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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-K

(Mark One)

For the fiscal year ended December 31, 2003

OR

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)

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

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

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 $163.8 million as of June 27, 2003, based on $28.49 per unit, the closing price of the Common Units as reported on the New York Stock Exchange on that date.

At February 27, 2004, the number of the registrant’s Common Units outstanding was 11,388,154, and its Subordinated Units outstanding was 11,383,639.

DOCUMENTS INCORPORATED BY REFERENCE: NONE

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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:

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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 on October 15, 2001. 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.

In February 2002, 5,750,000 common units, representing approximately 24.8 percent of the partnership interests, were sold to the public in an initial public offering (“IPO”). Sunoco, Inc., through its wholly-owned subsidiaries (collectively, “Sunoco”), currently owns approximately 75.3 percent of the partnership interests, 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 a limited partnership formed by Sunoco, Inc. to own, operate and acquire a geographically diversified portfolio of complementary energy assets. 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 52 percent of the Partnership’s total revenues for the year ended December 31, 2003. The business comprises three segments:

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 17 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 68 percent of the Eastern Pipeline segment’s total revenues for the year ended December 31, 2003.

Refined Product Pipelines

The refined product pipelines transport refined products from Sunoco R&M’s Philadelphia and Marcus Hook, Pennsylvania and Toledo, Ohio 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, isobutane, 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 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:

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

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The following table sets forth, for each of the refined product pipeline systems, the origin and destination, miles of pipeline and diameter. Except as indicated below, the Partnership owns 100 percent of the refined product pipeline systems.

Origin and Destination

N.M. Not meaningful.

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:

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Explorer Pipeline

The Partnership owns a 9.4 percent interest in Explorer Pipeline Company (“Explorer”), a joint venture that owns a 1,410-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 commensurate 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 and Toledo, Ohio 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 commensurate with its ownership interest.

In 1999, Wolverine purchased pipeline assets belonging to Total in Michigan that supported the Alma refinery. Wolverine has used these assets to make deliveries to Lansing and Bay City. Since the purchase, Wolverine has been expanding the pipeline capacity to these cities and expects to complete the last phase of the additional planned expansion when permits are obtained.

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 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 commensurate 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 656-mile common carrier refined product pipeline. Other owners of Yellowstone are ExxonMobil and ConocoPhillips. The system, which is operated by ConocoPhilips 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.

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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. While the last payment on the debt is projected to be made in 2004, there are no assurances that dividends will be paid in 2004 or in future years.

Terminal Facilities

Sunoco R&M accounted for approximately 65 percent of the Terminal Facilities segment’s total revenues for the year ended December 31, 2003.

Refined Product Terminals

The Partnership’s 31 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:

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

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The 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 maximum flexibility.

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.

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

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 2003 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.

Fort Mifflin Terminal. 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

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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.

Hog Island Wharf. The Hog Island Wharf is located next to the Fort Mifflin Terminal on the Delaware River. The Hog Island Wharf 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.

Darby Creek Tank Farm. 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:

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 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:

The 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 51 percent of the Western Pipeline System segment’s total revenues for the year ended December 31, 2003.

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Crude Oil Pipelines

The Partnership owns and operates approximately 1,868 miles of crude oil trunk pipelines and approximately 822 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.

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

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 following table details the mileage and diameter of the pipelines in each major crude oil trunk line system. The Partnership transports most of the crude oil to and lube extracted feedstock from Sunoco R&M’s Tulsa, Oklahoma refinery.

Major System

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Oklahoma

The Partnership owns and operates a large crude oil pipeline and gathering system in Oklahoma. This system contains 681 miles of crude oil trunk pipelines and 435 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:

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 the largest purchaser of crude oil from producers in the state, and is the primary shipper on its Oklahoma system. Other significant shippers are Sunoco R&M and Sinclair, which ship primarily on the Enid to Tulsa segment.

West Texas

The Partnership owns and operates approximately 817 miles of crude oil trunk pipelines and approximately 244 miles of crude oil gathering pipelines in West and North Central Texas. Deliveries are made on the West Texas system to:

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 143 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 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

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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 is operated by ChevronTexaco, 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. Shippers on the pipeline are the Partnership, Sunoco, an affiliate of one other owner and several unaffiliated customers. The Partnership receives a quarterly cash dividend from West Texas Gulf that is commensurate 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, 2003, the Partnership purchased 193,176 bpd from approximately 3,400 producers and from approximately 34,000 leases, and undertook approximately 300,000 bpd of exchanges and bulk purchases during the same period.

Crude Oil Lease 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 to the Partnership’s pipeline or transported via truck to the Partnership’s pipeline or a third party’s pipeline. The trucking services are performed either by the Partnership’s truck fleet or third-party trucking operations.

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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 exchanges for the years presented:

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:

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 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.

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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 113 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

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, 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.

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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

Wolverine, West Shore and Yellowstone Pipe Line Interest Acquisitions. On November 15, 2002, the Partnership acquired an affiliate of Union Oil Company of California, 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 656-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.

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.

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.

Subsequent Event

Eagle Point Logistics Assets. On January 13, 2004, Sunoco closed on its purchase of the Eagle Point Refinery in Westville, New Jersey from El Paso Corporation. Management of the Partnership is currently negotiating with Sunoco for the acquisition of certain pipeline and other logistics assets associated with the refinery.

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 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, and Tulsa refineries, or refined products transported from the Philadelphia, Marcus Hook, and Toledo 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, 2003, Sunoco R&M accounted for approximately 52 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

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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, the Partnership will continue to receive a significant portion of the throughput at these facilities from Sunoco R&M.

The 31 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 Beaumont.

The Inkster Terminal’s primary competition comes from the 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:

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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 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 believes it is on track to complete the assessment of the highest risk 50 percent of line segments by September 30, 2004, with 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

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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. Violations of 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, 2003, the Partnership has not incurred any material environmental liabilities that were not covered by the environmental indemnification.

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Air Emissions

The Partnership’s operations are subject to the Clean Air Act and comparable state and local statutes. Amendments to the Clean Air Act enacted in late 1990 as well as recent or soon to be adopted changes to state implementation plans for controlling air emissions in regional, non-attainment areas require or will require most industrial operations in the United States to incur capital expenditures in order to meet air emission control standards developed by the Environmental Protection Agency (“EPA”) and state environmental agencies. As a result of these amendments, the Partnership’s facilities that emit volatile organic compounds or nitrogen oxides are subject to increasingly stringent regulations, including requirements that some sources install maximum or reasonably available control technology. In addition, the 1990 Clean Air Act Amendments established a new operating permit for major sources, which applies to some of the Partnership’s facilities. 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. Since the late 1990s, the EPA has undertaken significant enforcement initiatives under authority of the Clean Air Act. These enforcement initiatives have been targeted at industries that have large manufacturing facilities and that are significant sources of emissions, such as the refining, paper and pulp, and electric power generating industries. As part of these initiatives, 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

The Comprehensive Environmental Response, Compensation, and Liability Act, referred to as CERCLA and also known as Superfund, and comparable state laws impose liability, without regard to fault or the legality of the original conduct, on certain classes of persons that contributed to the release of a “hazardous substance” into the environment. These persons include the owner or operator of the site where the release occurred and companies that disposed or arranged for the disposal of the hazardous substances found at the site. Under CERCLA, these persons may be subject to joint and several liability for the costs of cleaning up the hazardous substances that have been released into the environment, for damages to natural resources, and for the costs of certain health studies. CERCLA also authorizes the EPA and, in some instances, third parties to act in response to threats to the public health or the environment and to seek to recover from the responsible classes of persons the costs they incur. It is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by hazardous substances or other pollutants released into the environment. In the course of ordinary operations, the Partnership may generate waste that falls within CERCLA’s 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 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. From time to time, the EPA considers the adoption of stricter disposal standards for non-hazardous wastes,

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including crude oil and gas wastes. 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. Although operating and disposal practices have been utilized that were standard in the industry at the time, hydrocarbons or other waste may have been disposed of or released on or under the properties owned or leased by the Partnership or on or under other locations where these wastes have been taken for disposal. In addition, many of these properties have been operated by third parties whose treatment and disposal or release of hydrocarbons or other wastes was not under the Partnership’s control. 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 discharge of regulated substances into regulated waters is prohibited, except in accord with the terms of a permit issued by applicable federal or state authorities. The Oil Pollution Act, enacted in 1990, amends provisions of the Clean Water Act as they pertain to prevention and response to oil releases.

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.

Endangered Species Act

The Endangered Species Act restricts activities that may affect endangered species or their habitats. While some of the Partnership’s facilities are in areas that may be designated as a habitat for endangered species, management believes that the Partnership is in substantial compliance with the Endangered Species Act. However, the discovery of previously unidentified endangered species could cause the Partnership to incur additional costs or become subject to operating restrictions or bans in the affected area.

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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 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 is therefore the responsible party and needs to perform the necessary assessment, remediation, and/or monitoring activities. Remediation programs may be mandated at four sites, one in Texas, two in Pennsylvania, and one in Michigan. 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 to its financial position at December 31, 2003. 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.

Index-Based Rates and Other Subsequent Developments. In October 1992, Congress passed the Energy Policy Act of 1992. The Energy Policy Act deemed interstate petroleum pipeline rates in effect during the 365-day period preceding enactment that had not been subject to complaint, protest, or investigation during such period, to be just and reasonable under the Interstate Commerce Act. All of the Partnership’s interstate pipeline rates were deemed just and reasonable, and so “grandfathered” under the Energy Policy Act. The Energy Policy Act also limited the circumstances under which the FERC may change grandfathered rates in response to complaints. In order to challenge grandfathered rates, a complainant must show that it was contractually barred from challenging the rate prior to enactment of the Energy Policy Act (and filed the complaint within 30 days of the expiration of the contractual bar), that the nature of the service underlying the rate has substantially changed, or that the rate is unduly discriminatory or preferential.

The Energy Policy Act further required the FERC to issue rules establishing a simplified and generally applicable ratemaking methodology for interstate petroleum pipelines and to streamline procedures in petroleum pipeline proceedings. FERC Order No. 561, effective January 1, 1995, adopted a new indexed rate methodology for interstate petroleum pipelines. Under the resulting regulations, petroleum pipelines were able to change their

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rates within prescribed ceiling levels that were tied to changes in the Producer Price Index for Finished Goods, or PPI, minus one percent. Rate increases made under the index are subject to protest, but the scope of the protest proceeding will be limited to an inquiry into whether the portion of the rate increase resulting from application of the index substantially exceeds the pipeline’s increase in costs. The indexing methodology applies to any existing rate, whether grandfathered or established after enactment of the Energy Policy Act. As a result of certain litigation, on February 24, 2003, the FERC ordered that the appropriate index for the current period should be the PPI without the minus one percent adjustment. It further ruled that pipelines may calculate the current ceiling rate using the PPI as though it had been the index in effect since July 1, 2001.

Under Order No. 561, as a general rule, pipelines must use the indexing methodology to change their rates. However, the FERC retained cost-of-service ratemaking, market-based rates, and settlement as alternatives to the indexing approach in certain specified circumstances. A pipeline may follow the cost-of-service approach when seeking to increase its rates above index levels (or when seeking to avoid lowering rates to index levels), so long as there is a substantial difference between the actual cost increases (or decreases) experienced by the pipeline and the rate resulting from application of the index. FERC Opinion No. 435, issued in January 1999, affirmed the determination (in the FERC’s earlier Opinion No. 397) that there should not be a corporate income tax allowance built into a petroleum pipeline’s rates for income attributable to noncorporate partners. In subsequent decisions on rehearing, the FERC further defined the scope of the income tax allowance for publicly traded limited partnerships, and resolved a number of other cost of service issues.

A pipeline can charge market-based rates if it establishes that it lacks significant market power in the affected markets. The opportunity to charge market-based rates means that the pipeline may charge prices established by competitive market forces. FERC Order No. 572, issued October 25, 1994, established procedural rules governing petroleum pipelines’ applications for a finding that the pipeline lacks significant market power in the relevant market. In addition, a pipeline can establish rates under settlement, resulting from the unanimous agreement of the pipeline and all the shippers using the service to which the rate applies. The FERC, however, will entertain a challenge to settlement rates that alleges the same circumstances required to challenge an indexed rate.

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. 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, 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.

Employees

To carry out the Partnership’s operations, the general partner and its affiliates employed approximately 1,150 people at December 31, 2003 who provide direct support to the operations. Labor unions or associations represent approximately 650 of these employees at December 31, 2003. 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.

(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.

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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, 2003.

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

No matters were submitted to a vote of the security holders, through solicitation of proxies or otherwise, during fiscal 2003.

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PART II

ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY AND RELATED SECURITYHOLDER MATTERS

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 28, 2004, there were 70 holders of record of the Partnership’s common units. These holders of record included the general partner with 5,638,154 common units registered in its name, and Cede & Co. with 5,682,634 common units (representing approximately 5,800 beneficial owners) registered to it.

The high and low closing sales price ranges (composite transactions) and distributions declared by quarter for 2002 and 2003 since the close of the IPO on February 8, 2002 were as follows:

The Partnership also has 11,383,639 subordinated units issued, all of which are held by the general partner and for which there is no established public trading market.

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.

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

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,

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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. The Partnership has met the minimum quarterly distribution requirements on all outstanding units for each of the four quarter periods in 2002 and 2003. In addition, one-quarter of the subordinated units may convert to common units on a one-for-one basis 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. 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.

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

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 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.

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 1999, 2000 and 2001, the Partnership and Predecessor for 2002, and the Partnership for 2003.

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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 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 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 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.

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Management of the Partnership believes EBITDA information enhances an investor’s understanding of a business’s ability to satisfy principal and interest obligations with respect to its indebtedness and to utilize cash for other purposes, including the payment of distributions. In addition, EBITDA is used as a measure in the Credit Facility in determining the Partnership’s 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 does not represent and should not be considered as an alternative to net income, income from operations 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.

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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 historical financial statements of Sunoco Logistics (Predecessor) and 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 subsidiaries, 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. 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 three 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 interests in Wolverine and Yellowstone and a 9.2 percent interest in West Shore were acquired on November 15, 2002 for a purchase price of $54.0 million. On September 30, 2003, an additional 3.1 percent interest in West Shore was acquired for $3.7 million, increasing the Partnership’s overall ownership interest to 12.3 percent. The Terminal Facilities business includes a network of 31 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 and a refined product storage terminal used by Sunoco R&M’s Marcus Hook refinery. 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. The interest in West Texas Gulf was acquired on November 15, 2002 for $10.6 million.

Eastern Pipeline System

Revenues from 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

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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 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

Prior to January 1, 2002, most of the terminalling and throughput services provided to Sunoco R&M were at fees that enabled the Partnership to recover its costs but not generate operating income. The Partnership is now charging Sunoco R&M fees for these services, generally effective January 1, 2002, 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”.) Under this agreement, operating income from terminalling and storage activities depends on throughput and storage volume and the level of fees charged for terminalling and storage services, as well as the fixed and variable costs of operating these facilities.

The Partnership generates revenue at the Nederland Terminal by charging storage and throughput fees for crude oil and other petroleum products. The operating income generated at this facility depends on storage and throughput volume and the level of fees charged for these services, as well as the fixed and variable costs of operating the terminal. 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

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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 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.

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Agreements with Sunoco R&M and Sunoco, Inc.

Upon the closing of the February 2002 IPO, the Partnership entered into the following agreements:

Pipelines and Terminals Storage and Throughput Agreement

Under this agreement, Sunoco R&M is paying the Partnership fees generally comparable to those charged by third parties to:

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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.

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.