset and depreciated over its estimated useful life. Prior to January 1, 2003, a liability for an asset retirement obligation was recognized using a cost-accumulation measurement approach. The cumulative effect of this accounting change for years prior to 2003 of $0.4 million was included in cost of products sold and operating expenses in the statement of income for the year ended December 31, 2003. The Partnership did not reflect the amount as a cumulative effect of an accounting change as it was not material to the financial statements. This change did not otherwise have a significant impact on the Partnership’s statement of income for the year ended December 31, 2003. At December 31, 2004, the Partnership’s liability for asset retirement obligations was $0.7 million. The Partnership has legal asset retirement obligations for several other assets, including certain pipelines and terminals, for which it is not possible to estimate the time period when the obligations will be settled. Consequently, the fair value of the retirement obligations for these assets cannot be measured and recognized at this time.

 

Lease Accounting

 

Effective July 1, 2003, the Partnership adopted the provisions of Emerging Issues Task Force Issue 01-8, “Determining Whether an Arrangement Contains a Lease” (“EITF 01-8”). EITF 01-8 provides guidance in determining whether an arrangement meets the definition of a lease under the provisions of Statement of Financial Accounting Standards No. 13, “Accounting for Leases” (“SFAS No. 13”). SFAS No. 13 defines a lease

 

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as an agreement conveying the right to use property, plant or equipment for a stated period of time. EITF 01-8 provides criteria to determine whether an arrangement conveys the right to use property, plant and equipment under SFAS No. 13. The accounting requirements under EITF 01-8 could affect an arrangement’s timing of revenue and expense recognition, and revenues reported as transportation and storage services might have to be reported as rental or leasing income. The provisions of EITF 01-8 are to be applied prospectively to arrangements agreed to, modified, or acquired in business combinations after July 1, 2003. Previous arrangements that would be leases or would contain a lease according to this pronouncement will continue to be recorded in accordance with their prior accounting treatment. The Partnership is continually analyzing its agreements that were in existence prior to July 1, 2003 to determine if the accounting for these agreements would be impacted upon renewal or amendment. The provisions of EITF 01-8 had no material impact on the Partnership’s financial statements for the years ended December 31, 2003 and 2004.

 

Reclassifications

 

Certain amounts in the prior years’ financial statements have been reclassified to conform to the current year presentation.

 

2. Equity Offerings

 

On February 8, 2002, Sunoco, through its subsidiary, Sunoco Partners LLC, the general partner of the Partnership, contributed the Predecessor to the Partnership in exchange for: (i) a 2 percent general partner interest in the Partnership; (ii) incentive distribution rights (as defined in the Partnership Agreement); (iii) 5,633,639 common units; (iv) 11,383,639 subordinated units; and (v) a special interest representing the right to receive from the Partnership, on the closing of the IPO, the net proceeds from the issuance of $250 million of ten-year senior notes (the “Senior Notes”) by Sunoco Logistics Partners Operations L.P., a wholly-owned entity of the Partnership (the “Operating Partnership”), which totaled $244.8 million. The Partnership concurrently issued 5,750,000 common units (including 750,000 units issued pursuant to the underwriters’ over-allotment option), representing a 24.8 percent limited partnership interest in the Partnership, in an IPO at a price of $20.25 per unit. Proceeds from the IPO, which totaled $96.5 million net of underwriting discounts and offering expenses, were used by the Partnership to replace working capital that was not contributed to the Partnership by Sunoco.

 

On April 7, 2004, the Partnership sold 3.4 million common units in a public offering for total gross proceeds of $135.1 million. The units were issued under the Partnership’s previously filed Form S-3 shelf registration statement. The sale of the units resulted in net proceeds of $128.7 million, after underwriters’ commissions and legal, accounting, and other transaction expenses. Net proceeds from the sale were used to (a) redeem approximately 2.2 million common units from Sunoco for $82.7 million, (b) replenish cash utilized to acquire the Eagle Point logistics assets for $20.0 million, (c) finance the acquisition of two refined product terminals for $12.0 million, (d) finance the acquisition of an additional 33.3 percent undivided interest in the Harbor pipeline for $7.3 million, and (e) for general partnership purposes, including to replenish cash used for past acquisitions and capital improvements, and for other expansion, capital improvements or acquisition projects. As a result of this net issuance of 1.2 million common units, the Partnership also received $1.0 million from its general partner as a capital contribution to maintain its 2.0 percent general partner interest. After the redemption of its units, Sunoco’s ownership interest in the Partnership decreased from 75.3 percent to 62.6 percent, including its 2.0 percent general partner interest.

 

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3. Related Party Transactions

 

Prior to the IPO, substantially all of the related party transactions discussed below were settled immediately through the net parent investment account. Subsequent to the IPO, normal trade terms apply to transactions with Sunoco as described in various agreements discussed below which were entered into concurrent with the IPO.

 

Advances to Affiliate

 

The Partnership has a treasury services agreement with Sunoco pursuant to which it, among other things, participates in Sunoco’s centralized cash management program. Under this program, all of the Partnership’s cash receipts and cash disbursements are processed, together with those of Sunoco and its other subsidiaries, through Sunoco’s cash accounts with a corresponding credit or charge to an intercompany account. The intercompany balances are settled periodically, but no less frequently than monthly. Amounts due from Sunoco earn interest at a rate equal to the average rate of the Partnership’s third-party money market investments, while amounts due to Sunoco bear interest at a rate equal to the interest rate provided in the Partnership’s revolving credit facility (see Note 10).

 

Selling, general and administrative expenses in the statements of income include costs incurred by Sunoco for the provision of centralized corporate functions such as legal, accounting, treasury, engineering, information technology, insurance and other corporate services. Prior to the closing of the February 2002 IPO, such expenses were based on amounts negotiated between the parties, which approximated Sunoco’s cost of providing such services. Under an omnibus agreement (“Omnibus Agreement”) with Sunoco that the Partnership entered into at the closing of the IPO, Sunoco provided these centralized corporate functions for three years for an annual administrative fee, which was increased annually by the lesser of 2.5 percent or the consumer price index for the applicable year. The fee for the annual period ended December 31, 2004 was $8.4 million. In January 2005, both parties agreed to extend this provision of the Omnibus Agreement for a one-year term for an annual fee of $8.4 million. These costs were also subject to increase if the Partnership consummated an acquisition or constructed additional assets that required an increase in the level of general and administrative services received by the Partnership from the general partner or Sunoco. The annual fee includes expenses incurred by Sunoco to perform the centralized corporate functions described above. This fee did not include the costs of shared insurance programs, which were allocated to the Partnership based upon its share of the cash premiums incurred. This fee also did not include salaries of pipeline and terminal personnel or other employees of the general partner, including senior executives, or the cost of their employee benefits. The Partnership reimbursed Sunoco for these costs and other direct expenses incurred on the Partnership’s behalf. Selling, general and administrative expenses in the statements of income include costs related to the provision of these centralized corporate functions and allocation of shared insurance costs of $10.2 million, $10.9 million and $10.9 million for the years ended December 31, 2002, 2003 and 2004, respectively.

 

The Partnership entered into a license agreement at the closing of the IPO with Sunoco and certain of its affiliates, including its general partner, Sunoco Partners LLC, pursuant to which the Partnership granted to Sunoco Partners LLC a license to the Partnership’s intellectual property so that Sunoco Partners LLC can manage the Partnership’s operations and create intellectual property using the Partnership’s intellectual property. Sunoco Partners LLC will assign to the Partnership the new intellectual property it creates in operating the Partnership’s business. Sunoco Partners LLC has also licensed to the Partnership certain of its own intellectual property for use in the conduct of the Partnership’s business and the Partnership licensed to Sunoco Partners LLC certain of the Partnership’s intellectual property for use in the conduct of its business. The license agreement also grants to the Partnership a license to use the trademarks, trade names, and service marks of Sunoco in the conduct of the Partnership’s business.

 

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Allocated Sunoco employee benefit plan expenses for employees who work in the pipeline, terminalling, storage and crude oil gathering operations, including senior executives, include non-contributory defined benefit retirement plans, defined contribution 401(k) plans, employee and retiree medical, dental and life insurance plans, incentive compensation plans and other such benefits. The Partnership’s and Predecessor’s share of allocated Sunoco employee benefit plan expenses was $19.6 million, $20.6 million and $21.0 million for the years ended December 31, 2002, 2003 and 2004, respectively. These expenses are reflected in cost of products sold and operating expenses and selling, general and administrative expenses in the statements of income. In connection with the transfer of the Predecessor’s operations to the Partnership, these employees, including senior executives, became employees of the Partnership’s general partner or its affiliates, wholly-owned subsidiaries of Sunoco. The Partnership has no employees.

 

Accounts Receivable, Affiliated Companies

 

Affiliated revenues in the statements of income consist of sales of crude oil as well as the provision of crude oil and refined product pipeline transportation, terminalling and storage services to Sunoco R&M. Sales of crude oil are computed using the formula-based pricing mechanism of a supply agreement with Sunoco R&M. Management of the Partnership believes these terms to be comparable to those that could be negotiated with an unrelated third party. Pipeline revenues are generally determined using posted tariffs. Concurrent with the closing of the February 2002 IPO, the Partnership entered into a pipelines and terminals storage and throughput agreement and various other agreements with Sunoco R&M under which the Partnership is charging Sunoco R&M fees for services provided under these agreements that, in management’s opinion, are comparable to those charged in arm’s-length, third-party transactions. Under the pipelines and terminals storage and throughput agreement, Sunoco R&M has agreed to pay the Partnership a minimum level of revenues for transporting and terminalling refined products. Sunoco R&M also has agreed to minimum throughputs of refined products and crude oil in the Partnership’s Inkster Terminal, Fort Mifflin Terminal Complex, Marcus Hook Tank Farm and certain crude oil pipelines. Under various other agreements entered into at the closing of the IPO, Sunoco R&M is, among other things, purchasing from the Partnership, at market-based rates, particular grades of crude oil that the Partnership’s crude oil acquisition and marketing business purchases for delivery to certain pipelines. These agreements automatically renew on a monthly basis unless terminated by either party on 30 days’ written notice. Sunoco R&M also leases the Partnership’s 58 miles of interrefinery pipelines between Sunoco R&M’s Philadelphia and Marcus Hook refineries for a term of 20 years.

 

Subsequent to the February 2002 IPO, the Partnership has entered into various other agreements with Sunoco, Inc., Sunoco R&M, and their affiliates, including throughput agreements regarding certain acquired assets or improvements or expansions at existing assets which are not covered within the agreements mentioned previously. Under these agreements, the Partnership is charging Sunoco R&M fees for services provided that are comparable to those charged in arm’s-length, third-party transactions and, in some instances, provide for minimum throughputs within these assets.

 

Note Receivable from Affiliate

 

Effective October 1, 2000, the Predecessor loaned $20.0 million to Sunoco. The loan, which was evidenced by a note that was collected on January 1, 2002, earned interest at a rate based on the short-term applicable federal rate established by the Internal Revenue Service.

 

Long-term Debt due Affiliate

 

At January 1, 2002, the Predecessor had long-term debt due to affiliate that was not assumed by the Partnership at the date of the IPO. The debt consisted of individual notes payable to Sunoco. One of the notes

 

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bore interest at a rate based on the short-term applicable federal rate established by the Internal Revenue Service, while the other notes bore interest based on the prime rate. Cash payments for interest in regards to the debt due affiliate, net of capitalized interest (see Note 1), were $0.7 million in 2002. There was no cash payment for interest on debt due to affiliate in 2003 or 2004.

 

Capital Contributions

 

The Omnibus Agreement requires Sunoco R&M to: reimburse the Partnership for any operating expenses and capital expenditures in excess of $8.0 million per year in each calendar year from 2002 to 2006 that are made to comply with the U.S. Department of Transportation’s (“DOT”) pipeline integrity management rule, subject to a maximum aggregate reimbursement of $15.0 million over the five-year period ending December 31, 2006; complete, at its expense, certain tank maintenance and inspection projects at the Darby Creek Tank Farm; and reimburse the Partnership for up to $10.0 million of expenditures required at the Marcus Hook Tank Farm and the Darby Creek Tank Farm to maintain compliance with existing industry standards and regulatory requirements.

 

For the years ended December 31, 2002, 2003 and 2004, the Partnership was reimbursed $0.7 million, $1.9 million and $2.1 million, respectively, by Sunoco R&M for maintenance capital expenditures and operating expenses incurred in excess of $8.0 million to comply with DOT’s pipeline integrity management rule. At December 31, 2004, the Partnership has received a cumulative reimbursement of $4.7 million in regard to the $15.0 million maximum reimbursement over the five-year period for compliance expenditures relative to the DOT’s pipeline integrity management rule. For the year ended December 31, 2002, the Partnership was also reimbursed $2.1 million by Sunoco R&M for certain tank maintenance and inspection expenditures at the Darby Creek Tank Farm. There were no amounts expended for these tank maintenance and inspection projects at the Darby Creek Tank Farm during 2003 and 2004. For the years ended December 31, 2002, 2003 and 2004, the Partnership was reimbursed by Sunoco R&M for expenditures at the Marcus Hook Tank Farm and the Darby Creek Tank Farm to maintain compliance with existing industry standards and regulatory requirements. These expenditures, which were recorded as maintenance capital and operating expenses, were as follows:

 

     Partnership
and
Predecessor


   Partnership

     Year Ended December 31,

     2002

   2003

   2004

     (amounts in thousands)

Maintenance capital

   $ 534    $ 2,982    $ 4,140

Operating expenses

     351      467      540
    

  

  

     $ 885    $ 3,449    $ 4,680
    

  

  

 

At December 31, 2004, the Partnership has received a cumulative reimbursement of $9.0 million relative to the $10.0 million maximum reimbursement for compliance expenditures at the Marcus Hook Tank Farm and the Darby Creek Tank Farm. The aggregate amounts reimbursed related to all of the previously mentioned provisions of the Omnibus Agreement of $3.7 million, $5.3 million and $6.8 million for the years ended December 31, 2002, 2003 and 2004, respectively, by Sunoco R&M related to these projects were recorded as capital contributions to Partners’ Capital within the Partnership’s balance sheets.

 

Under the terms of the Interrefinery Lease Agreement, Sunoco R&M is required to reimburse the Partnership for any non-routine maintenance expenditures, as defined, incurred during the term of the agreement. The Eagle Point purchase agreement requires Sunoco R&M to reimburse the Partnership for certain maintenance

 

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capital and expense expenditures incurred regarding the assets acquired, as defined, up to $5.0 million within the first 10 years of closing of the transaction. For the year ended December 31, 2004, the Partnership incurred maintenance capital expenditures of $0.2 million under the provisions within these agreements and was reimbursed by Sunoco R&M. The reimbursements were recorded as capital contributions to Partners’ Capital within the Partnership’s balance sheet.

 

Asset Acquisitions

 

On March 30, 2004, the Partnership acquired the Eagle Point refinery logistics assets from Sunoco R&M for $20 million (see Note 14). In connection with the acquisition, the Partnership entered into a throughput agreement with Sunoco R&M under which the Partnership is charging Sunoco R&M fees for services provided under this agreement comparable to those charged in arm’s length, third-party transactions. The throughput agreement also requires Sunoco R&M to maintain minimum volumes on the truck rack acquired in this transaction upon completion of certain capital improvements which were completed during the fourth quarter of 2004.

 

On November 15, 2002, the Partnership acquired an equity ownership interest in West Texas Gulf Pipe Line for $10.6 million from Sunoco (see Note 14). Since the acquisition was from a related party, the interest in the entity was recorded by the Partnership at Sunoco’s historical cost of $11.7 million rather than the acquisition price of $10.6 million. The additional $1.1 million was recorded by the Partnership as a capital contribution.

 

Redemption of Common Units

 

In April 2004, the Partnership sold 3.4 million common units in a public offering (see Note 2). The proceeds of this offering were partially utilized to redeem approximately 2.2 million common units from Sunoco for $82.7 million. The redemption price per unit was equal to the public offering price per unit after the underwriters’ commissions. As a result of this net issuance of 1.2 million common units, the general partner contributed $1.0 million to the Partnership to maintain its 2.0 percent ownership interest. The Partnership recorded this amount as a capital contribution to Partners’ Capital within its balance sheet. In connection with the equity offering, the Partnership and Sunoco entered into an agreement whereby Sunoco agreed to reimburse the Partnership for transaction costs incurred by the Partnership based upon the percentage that Sunoco’s net redemption proceeds received represented of the total gross proceeds of the Partnership’s offering (approximately 64.2 percent). Reimbursement of these costs of $0.4 million occurred during the fourth quarter of 2004 when the transaction costs were finalized and was accounted for as an increase to Partners’ Capital within the Partnership’s balance sheet.

 

4. Write-Down of Assets

 

In December 2002, the Partnership recorded a $6.3 million provision to write-down an idled refined product pipeline in the Eastern Pipeline System and a related terminal. These assets were idled as a result of a long-term agreement entered into by the Partnership in December 2002 to lease throughput capacity on a third-party refined product pipeline which allows it to provide substantially the same service as existed on the idled pipeline while reducing operating expenses. This provision was recorded within depreciation and amortization in the Partnership’s statements of income.

 

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5. Income Taxes

 

As discussed in Note 1, substantially all income taxes are the responsibility of the unitholders and not the Partnership as of February 8, 2002 (the date of the IPO). However, prior to February 8, 2002, the Predecessor was included in the consolidated federal income tax return filed by Sunoco, prepared on a separate-return basis.

 

The components of income tax expense are as follows (in thousands of dollars):

 

     Predecessor

     Year Ended
December 31,
2002


Income taxes currently payable:

      

U.S. federal

   $ 841

State

     39
    

       880
    

Deferred taxes:

      

U.S. federal

     616

State

     59
    

       675
    

     $ 1,555
    

 

The reconciliation of income tax expense at the U.S. statutory rate to income tax expense is as follows (in thousands of dollars):

 

     Predecessor

 
     Year Ended
December 31,
2002


 

Income tax expense at the U.S. statutory rate of 35 percent

   $ 1,742 (1)

Increase (reduction) in income taxes resulting from:

        

State income taxes net of Federal income tax effects

     64  

Dividend exclusion for joint venture pipeline operations

     (262 )

Other

     11  
    


     $ 1,555  
    



(1) Based upon income for the period from January 1, 2002 through February 7, 2002, the date prior to the IPO.

 

Cash payments for income taxes (including amounts paid to Sunoco) amounted to $0.1 million in 2002.

 

6. Net Income Per Unit Data

 

The computation of basic net income per limited partner unit is calculated by dividing net income, after the deduction of the general partner’s interest in net income, by the weighted-average number of common and subordinated units outstanding during the year. The general partner’s interest in net income is calculated on a quarterly basis based upon its percentage interest in quarterly cash distributions declared. The general partner’s interest in quarterly cash distributions consists of its 2.0 percent general interest and “incentive distributions”, which are increasing percentages, up to 50 percent of quarterly distributions in excess of $0.50 per limited partner unit (see Note 15). The general partner was allocated net income of $0.9 million (representing 2.0 percent

 

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of total net income for the period) for the period from February 8, 2002 to December 31, 2002, $1.4 million (representing 2.4 percent of total net income for the period) for the year ended December 31, 2003, and $2.8 million (representing 5.0 percent of total net income for the period) for the year ended December 31, 2004. Diluted net income per limited partner unit is calculated by dividing net income applicable to limited partners’ by the sum of the weighted-average number of common and subordinated units outstanding and the dilutive effect of incentive unit awards (see Note 13), as calculated by the treasury stock method.

 

Prior to the closing of the Partnership’s IPO on February 8, 2002, there were no limited partner units outstanding. As such, net income per limited partner unit is not presented for the 38-day period from January 1, 2002 to February 7, 2002. The following table sets forth the reconciliation of the weighted average number of limited partner units used to compute basic net income per limited partner unit to those used to compute diluted net income per limited partner unit for the period from February 8, 2002 to December 31, 2002 and the years ended December 31, 2003 and 2004:

 

     Partnership

     2002

   2003

   2004

Weighted average number of limited partner units outstanding—basic

   22,767,899    22,771,793    23,666,211

Add effect of dilutive unit incentive awards

   17,508    122,727    240,940
    
  
  

Weighted average number of limited partner units—diluted

   22,785,407    22,894,520    23,907,151
    
  
  

 

7. Inventories

 

The components of inventories are as follows (in thousands of dollars):

 

     Partnership

     December 31,

     2003

   2004

Crude oil

   $ 26,543    $ 26,428

Materials, supplies and other

     725      700
    

  

     $ 27,268    $ 27,128
    

  

 

The current replacement cost of crude oil inventory exceeded its carrying value by $38.1 million and $59.7 million at December 31, 2003 and 2004, respectively. During 2002 and 2004, the Partnership reduced crude oil inventory quantities, which were valued at lower LIFO costs prevailing in prior years. The effect of this reduction in inventory was to increase 2002 net income by $1.5 million and 2004 net income by $0.5 million.

 

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8. Properties, Plants and Equipment

 

The components of net properties, plants and equipment are as follows (in thousands of dollars):

 

     Estimated
Useful Lives


   Partnership

 
        December 31,

 
        2003

    2004

 

Land and land improvements (including rights of way)

   —      $ 49,425     $ 56,678  

Pipeline and related assets

   38 - 60      510,670       536,502  

Terminals and storage facilities

   5 - 44      345,950       383,809  

Other

   5 - 48      75,674       77,656  

Construction-in-progress

   —        24,026       41,283  
         


 


            1,005,745       1,095,928  

Less: Accumulated depreciation and amortization

          (422,581 )     (448,728 )
         


 


          $ 583,164     $ 647,200  
         


 


 

9. Investment in Affiliates

 

The Partnership’s ownership percentages in corporate joint ventures as of December 31, 2003 and 2004 are as follows:

 

     Partnership
Ownership
Percentage


 

Explorer Pipeline Company

   9.4 %

Wolverine Pipe Line Company

   31.5 %

West Shore Pipe Line Company

   12.3 %

Yellowstone Pipe Line Company

   14.0 %

West Texas Gulf Pipe Line Company

   43.8 %

 

The following table provides summarized financial information on a 100 percent basis for the Partnership’s equity ownership interests. The results of Wolverine, West Shore, Yellowstone and West Texas Gulf have been included from their dates of acquisition (see Note 14) (in thousands of dollars):

 

     Partnership
and
Predecessor


   Partnership

     2002

   2003

   2004

Income Statement Data:

                    

Total revenues

   $ 213,609    $ 345,741    $ 375,740

Income before income taxes

   $ 106,234    $ 155,577    $ 158,529

Net income

   $ 70,447    $ 94,437    $ 100,876

Balance Sheet Data (as of year-end):

                    

Current assets

   $ 100,132    $ 93,479    $ 100,971

Non-current assets

   $ 441,720    $ 472,444    $ 473,183

Current liabilities

   $ 70,404    $ 67,834    $ 69,836

Non-current liabilities

   $ 419,563    $ 444,845    $ 446,482

Net equity

   $ 51,885    $ 53,244    $ 57,836

 

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The Partnership’s investments in Wolverine, West Shore, Yellowstone, and West Texas Gulf at December 31, 2004 include an excess investment amount of approximately $56.2 million, net of accumulated amortization of $1.3 million. The excess investment is the difference between the investment balance and the Partnership’s proportionate share of the net assets of the entities. The excess investment was allocated to the underlying tangible and intangible assets. Other than land and indefinite-lived intangible assets, all amounts allocated, principally to pipeline and related assets, were amortized using the straight-line method over their estimated useful life of 40 years and included within depreciation and amortization in the statements of income.

 

10. Long-Term Debt

 

The components of long-term debt are as follows (in thousands of dollars):

 

     Partnership

 
     December 31,

 
     2003

    2004

 

Credit Facility

   $ 64,500     $ 64,500  

Senior Notes

     250,000       250,000  

Less unamortized bond discount

     (1,364 )     (1,195 )
    


 


     $ 313,136     $ 313,305  
    


 


 

On November 22, 2004, the Operating Partnership entered into a new, five-year $250 million Credit Facility. This Credit Facility replaces the Operating Partnership’s previous credit agreement, which was scheduled to mature on January 31, 2005. The Credit Facility is available to fund the Operating Partnership’s working capital requirements, to finance future acquisitions and for general partnership purposes. It may also be used to fund the quarterly distribution to a maximum of $20.0 million. Borrowing under this distribution sublimit must be reduced to zero each year for a 15-day period. The Credit Facility bears interest at the Operating Partnership’s option, at either (i) LIBOR plus an applicable margin or (ii) the higher of the federal funds rate plus 0.50 percent or the Citibank prime rate (each plus the applicable margin). The interest rate on the outstanding borrowings at December 31, 2004 was 2.94 percent. The Credit Facility may be prepaid at any time. The Credit Facility contains various covenants limiting the Operating Partnership’s ability to incur indebtedness; grant certain liens; make certain loans, acquisitions and investments; make any material change to the nature of its business; acquire another company; or enter into a merger or sale of assets, including the sale or transfer of interests in the Operating Partnership’s subsidiaries. The Credit Facility also contains covenants requiring the Operating Partnership to maintain, on a rolling four-quarter basis, a maximum total debt to EBITDA ratio (each as defined in the credit agreement) of 4.5 to 1, which can be increased to 5.0 to 1 during an acquisition period (as defined in the credit agreement); and an interest coverage ratio (as defined in the credit agreement) of at least 3.0 to 1. The Operating Partnership is in compliance with these covenants as of December 31, 2004. The Partnership’s ratio of total debt to EBITDA was 2.8 to 1 and the interest coverage ratio was 5.4 to 1 for the year ended December 31, 2004.

 

The Senior Notes were issued in connection with the February 2002 IPO and are at 7.25 percent, due February 15, 2012, and were issued by the Operating Partnership at a discount of 99.325 percent of the principal amount. The discount is amortized on a straight-line basis over the term of the Senior Notes and is included within interest expense in the statements of income. The Senior Notes are redeemable, at a make-whole premium, and are not subject to sinking fund provisions. The Senior Notes contain various covenants limiting the Operating Partnership’s ability to incur certain liens, engage in sale/leaseback transactions, or merge, consolidate or sell substantially all of its assets. The Operating Partnership is in compliance with these covenants as of

 

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December 31, 2004. In addition, the Senior Notes are also subject to repurchase by the Operating Partnership at a price equal to 100 percent of their principal amount, plus accrued and unpaid interest upon a change of control to a non-investment grade entity. The Operating Partnership distributed the net proceeds of $244.8 million after offering commissions and issuance expenses from the sale of the outstanding Senior Notes to the Partnership for distribution to Sunoco.

 

The Partnership and the operating subsidiaries of the Operating Partnership serve as joint and several guarantors of the Senior Notes and of any obligations under the Credit Facility. The guarantees are full and unconditional.

 

The Partnership has no operations and its only assets are its investments in its wholly-owned partnerships and subsidiaries. The Operating Partnership also has no operations and its assets are limited primarily to its investments in its wholly-owned operating partnerships, deferred charges, and cash and cash equivalents of $52.7 million. Except for amounts associated with the Senior Notes, the Credit Facility, cash and cash equivalents and advances to affiliate, the assets and liabilities in the balance sheets and the revenues and costs and expenses in the statements of income are primarily attributable to the operating partnerships.

 

The aggregate amount of long-term debt maturities is as follows (in thousands of dollars):

 

Year Ended December 31:


    

2009

   $ 64,500

2012

     250,000
    

     $ 314,500
    

 

Cash payments for interest related to long-term debt, net of capitalized interest (see Note 1), were $8.6 million, $19.3 million and $19.4 million in 2002, 2003 and 2004, respectively.

 

11. Commitments and Contingent Liabilities

 

Total rental expense for 2002, 2003 and 2004 amounted to $3.1 million, $4.5 million and $4.5 million, respectively. The Partnership, as lessee, has noncancelable operating leases for land, office space and equipment for which the aggregate amount of future minimum annual rentals as of December 31, 2004 is as follows (in thousands of dollars):

 

Year Ended December 31:


    

2005

   $ 2,692

2006

     2,351

2007

     2,077

2008

     1,722

2009

     1,417

Thereafter

     4,218
    

Total

   $ 14,477
    

 

As part of the agreement to purchase the equity ownership interest in Wolverine in November 2002 (see Note 14), the Partnership agreed to assume participation in an agreement along with the other owners of Wolverine to guarantee certain outstanding debt instruments of Wolverine based upon ownership percentage.

 

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Based upon outstanding indebtedness of these instruments of approximately $0.8 million at December 31, 2004, the approximate value of the guarantee is $0.3 million.

 

The Partnership is subject to numerous federal, state and local laws which regulate the discharge of materials into the environment or that otherwise relate to the protection of the environment. These laws and regulations result in liabilities and loss contingencies for remediation at the Partnership’s facilities and at third-party or formerly owned sites. At December 31, 2003 and 2004, there were accrued liabilities for environmental remediation in the balance sheets of $0.5 million and $0.8 million, respectively. The accrued liabilities for environmental remediation do not include any amounts attributable to unasserted claims, nor have any recoveries from insurance been assumed. Pretax charges against income for environmental remediation totaled $1.2 million, $1.2 million and $1.4 million for the years ended December 31, 2002, 2003 and 2004, respectively.

 

Total future costs for environmental remediation activities will depend upon, among other things, the identification of any additional sites, the determination of the extent of the contamination at each site, the timing and nature of required remedial actions, the technology available and needed to meet the various existing legal requirements, the nature and extent of future environmental laws, inflation rates and the determination of the Partnership’s liability at multi-party sites, if any, in light of uncertainties with respect to joint and several liability, and the number, participation levels and financial viability of other parties. As discussed below, the Partnership’s current and future costs have been and will be impacted by an indemnification from Sunoco.

 

The Predecessor is a party to certain pending and threatened claims. Although the ultimate outcome of these claims cannot be ascertained at this time, it is reasonably possible that some portion of them could be resolved unfavorably to the Predecessor. Management does not believe that any liabilities which may arise from such claims and the environmental matters discussed above would be material in relation to the financial position of the Partnership at December 31, 2004. Furthermore, management does not believe that the overall costs for such matters will have a material impact, over an extended period of time, on the Partnership’s operations, cash flows or liquidity.

 

Sunoco has indemnified the Partnership for 30 years from environmental and toxic tort liabilities related to the assets contributed to the Partnership that arise from the operation of such assets prior to the closing of the February 2002 IPO. Sunoco has indemnified the Partnership for 100 percent of all losses asserted within the first 21 years of closing of the February 2002 IPO. Sunoco’s share of liability for claims asserted thereafter will decrease by 10 percent a year. For example, for a claim asserted during the twenty-third year after closing of the February 2002 IPO, Sunoco would be required to indemnify the Partnership for 80 percent of its loss. There is no monetary cap on the amount of indemnity coverage provided by Sunoco. The Partnership has agreed to indemnify Sunoco for events and conditions associated with the operation of the Partnership’s assets that occur on or after the closing of the February 2002 IPO and for environmental and toxic tort liabilities to the extent Sunoco is not required to indemnify the Partnership.

 

Sunoco also has indemnified the Partnership for liabilities, other than environmental and toxic tort liabilities related to the assets contributed to the Partnership, that arise out of Sunoco’s ownership and operation of the assets prior to the closing of the February 2002 IPO and that are asserted within 10 years after closing of the February 2002 IPO. In addition, Sunoco has indemnified the Partnership from liabilities relating to certain defects in title to the assets contributed to the Partnership and associated with failure to obtain certain consents and permits necessary to conduct its business that arise within 10 years after closing of the February 2002 IPO as well as from liabilities relating to legal actions currently pending against Sunoco or its affiliates and events and conditions associated with any assets retained by Sunoco or its affiliates.

 

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Management of the Partnership does not believe that any liabilities which may arise from claims indemnified by Sunoco would be material in relation to the financial position of the Partnership at December 31, 2004. There are certain other pending legal proceedings related to matters arising after the February 2002 IPO that are not indemnified by Sunoco. Management believes that any liabilities that may arise from these legal proceedings will not be material in relation to the financial position of the Partnership at December 31, 2004.

 

12. Net Parent Investment

 

The Predecessor’s net parent investment account represented a net balance resulting from the settlement of intercompany transactions (including federal income taxes) between the Predecessor and Sunoco as well as Sunoco’s ownership interest in the net assets of the Predecessor. It also reflects the Predecessor’s participation in Sunoco’s central cash management program, wherein all of the Predecessor’s cash receipts were remitted to Sunoco and all cash disbursements were funded by Sunoco. There were no terms of settlement or interest charges attributable to this balance. The Predecessor’s net parent investment account excludes amounts loaned to/borrowed from Sunoco evidenced by interest-bearing notes.

 

In connection with the contribution of the Predecessor to the Partnership on February 8, 2002, Sunoco retained certain assets and liabilities. The following table summarizes the carrying amount of the assets and liabilities which were not contributed by Sunoco (in thousands of dollars):

 

Account receivable

   $ 2,446

Inventories

     6,989

Deferred income taxes

     2,821

Properties, plants and equipment, net

     1,482

Other deferred charges

     1,464
    

       15,202
    

Accounts payable

     4,152

Accrued liabilities

     10,714

Taxes payable

     14,072

Long-term debt due affiliate

     90,000

Deferred income taxes

     78,815

Other deferred credits and liabilities

     8,336
    

       206,089
    

Net liabilities retained by Sunoco

   $ 190,887
    

 

13. Management Incentive Plan

 

Sunoco Partners LLC, the general partner of the Partnership, has adopted the Sunoco Partners LLC Long-Term Incentive Plan (“LTIP”) for employees and directors of the general partner who perform services for the Partnership. The LTIP is administered by the independent directors of the Compensation Committee of the general partner’s board of directors. LTIP awards may consist of either restricted units or unit options. The LTIP currently permits the grant of restricted units and unit options covering an aggregate of 1,250,000 common units.

 

Restricted Units

 

A restricted unit entitles the grantee to receive a common unit or, at the discretion of the Compensation Committee, an amount of cash equivalent to the value of a common unit upon the vesting of the unit, which may

 

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include the attainment of predetermined performance targets. The Compensation Committee may make additional grants under the LTIP to employees and directors containing such terms as the Compensation Committee shall determine. Common units to be delivered to the grantee upon vesting may be common units acquired by the general partner in the open market, common units already owned by the general partner, common units acquired by the general partner directly from the Partnership or any other person, or any combination of the foregoing. The general partner will be entitled to reimbursement by the Partnership for the cost incurred in acquiring common units. If the Partnership issues new common units upon vesting of the restricted units, the total number of common units outstanding will increase. The Compensation Committee, in its discretion, may grant tandem distribution equivalent rights (“DER”) with respect to the restricted units. DERs entitle the grantee to receive an amount of cash equal to the per unit cash distributions made by the Partnership during the period the restricted unit is outstanding.

 

The following table provides the LTIP restricted unit activity for the three-year period ended December 31, 2004:

 

     Partnership

     2002

   2003

    2004

Outstanding at January 1

   —      185,625     264,247

Granted(1)

   185,625    66,714     52,045

Performance factor adjusted(2)

   —      19,508     25,529

Matured

   —      —       —  

Cancelled

   —      (7,600 )   —  
    
  

 

Outstanding at December 31

   185,625    264,247     341,821
    
  

 

(1) The weighted average price for restricted unit awards on the date of grant was $19.87, $24.94 and $37.15 for awards granted in 2002, 2003 and 2004, respectively.
(2) Consists of adjustments to performance-based awards to reflect actual performance. The adjustments are required since the original grants of these awards were at 100 percent of the targeted amounts.

 

The Partnership recognized non-cash compensation expense of $0.7 million, $2.2 million and $3.2 million for the years ended December 31, 2002, 2003 and 2004, respectively, related to the unit grants and performance factor adjustments noted in the table above. Each of the restricted unit grants also have tandem DERs for which the Partnership recognized compensation expense of $0.2 million, $0.6 million and $0.8 million for the years ended December 31, 2002, 2003 and 2004, respectively.

 

Unit Options

 

A unit option entitles the grantee to purchase a common unit at a price determined at the date of grant by the Compensation Committee. There have been no grants of unit options for the years ended December 31, 2002, 2003 and 2004, and there are no unit options outstanding as of December 31, 2004. However, the Compensation Committee may, in the future, make grants under the LTIP to employees and directors containing such terms as the Compensation Committee shall determine, provided that unit options have an exercise price no less than the fair market value of the units on the date of grant. Upon exercise of a unit option, the general partner will deliver common units acquired by it in the open market, purchased directly from the Partnership or any other person, use common units already owned by the general partner, or any combination of the foregoing. The general partner will be entitled to reimbursement by the Partnership for the difference between the cost incurred by the general partner in acquiring such common units and the proceeds received by the general partner from an optionee at the time of exercise. Thus, the cost of the unit options will be born by the Partnership. If the Partnership issues new

 

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common units upon exercise of the unit options, the total number of common units outstanding will increase, and the general partner will remit to the Partnership the proceeds received by it from the optionee upon exercise of the unit option.

 

The Partnership follows SFAS 123 (as discussed in Note 1) and has recognized compensation expense related to the restricted units granted based on the fair value method.

 

14. Acquisitions

 

On November 30, 2004, the Partnership acquired a refined products terminal located in Columbus, Ohio for approximately $8.0 million. The terminal is connected to a third-party, refined product, common carrier pipeline and includes 6 refined product tanks with approximately 160,000 barrels of working storage capacity. The purchase price was funded through cash on hand, and was allocated on a preliminary basis to property, plant and equipment within the Terminal Facilities business segment. The results of the acquisition are included in the financial st