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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549



FORM 10-K



(Mark One)    

ý

 

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

For the fiscal year ended December 31, 2012

OR

o

 

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

For the transition period from                                    to                                   

Commission file number 001-32593

Global Partners LP
(Exact name of registrant as specified in its charter)

Delaware
(State or other jurisdiction of
incorporation or organization)
  74-3140887
(I.R.S. Employer Identification No.)

P.O. Box 9161
800 South Street
Waltham, Massachusetts 02454-9161
(Address of principal executive offices, including zip code)

(781) 894-8800
(Registrant's telephone number, including area code)

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

Title of each class   Name of each exchange on which registered
Common Units representing limited partner interests   New York Stock Exchange

Securities registered pursuant to section 12(g) of the Act:
None

         Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes o    No ý

         Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes o    No ý

         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 ý    No o

         Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files. Yes ý    No o

         Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.    ý

         Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See definitions of "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act.:

Large accelerated filer o   Accelerated filer ý   Non-accelerated filer o   Smaller reporting company o

         Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes o    No ý

         The aggregate market value of common units held by non-affiliates of the registrant (treating directors and executive officers of the registrant's general partner and holders of 10% or more of the common units outstanding, for this purpose, as if they were affiliates of the registrant) as of June 29, 2012 was approximately $278,563,782 based on a price per common unit of $22.76, the price at which the common units were last sold as reported on the New York Stock Exchange on such date.

         As of March 12, 2013, 27,430,563 common units were outstanding.

   


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TABLE OF CONTENTS

 
   
   

PART I

       

Items 1. and 2.

 

Business and Properties

  4

Item 1A.

 

Risk Factors

  18

Item 1B.

 

Unresolved Staff Comments

  41

Item 3.

 

Legal Proceedings

  42

Item 4.

 

Mine Safety Disclosures

  43

PART II

       

Item 5.

 

Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

  44

Item 6.

 

Selected Financial Data

  45

Item 7.

 

Management's Discussion and Analysis of Financial Condition and Results of Operations

  48

Item 7A.

 

Quantitative and Qualitative Disclosures about Market Risk

  74

Item 8.

 

Financial Statements and Supplementary Data

  76

Item 9.

 

Changes in and Disagreements With Accountants on Accounting and Financial Disclosure

  76

Item 9A.

 

Controls and Procedures

  77

Item 9B.

 

Other Information

  78

PART III

       

Item 10.

 

Directors, Executive Officers and Corporate Governance

  79

Item 11.

 

Executive Compensation

  84

Item 12.

 

Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

  112

Item 13.

 

Certain Relationships and Related Transactions, and Director Independence

  114

Item 14.

 

Principal Accounting Fees and Services

  119

PART IV

       

Item 15.

 

Exhibits and Financial Statement Schedules

  120

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Forward-Looking Statements

        Some of the information contained in this Annual Report on Form 10-K may contain forward-looking statements. Forward-looking statements include, without limitation, any statement that may project, indicate or imply future results, events, performance or achievements, and may contain the words "may," "believe," "should," "could," "expect," "anticipate," "plan," "intend," "estimate," "continue," "will likely result," or other similar expressions. In addition, any statement made by our management concerning future financial performance (including future revenues, earnings or growth rates), ongoing business strategies or prospects, and possible actions by us are also forward-looking statements. Although we believe these forward-looking statements are reasonable as and when made, there may be events in the future that we are not able to predict accurately or control, and there can be no assurance that future developments affecting our business will be those that we anticipate. Additionally, all statements concerning our expectations regarding future operating results are based on current forecasts for our existing operations and do not include the potential impact of any future acquisitions. The factors listed under "Risk Factors," as well as any cautionary language in this report, describe the known material risks, uncertainties and events that may cause our actual results to differ materially from the expectations we describe in our forward-looking statements. Additional factors or events that may emerge from time to time, or those that we currently deem to be immaterial, could cause our actual results to differ, and it is not possible for us to predict all of them. You are cautioned not to place undue reliance on the forward-looking statements contained herein. The following factors are among those that may cause actual results to differ materially and adversely from our forward-looking statements:

    We may not have sufficient cash from operations to enable us to pay the minimum quarterly distribution or maintain distributions at current levels following establishment of cash reserves and payment of fees and expenses, including payments to our general partner.

    A significant decrease in demand for the products we sell could reduce our ability to make distributions to our unitholders.

    Our sales of home heating oil and residual oil could be significantly reduced by conversions to natural gasoline.

    Erosion of the value of the Mobil brand could adversely affect our gasoline sales and customer traffic.

    Our gasoline station and convenience store business could expose us to an increase in consumer litigation and result in an unfavorable outcome or settlement of one or more lawsuits where insurance proceeds are insufficient or otherwise unavailable.

    Our gasoline sales could be significantly reduced by a reduction in demand due to higher prices and to new technologies and alternative fuel sources, such as electric, hybrid or battery powered motor vehicles.

    Our crude oil sales could be adversely affected by, among other things, unanticipated changes in the crude oil market structure, grade differentials and volatility (or lack thereof), changes in refiner demand, severe weather conditions, significant changes in prices and interruptions in rail transportation services and other necessary services and equipment, such as railcars, trucks, loading equipment and qualified drivers.

    We depend upon rail and marine transportation services for a substantial portion of our logistics business in transporting the products we sell. A disruption in rail and marine transportation services could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.

    Changes to government usage mandates could adversely affect the availability and pricing of ethanol, which could negatively impact our sales.

    Warmer weather conditions could adversely affect our home heating oil and residual oil sales.

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    Our risk management policies cannot eliminate all commodity risk. In addition, noncompliance with our risk management policies could result in significant financial losses.

    Our results of operations are affected by the overall forward market for the products we sell.

    Our business could be affected by a range of issues, such as dramatic changes in commodity prices, energy conservation, competition, the global economic climate, movement of products between Europe and the United States, weekly and monthly refinery output levels, changes in local, domestic and worldwide inventory levels, seasonality and supply, weather and logistics disruptions.

    Increases and/or decreases in the prices of the products we sell could adversely impact the amount of borrowing available for working capital under our credit agreement, which credit agreement has borrowing base limitations and advance rates.

    We are exposed to trade credit risk in the ordinary course of our business.

    We are exposed to risk associated with our trade credit support in the ordinary course of our business.

    The condition of credit markets may adversely affect us.

    Our bank credit agreement and the indenture governing our senior notes contain operating and financial covenants, and our credit agreement contains borrowing base requirements. A failure to comply with the operating and financial covenants in our credit agreement and the indenture and any future financing agreements could impact our access to bank loans and restrict our ability to finance future operations or capital needs or to engage in, expand or pursue our business activities.

    A significant increase in interest rates could adversely affect our ability to service our indebtedness.

    Adverse developments in the areas where we conduct our business could reduce our ability to make distributions to our unitholders.

    A serious disruption to our information technology systems could significantly limit our ability to manage and operate our business efficiently.

    We are exposed to performance risk in our supply chain.

    Our businesses are subject to both federal and state environmental and non-environmental regulations which could have a material adverse effect on such businesses.

    Our general partner and its affiliates have conflicts of interest and limited fiduciary duties, which may permit them to favor their own interests to the detriment of unitholders.

    Unitholders have limited voting rights and are not entitled to elect our general partner or its directors or to remove our general partner without the consent of the holders of at least 662/3% of the outstanding units (including units held by our general partner and its affiliates), which could lower the trading price of our common units.

    Our tax treatment depends on our status as a partnership for federal income tax purposes.

    Unitholders may be required to pay taxes on their share of our income even if they do not receive any cash distributions from us.

        Additional information about risks and uncertainties that could cause actual results to differ materially from forward-looking statements is contained in Item 1A, "Risk Factors" in this Annual Report on Form 10-K.

        We expressly disclaim any obligation or undertaking to update these statements to reflect any change in our expectations or beliefs or any change in events, conditions or circumstances on which any forward-looking statement is based. All forward-looking statements included in this Annual Report on Form 10-K and all subsequent written or oral forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these cautionary statements.

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Available Information

        We make available free of charge through our website, www.globalp.com, our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934 as soon as reasonably practicable after we electronically file or furnish such material with the Securities and Exchange Commission ("SEC"). These documents are also available at the SEC's website at www.sec.gov. Our website also includes our Code of Business Conduct and Ethics, our Governance Guidelines and the charters of our Audit Committee and Compensation Committee.

        A copy of any of these documents will be provided without charge upon written request to the General Counsel, Global Partners LP, P.O. Box 9161, 800 South Street, Suite 200, Waltham, MA 02454; fax (781) 398-4165.

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PART I

        References in this Annual Report on Form 10-K to "Global Partners LP," "Partnership," "we," "our," "us" or like terms refer to Global Partners LP and its subsidiaries. References to "our general partner" refer to Global GP LLC.

Items 1. and 2.    Business and Properties.

Overview

        We are a publicly traded Delaware master limited partnership formed in March 2005. As of December 31, 2012, we had the following wholly owned subsidiaries: Global Companies LLC, Glen Hes Corp., Global Montello Group Corp. ("GMG"), Chelsea Sandwich LLC, Global Energy Marketing LLC, Alliance Energy LLC, Bursaw Oil LLC, GLP Finance Corp. and Global Energy Marketing II LLC. Our general partner manages our operations and activities and employs our officers and substantially all of our personnel, except for our gasoline station and convenience store employees and certain union personnel who are employed by GMG.

        We are a midstream logistics and marketing company that engages in the purchasing, selling and logistics of transporting Bakken and Canadian crude oil and other products via rail, establishing a "virtual pipeline" from the mid-continent region of the United States and Canada to refiners and other customers on the East and West Coasts. We own, control or have access to one of the largest terminal networks of refined petroleum products and renewable fuels in Massachusetts, Maine, Connecticut, Vermont, New Hampshire, Rhode Island, New York, New Jersey and Pennsylvania (collectively, the "Northeast"). We are one of the largest distributors of gasoline (including gasoline blendstocks such as ethanol and naphtha), distillates (such as home heating oil, diesel and kerosene), residual oil and renewable fuels to wholesalers, retailers and commercial customers in the New England states and New York. We are a major multi-brand gasoline distributor and have a portfolio of approximately 1,000 owned, leased and/or supplied gasoline stations primarily in the Northeast. We are also a distributor of natural gas.

Operations and Segments

        Collectively, we sold approximately $17.5 billion of refined petroleum products, renewable fuels, crude oil and natural gasoline for the year ended December 31, 2012. In addition, we had other revenues of approximately $124.1 million, primarily from convenience store sales at our directly operated stores and gas station rental income from sites owned by us and leased to others. As of December 31, 2012, we owned, leased or maintained dedicated storage facilities at 25 refined petroleum product bulk terminals, each with the capacity of more than 50,000 barrels, including 23 located throughout the Northeast that are supplied primarily by marine transport, pipeline, rail and/or truck and that collectively have approximately 10.5 million barrels of storage capacity. Additionally, we have storage capacity at our Albany, New York terminal to store crude oil and at select locations to store renewable fuels. In Columbus, North Dakota we completed construction of our new 100,000 barrel storage tank and truck offloading facility as part of the development of that location as a hub for the gathering, storage, transportation and marketing of crude oil and other products. We also have throughput and exchange agreements at numerous bulk terminals and inland storage facilities. In addition, we have storage agreements at several of our terminals granting storage rights to third parties for which we receive a fee.

        We purchase refined petroleum products, renewable fuels, crude oil and natural gas primarily from domestic and foreign refiners and ethanol producers, crude oil producers, major and independent oil companies and trading companies, and we sell these products in three segments: (i) Wholesale, (ii) Gasoline Distribution and Station Operations and (iii) Commercial. In 2012, our Wholesale sales accounted for approximately 78% of our total sales, and our Gasoline Distribution and Station Operations and Commercial sales accounted for18% and 4%, of our total sales, respectively.

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    Wholesale

        We own, control or have access to one of the largest terminal networks of refined petroleum products and renewable fuels in the Northeast. We engage in the logistics of gathering, storage, transportation and marketing of refined petroleum products, renewable fuels and crude oil. We are one of the largest distributors of gasoline (including gasoline blendstocks such as ethanol and naphtha), distillates (such as home heating oil, diesel and kerosene), residual oil and renewable fuels to wholesalers in the New England states and New York. In addition, we sell crude oil to refiners.

        On January 1, 2013, we signed a five-year contract with Phillips 66 under which we will use our storage, rail transloading, logistics and transportation system to deliver crude oil from the Bakken region of North Dakota to Phillips 66's Bayway, New Jersey refinery. On February 1, 2013, we acquired a 60% membership interest in Basin Transload LLC ("Basin Transload"), which operates two transloading facilities (which are facilities used for transferring product shipments from one mode of transportation to another) in North Dakota. On February 15, 2013, we acquired 100% of the membership interests in Cascade Kelly Holdings LLC ("Cascade Kelly"), which owns a West Coast crude oil and ethanol facility near Portland, Oregon. See "—Recent Developments" for a further discussion on these transactions.

        We believe we have created a "virtual pipeline" solution for the transportation of crude oil and other products from the mid-continent region of the United States and Canada to the East and West Coasts. This "virtual pipeline" consists of our strategically located terminal assets, our logistical capabilities and access to railroad and barge transportation. We have enhanced our capabilities and our business with the Phillips 66, Basin Transload and Cascade Kelly transactions early in 2013.

    Gasoline Distribution and Station Operations

        As of December 31, 2012, we had a portfolio of approximately 1,000 owned, leased and/or supplied gasoline stations primarily in the Northeast.

        In September 2010, we completed the acquisition from ExxonMobil Corporation ("ExxonMobil") of 190 retail gasoline stations, together with the rights to (i) supply Mobil-branded fuel to those stations as well as an additional 31 existing locations in Massachusetts, New Hampshire and Rhode Island, and (ii) expand supply opportunities for Mobil-branded and Exxon-branded fuel in certain other New England states. This acquisition expanded our supply business and added vertical integration to our transportation fuel business in New England. On March 1, 2012, we acquired Alliance Energy LLC ("Alliance"), a gasoline distributor and operator of gasoline stations and convenience stores. As of the date of the acquisition, Alliance's portfolio included approximately 540 gasoline stations in the Northeast, of which it owned or held under long-term lease approximately 250 stations, and had supply contracts for the remaining stations. The Alliance acquisition expanded our geographic footprint for gasoline stations to include Connecticut, New Jersey, New York, Pennsylvania, Maine and Vermont. Alliance is a top-tier distributor of multiple brands, including Exxon, Mobil, Shell, Sunoco, CITGO and Gulf. Prior to the closing of the acquisition, Alliance was wholly owned by AE Holdings Corp. ("AE Holdings"), which is approximately 95% owned by members of the Slifka family. See Note 3 of Notes to Consolidated Financial Statements included elsewhere in this report.

        On April 26, 2012, we entered into an agreement with Getty Realty Corp. ("Getty Realty") to supply and provide management services to more than 200 of its gasoline stations in New York and New Jersey. On November 19, 2012, we signed a long-term lease agreement with Getty Realty for approximately 90 of those 200 sites which enables us to supply gasoline to and operate gasoline stations in the New York City boroughs of Queens, Manhattan and the Bronx, as well as in Long Island and Westchester County. The lease with Getty Realty significantly expands our retail gasoline and fuel distribution presence in the New York City metro region.

    Commercial

        This segment includes sales and deliveries to end user customers in the public sector and to commercial and industrial end users of unbranded gasoline, home heating oil, diesel, kerosene, residual oil, renewable fuels and natural gas. Our Commercial segment also includes sales of custom blended distillates and residual oil delivered by barge or from a terminal dock to ships through our bunkering activity.

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Seasonality

        Due to the nature of our business and our customers' reliance, in part, on consumer travel and spending patterns, we may experience more demand for gasoline and gasoline blendstocks during the late spring and summer months than during the fall and winter. Travel and recreational activities are typically higher in these months in the geographic areas in which we operate, increasing the demand for gasoline and gasoline blendstocks that we distribute. Therefore, our volumes in gasoline and gasoline blendstocks are typically higher in the second and third quarters of the calendar year. Demand for some of our refined petroleum products, specifically home heating oil and residual oil for space heating purposes, is generally greater during the winter months. Therefore, heating oil and residual oil sales are generally higher during the first and fourth quarters of the calendar year. These factors may result in significant fluctuations in our quarterly operating results. The increase in the non-weather sensitive components of our business helps to partially offset the economic impact that warmer weather conditions may have on our home heating oil and residual oil sales. Portions of our heating oil and residual oil are sold on a forward fixed price basis. In 2012, our volume in transportation fuels, which continues to represent a growing portion of our sales, exceeded our heating oil volumes.

Business Strategies

        We intend to pursue the following business strategies:

    Diversification and enhancement of year-round streams of income.  We seek to enhance and diversify our sources of income throughout the year through organic growth and acquisitions and expansion activities:

    Pursue organic growth and expansions. We strive to improve returns and create operating efficiencies through asset and logistics expansions and improvements, such as additional rail loading capacity, tank reconfigurations and flexibility in our usage of storage tanks. In addition, in the last several years we have expanded and diversified our product menu to include additional products, such as crude oil, ethanol, natural gas and biofuel, and we expect to begin selling propane in the near future from a facility in Albany, New York. We also pursue the expansion of our gasoline station business with the introduction of new-to-industry sites, the razing and rebuilding of sites within our existing portfolio and the conversion of repair-based sites to convenience stores. We have also sought, and continue to seek, to (1) strategically expand our branding arrangements with major suppliers of refined petroleum products, (2) identify and implement co-branding opportunities with national retailers, such as our existing accounts with Dunkin' Donuts and Subway, (3) strategically expand our Alltown convenience store brand and (3) expand opportunities for the marketing of transportation fuels under the Global brand.

    Expand assets, transportation logistics and marketing businesses through strategic acquisitions. We pursue strategic and accretive acquisitions of assets, transportation logistic opportunities and marketing businesses of petroleum products, gasoline and other transportation fuels, heating oil, crude oil and natural gas, within and beyond the Northeast market. We also pursue strategic and accretive acquisitions of upstream or downstream retail marketing assets, as well as transportation assets and businesses. Because of our extensive experience in logistics and marketing, we believe we have a competitive advantage over bidders interested in purchasing only physical assets. We look to leverage our experience by identifying and consummating purchases that fit strategically with our existing operations. For example, we seek portfolios (large and small) of retail gasoline stations that complement our existing gasoline station operations.

    Serve as a preferred supplier to our customers.  We believe that our customers value dependability and quality of supply. We strive to maintain a level of inventory to ensure that the supply needs of our customers are always satisfied. During periods of product shortages, we have historically succeeded in sustaining a supply of product sufficient to meet the needs of our customers. We own, control or have access to bulk terminals, inland storage facilities and gasoline stations and convenience stores that are strategically located for ease of access by our customers. Additionally, we satisfy specific wholesale customer needs by customizing our products, such as diesel, home heating oil and gasoline, by blending and injecting additives.

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    Focus on credit fundamentals of our customers.  We manage our trade credit exposure through conservative management practices, such as:

    pre-approving customers up to certain credit limits;

    seeking secondary sources of repayment for trade credit, such as letters of credit or guarantees;

    not offering to extend credit as a marketing tool to attract customers; and

    utilizing automatic debit systems for payment.

      As a result of these practices, in each of the past five years the amount of account receivables that we wrote off was insignificant as a percentage of sales.

    Minimize our exposure to commodity price volatility.  We actively manage our business to minimize commodity price exposure by using hedging techniques. We seek to maintain a position that is substantially balanced between purchases and sales by establishing an offsetting sales position with a positive margin each time we commit to purchase a volume of product.

Recent Developments

Acquisitions

Basin Transload

        On February 1, 2013, we acquired a 60% membership interest in Basin Transload, which operates two transloading facilities in Columbus and Beulah, North Dakota for crude oil and other products, with a combined rail loading capacity of 160,000 barrels per day. The purchase price, which is subject to purchase adjustments, was approximately $85.0 million which we financed with borrowings under our credit facility.

        The transloading facilities are approximately 195 miles apart in Columbus and Beulah. The Columbus facility is located along the Canadian Pacific Railway and provides single line rail haul service to our recently expanded terminal in Albany, New York. Basin Transload's Beulah site, which supports crude oil production efforts in the Williston Basin, is located along the Burlington Northern Santa Fe ("BNSF") Railway with direct long-haul rail service to the West Coast and Gulf Coast markets.

        Basin Transload provides us with strategically located assets in the Bakken region. The facilities will help form a network of unique origin and destination locations through which our customers can efficiently supply cost-competitive crude oil to destinations on the East and West coasts. In addition to our interest in Basin Transload, we own and operate a 100,000 barrel storage tank and truck offloading rack at the Columbus facility.

Cascade Kelly

        On February 15, 2013, and pursuant to the Membership Interest Purchase Agreement dated as of January 22, 2013 between us and JH Kelly Holdings LLC, we acquired 100% of the membership interests in Cascade Kelly, which owns a West Coast crude oil and ethanol facility near Portland, Oregon. The total purchase price was approximately $95.0 million which we funded with borrowings under our credit facility and with proceeds from the issuance of our unsecured 8.00% senior notes due 2018. The transaction includes a rail transloading facility serviced by the BNSF Railway, 200,000 barrels of storage capacity, a deepwater marine terminal with access to a 1,200-foot leased dock and the largest ethanol plant on the West Coast. Situated along the Columbia River in Clatskanie, Oregon, the site is located on land leased under a long-term agreement from the Port of St. Helens. The purchase of this crude oil and ethanol facility strategically enhances our network of origin and destination assets and extends our virtual pipeline to the West Coast.

Other Developments

Phillips 66

        On January 1, 2013, we signed a five-year contract with Phillips 66 under which we will use our storage, rail transloading, logistics and transportation system to deliver crude oil from the Bakken region of North Dakota to Phillips 66's Bayway, New Jersey refinery. The terms of the contract include a take-or-pay commitment from Phillips 66 to receive approximately 91 million barrels of crude oil over the contract term. The majority of the crude oil is expected to be transloaded at Basin Transload's Columbus, North Dakota rail facility (see above). The crude oil will be transported on Canadian Pacific's rail network from the Bakken directly to our terminal in Albany, New York and then shipped by barge to Phillips 66's refinery.

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Rail Expansion of Albany Terminal Facility

        During the fourth quarter of 2012, we completed a build-out project at our terminal facility in Albany, New York that increased rail receipts and throughput storage capacities of ethanol and crude oil and converted certain storage tanks for the handling of crude oil. This expansion increased our capacity to receive and distribute crude oil and other products from 55,000 barrels per day to 160,000 barrels per day and allows the terminal to offload two 120-car unit trains in a 24-hour period. Our rail expansion serves to enhance our "virtual pipeline" solution for the transportation of crude oil and other products from the mid-continent region to Albany, New York. Our rail shipments from the mid-continent to Albany average four or five days, with some shipments completed in as little as two and a half days. From Albany, it is then a one to one and a half day trip by barge to the East Coast refineries.

Construction of Rail-fed Propane Storage and Distribution Facility in Albany

        We are constructing a new rail-fed propane storage and distribution facility near our terminal in Albany, New York. This will be a single line rail haul facility serviced by Canadian Pacific. We believe this storage location, which will have an initial capacity of 540,000 gallons, will be an attractive source of cost-competitive mid-continent propane for wholesale customers in the Northeast.

Hurricane Sandy

        At the end of October 2012, Hurricane Sandy struck the Northeast causing significant damage in the states of New York, Connecticut and New Jersey. As a result of the storm, marine traffic in New York harbor and along the Hudson River was disrupted. While some of our terminals on Long Island and in Newburgh, New York suffered flooding and power outages, the damage to our terminal infrastructure was not significant. We do not believe that disruptions in supply and within the channels of distribution caused by the hurricane had a material adverse impact on our results of operations in the fourth quarter of 2012.

Product Sales

    General

        We sell our refined petroleum products, renewable fuels, crude oil and natural gas in three reporting segments, Wholesale, Gasoline Distribution and Station Operations and Commercial. The majority of the petroleum products we sell can be grouped into four categories: gasoline (including gasoline blendstocks such as ethanol and naphtha), distillates, residual oil and crude oil.

        The following table presents our product sales as a percentage of total sales:

 
  Year Ended December 31,  
 
  2012   2011   2010  

Gasoline sales: gasoline and gasoline blendstocks such as ethanol and naphtha

    68%     68%     60%  

Distillates (home heating oil, diesel and kerosene), residual oil, crude oil and natural gas sales

    32%     32%     40%  
               

Total

    100%     100%     100%  
               

        We had one customer, ExxonMobil, who accounted for approximately 16%, 19% and 19% of our total sales for the years ended December 31, 2012, 2011 and 2010, respectively.

        Gasoline.    We sell all grades of branded and unbranded gasoline that comply with seasonal and geographical requirements in the areas in which we market.

        Distillates.    Distillates are divided into home heating oil, diesel and kerosene. In 2012, sales of home heating oil, diesel and kerosene accounted for approximately 54%, 44%% and 2%, respectively, of our total volume of distillates sold.

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        We sell generic home heating oil and Heating Oil Plus™, our proprietary premium branded heating oil. Heating Oil Plus™ is electronically blended at the delivery facility. In 2012, approximately 12% of the volume of home heating oil we sold to wholesale resellers was Heating Oil Plus™. In addition, we sell the additive used to create Heating Oil Plus™ to some wholesale resellers, make injection systems available to them and provide technical support to assist them with blending. We also educate the sales force of our customers to better prepare them for marketing our products to their customers.

        We sell generic diesel and Diesel One®, our proprietary premium diesel fuel product. We offer marketing and technical support for those customers who purchase Diesel One®.

        Residual Oil.    We are one of the primary residual oil marketers in the Northeast. We specially blend residual oil for users in accordance with their individual power plant specifications.

        Crude Oil and Other Products.    In the fourth quarter of 2011, we expanded our product offerings and began buying and selling mid-continent crude oil in the United States and Canada. We are a leader in the logistics of transporting crude oil and other products from the mid-continent region of the United States and Canada to the East Coast. With the acquisition of Cascade Kelly, we can now supply cost-competitive crude oil from the United States and Canadian mid-continent and supply refiners on the West Coast.

    Wholesale

        In the Wholesale segment, we sell unbranded gasoline (including gasoline blendstocks such as ethanol and naphtha) and diesel to unbranded gasoline customers and other resellers of transportation fuels. We sell home heating oil, diesel, kerosene and residual oil to home heating oil retailers and wholesale distributors. We also sell crude oil to refiners. In 2012, this segment accounted for approximately 79% of our total volume sold. Generally, customers use their own vehicles or contract carriers to take delivery of the gasoline and distillate products at bulk terminals and inland storage facilities that we own or control or with which we have throughput or exchange agreements. Please read "—Storage." Crude oil is aggregated by truck or pipeline in the mid-continent, transported on land by train and shipped to refineries on the East and West Coasts in barges. Additionally, ethanol is shipped primarily by rail and by barge.

        In 2012, we sold unbranded gasoline and diesel, including Diesel One®, to approximately 950 wholesalers and retail gasoline station operators.

        In 2012, we sold home heating oil, including Heating Oil Plus™, to approximately 970 wholesale distributors and retailers. We have a fixed price sales program that we market primarily to wholesale distributors and retailers which uses the New York Mercantile Exchange ("NYMEX") heating oil contract as the pricing benchmark and as the vehicle to manage the commodity risk. Please read "—Commodity Risk Management." In 2012, approximately 30% of our home heating oil volume was sold using forward fixed price contracts. A forward fixed price contract requires our customer to purchase a specific volume at a specific price during a specific period. The remaining home heating oil was sold on either a posted price or a price based on various indices which, in both instances, reflect current market conditions.

        In 2012, we moved 254 trains of crude oil and ethanol to our Albany, New York facility (approximately 39,000 barrels per day).

        Financial information with respect to the Wholesale segment, including information concerning revenues, gross profit, net product margin and total assets may be found under Item 7, "Management's Discussion and Analysis and Results of Operations" and in Note 17 of Notes to Consolidated Financial Statements included elsewhere in this Annual Report on Form 10-K.

    Gasoline Distribution and Station Operations

        In the Gasoline Distribution and Station Operations segment, we sell branded and unbranded gasoline to gasoline stations and other sub-jobbers. This segment also includes gasoline, convenience store, car wash and other ancillary sales at our directly operated stores, as well as rental income from dealer leased gasoline stations. As of December 31, 2012, we had a portfolio of approximately 1,000 owned, leased and/or supplied gasoline stations primarily in the Northeast. In 2012, this segment accounted for approximately 15% of our total volume sold.

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        Financial information with respect to the Gasoline Distribution and Station Operations segment, including information concerning revenues, gross profit, net product margin and total assets may be found under Item 7, "Management's Discussion and Analysis and Results of Operations" and in Note 17 of Notes to Consolidated Financial Statements included elsewhere in this Annual Report on Form 10-K.

    Commercial

        Our Commercial segment includes sales and deliveries of unbranded gasoline, home heating oil, diesel, kerosene, residual oil, renewable fuels and natural gas to end user customers in the public sector and to large commercial and industrial end users. In the case of commercial and industrial end user customers, we sell products primarily either through a competitive bidding process or through contracts of various terms. Our Commercial segment also includes sales of custom blended distillates and residual oil delivered by barges or from a terminal dock to ships through our bunkering activity. In 2012, this segment accounted for approximately 6% of our total volume sold.

        Our commercial end user customers include federal and state agencies, municipalities, large industrial companies, many autonomous authorities such as transportation authorities and water resource authorities, colleges and universities and a group of small utilities. In our Commercial segment, we generally arrange the delivery of the product to the customer's designated location. We typically hire third-party common carriers to deliver the product. Please read "—Storage."

        In this segment, we respond to publicly-issued requests for product proposals and quotes. As of December 31, 2012, we had contracts as a result of this public bidding process with the U.S. government and the states of Massachusetts, New Hampshire, New York and Rhode Island. We also had contracts with municipalities, autonomous authorities and institutional customers in the Northeast to meet their various fuel requirements.

        A majority of the contracts in our bid business are for a term of one to three years. We offer both fixed and indexed price and volume contracts to customers. The majority of bid activity is priced using an indexed price with the index typically chosen by the issuing authority in its solicitation for the bid proposal. The indexed prices are usually referenced to one of five industry publications and/or the utilization of regulated exchanges.

        Our commercial customers also include cruise ships, dry and wet bulk carriers, fishing fleets and other marine vessels. We blend distillates and residual oil to the customers' specifications at the terminal facility or on the barge and then deliver the resulting bunker fuel directly to the ship or barge.

        Financial information with respect to the Commercial segment, including information concerning revenues, gross profit, net product margin and total assets may be found under Item 7, "Management's Discussion and Analysis and Results of Operations" and in Note 17 of Notes to Consolidated Financial Statements included elsewhere in this Annual Report on Form 10-K.

Supply

        Our products come from some of the major energy companies in the world as well as North American crude oil producers. Products can be sourced from the United States, Canada, South America, Europe, Russia and occasionally from Asia. Most of our products are delivered by water, pipeline, rail or truck. During 2012, we purchased an average of approximately 398,000 barrels per day of refined petroleum products, renewable fuels and crude oil from approximately 140 suppliers. In 2012, our top ten suppliers accounted for approximately 61% of our product purchases. We enter into supply agreements with these suppliers on a term basis or a spot basis. With respect to trade terms, our supply purchases vary depending on the particular contract from prompt payment (usually three days) to net 30 days. Please read "—Commodity Risk Management." We obtain our convenience store inventory from traditional suppliers.

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Commodity Risk Management

        Since we take title to the refined petroleum products, renewable fuels and crude oil that we sell, we are exposed to commodity risk. Commodity risk is the risk of unfavorable market fluctuations in the price of commodities such as refined petroleum products, renewable fuels and crude oil. We endeavor to minimize commodity risk in connection with our daily operations. Generally, as we purchase and/or store these products, we reduce commodity risk through hedging by selling futures contracts on regulated exchanges or using other derivatives, and then lift hedges as we sell the product for physical delivery to third parties. Products are generally purchased and sold at spot market prices, fixed prices or indexed prices. While we use these transactions to seek to maintain a position that is substantially balanced within our product purchase activities, we may experience net unbalanced positions for short periods of time as a result of variances in daily sales and transportation and delivery schedules as well as logistical issues, for example, associated with inclement weather conditions. In connection with managing these positions, maintaining a constant presence in the marketplace, and managing the futures market outlook for future anticipated inventories, which are necessary for our business, we engage in a controlled trading program for up to an aggregate of 250,000 barrels of these products at any point in time. Our policy is generally to purchase only products for which we have a market and to structure our sales contracts so that price fluctuations do not materially affect our profit. While our policies are designed to minimize market risk, as well as inherent basis risk, exposure to fluctuations in market conditions remains.

        In addition, because a portion of our crude oil business is conducted in Canadian dollars ("CAD"), we may use foreign currency derivatives to minimize the risks of unfavorable exchange rates. These instruments include foreign currency exchange contracts and forwards. In conjunction with entering into the commodity derivative, we may enter into a foreign currency derivative to hedge the resulting foreign currency risk. These foreign currency derivatives are generally short-term in nature and not designated for hedge accounting.

        Operating results are sensitive to a number of factors. Such factors include commodity location, grades of product, individual customer demand for grades or location of product, localized market price structures, availability of transportation facilities, daily delivery volumes that vary from expected quantities and timing and costs to deliver the commodity to the customer. The term "basis risk" is used to describe the inherent market price risk created when a commodity of certain grade or location is purchased, sold or exchanged as compared to a purchase, sale or exchange of commodity at a different time or place, including, without limitation, transportation costs and timing differentials. We attempt to reduce our exposure to basis risk by grouping our purchase and sale activities by geographical region and commodity quality in order to stay balanced within such designated region. However, basis risk cannot be entirely eliminated, and basis exposure, particularly in backward markets (when prices for future deliveries are lower than current prices) or other adverse market conditions, can adversely affect our financial condition, results of operations and cash available for distribution to our unitholders.

        With respect to the pricing of commodities, we utilize futures contracts and other derivative instruments to minimize or hedge the impact of commodity price changes on our inventories and forward fixed price commitments. Any hedge ineffectiveness is reflected in our results of operations. We generally utilize regulated exchanges, including the NYMEX, the Chicago Mercantile Exchange ("CME") and the IntercontinentalExchange ("ICE"), which are regulated exchanges for the commodities that each trades, thereby reducing potential delivery and supply risks. Generally, our practice is to close all exchange positions rather than make or receive physical deliveries. We may also enter into derivative agreements which may not have a correlated exchange contract with counterparties that we believe have a strong credit profile in order to hedge market fluctuations and/or lock-in margins relative to our commitments.

        We monitor processes and procedures to prevent unauthorized trading by our personnel and to maintain substantial balance between purchases and sales or future delivery obligations. We can provide no assurance, however, that these steps will eliminate commodity risk or detect and prevent all violations of such trading processes and procedures, particularly if deception or other intentional misconduct is involved.

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        For more information about our policies and procedures to minimize our exposure to market risk, including commodity market risk, see Item 7, "Management's Discussion and Analysis and Results of Operations—Quantitative and Qualitative Disclosures About Market Risk."

Storage

        Bulk terminals and inland storage facilities play a key role in the distribution of product to our customers. As of December 31, 2012, we owned, leased or maintained dedicated storage facilities at 25 refined petroleum product bulk terminals, each with the capacity of more than 50,000 barrels, including 23 located throughout the Northeast that collectively have approximately 10.5 million barrels of storage capacity.

        We also have storage capacity at our Albany, New York terminal to store crude oil and at select locations to store renewable fuels. In addition, in Columbus, North Dakota we constructed a 100,000 barrel tank and truck offloading facility as part of the development of a hub for the gathering, storage, rail transloading, transportation and marketing of crude oil and other products.

        We also have throughput and exchange agreements at numerous bulk terminals and inland storage facilities. In addition, we have storage agreements at several of our terminals granting storage rights to third parties for which we receive a fee.

        The bulk terminals and inland storage facilities from which we distribute product are supplied by ship, barge, truck, pipeline and/or rail. The inland storage facilities, which we use exclusively to store distillates, are supplied with product delivered by truck from bulk terminals. Our customers receive product from our network of bulk terminals and inland storage facilities via truck, barge, rail and/or pipeline.

        Many of our bulk terminals operate 24 hours a day and consist of multiple storage tanks and automated truck loading equipment. These automated systems monitor terminal access, volumetric allocations, credit control and carrier certification through the remote identification of customers. In addition, some of the bulk terminals at which we market are equipped with truck loading racks capable of providing automated blending and additive packages which meet our customers' specific requirements.

        Throughput arrangements allow storage of product at terminals owned by others. Our customers can load product at these terminals, and we pay the owners of these terminals fees for services rendered in connection with the receipt, storage and handling of such product. Compensation to the terminal owners may be fixed or based upon the volume of our product that is delivered and sold at the terminal.

        We have exchange agreements with customers and suppliers. An exchange is a contractual agreement where the parties exchange product at their respective terminals or facilities. For example, we (or our customers) receive product that is owned by our exchange partner from such party's facility or terminal, and we deliver the same volume of our product to such party (or to such party's customers) out of one of the terminals in our terminal network. Generally, both sides of an exchange transaction pay a handling fee (similar to a throughput fee), and often one party also pays a location differential that covers any excess transportation costs incurred by the other party in supplying product to the location at which the first party receives product. Other differentials that may occur in exchanges (and result in additional payments) include product value differentials and timing differentials.

Competition

        In each of our operating segments, we encounter varying degrees of competition based on product and geographic locations and available logistics. Our competitors include terminal companies, major integrated oil companies and their marketing affiliates, wholesalers, producers and independent marketers of varying sizes, financial resources and experience. In our Northeast market, we compete in various product lines and for all customers. In the residual oil markets, however, where product is heated when stored and cannot be delivered long distances, we face less competition because of the strategic locations of our residual oil storage facilities. We are one of the primary residual oil marketers in the Northeast. We also compete with natural gas suppliers and marketers in our home heating oil and residual oil product lines. Bunkering requires facilities at ports to service vessels. In various other geographic markets, particularly the unbranded gasoline and distillates markets, we compete with integrated refiners, merchant refiners and regional marketing companies. Our retail gasoline stations compete with unbranded and branded retail gas stations as well as supermarket and warehouse stores that sell gasoline.

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Environmental

    General

        Our business of supplying refined petroleum products, renewable fuels and crude oil involves a number of activities that are subject to extensive and stringent environmental laws. As part of our business, we own and operate various petroleum storage and distribution facilities and gasoline stations and must comply with environmental laws at the federal, state and local levels, which increases the cost of operating terminals and gasoline stations and our business generally.

        Our operations also utilize a number of petroleum storage facilities and distribution facilities, including rail transloading facilities and gasoline stations that we do not own or operate, but at which refined petroleum products, renewable fuels and crude oil are stored. We utilize these facilities through several different contractual arrangements, including leases and throughput and terminalling services agreements. If facilities with which we contract that are owned and operated by third parties fail to comply with environmental laws, they could be shut down, requiring us to incur costs to use alternative facilities.

        Environmental laws and regulations can restrict or impact our business activities in many ways, such as:

    requiring remedial action to mitigate releases of hydrocarbons, hazardous substances or wastes caused by our operations or attributable to former operators;

    requiring capital expenditures to comply with environmental control requirements; and

    enjoining the operations of facilities deemed in noncompliance with environmental laws and regulations.

        Failure to comply with environmental laws and regulations may trigger a variety of administrative, civil and criminal enforcement measures, including the assessment of monetary penalties, the imposition of remedial requirements and the issuance of orders enjoining future operations. Certain environmental statutes impose strict, joint and several liability for costs required to clean up and restore sites where hydrocarbons, hazardous substances or wastes have been released or disposed of. Moreover, neighboring landowners and other third parties may file claims for personal injury and property damage allegedly caused by the release of hydrocarbons, hazardous substances or other wastes into the environment.

        The trend in environmental regulation is to place more restrictions and limitations on activities that may affect the environment over time. As a result, there can be no assurance as to the amount or timing of future expenditures for environmental compliance or remediation, and actual future expenditures may be different from the amounts we currently anticipate. We try to anticipate future regulatory requirements that might be imposed and plan accordingly to remain in compliance with changing environmental laws and regulations and minimize the costs of such compliance.

        We do not believe that compliance with federal, state or local environmental laws and regulations will have a material adverse effect on our financial position, results of operations or cash available for distribution to our unitholders. We can provide no assurance, however, that future events, such as changes in existing laws (including changes in the interpretation of existing laws), the promulgation of new laws, or the development or discovery of new facts or conditions will not cause us to incur significant costs.

    Hazardous Materials and Waste Handling

        In most instances, the environmental laws and regulations affecting our business relate to the release of hazardous substances into the water or soils and include measures to control pollution of the environment. For instance, the Comprehensive Environmental Response, Compensation, and Liability Act, as amended, also known as CERCLA or the Superfund law, and comparable state laws impose

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liability, without regard to fault or the legality of the original conduct, on certain classes of persons who are considered to be responsible for the release of hazardous substances 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. Under the Superfund law, these persons may be subject to joint and several liability for the costs of cleaning up hazardous substances that have been released into the environment, for damages to natural resources and for the costs of certain health studies. The Superfund law also authorizes the U.S. Environmental Protection Agency ("EPA"), and in some instances third parties, to act in response to threats to the public health or the environment and seek to recover from the responsible persons the costs they incur. It is possible 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 our ordinary operations, we may generate, store or otherwise handle materials and wastes that fall within the Superfund law's definition of a hazardous substance and, as a result, we may be jointly and severally liable under the Superfund law for all or part of the costs required to clean up sites at which those hazardous substances have been released into the environment.

        We currently own, lease or utilize storage or distribution facilities and gasoline stations where hydrocarbons are being or have been handled for many years. Although we have utilized operating and disposal practices that were standard in the industry at the time, hydrocarbons or other wastes may have been disposed of or released on, under or from the properties owned or leased by us or on or under other locations where we have contractual arrangements or 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 our control. These properties and wastes disposed thereon may be subject to the Superfund law or other federal and state laws. Under these laws, we could be required to remove or remediate previously disposed wastes, including wastes disposed of or released by prior owners or operators, clean up contaminated property, including groundwater contaminated by prior owners or operators or make capital improvements to prevent future contamination.

        Our operations generate a variety of wastes, including some hazardous wastes that are subject to the federal Resource Conservation and Recovery Act, as amended ("RCRA") and comparable state laws. By way of summary, these regulations impose detailed requirements for the handling, storage, treatment and disposal of hazardous waste. Our operations also generate solid wastes which are regulated under state law or the less stringent solid waste requirements of the federal Solid Waste Disposal Act. We believe that we are in substantial compliance with the existing requirements of RCRA, the Solid Waste Disposal Act, and similar state and local laws, and the cost involved in complying with these requirements is not material.

        We incur ongoing costs for monitoring groundwater and/or remediation of contamination at several facilities that we operate. Assuming that we will be able to continue to use common remedial and monitoring methods or associated engineering or institutional controls to demonstrate compliance with applicable regulatory requirements, as we have in the past and regulations currently allow, we believe that these costs will not have a material impact on our financial condition, results of operations or cash available for distribution to our unitholders.

    Above Ground Storage Tanks

        Above ground tanks that contain petroleum and other hazardous substances are subject to comprehensive regulation under environmental laws. Generally, these laws impose liability for releases and require secondary containment systems for tanks or that the operators take alternative precautions to ensure that no contamination results from tank leaks or spills. We believe we are in substantial compliance with environmental laws and regulations applicable to above ground storage tanks.

        The Oil Pollution Act of 1990 ("OPA") addresses three principal areas of oil pollution—prevention, containment and cleanup. In order to handle, store or transport oil at our terminals, we are required to file oil spill response plans with either the United States Coast Guard (for marine facilities) or the EPA. States in which we operate have enacted laws similar to OPA. Under OPA and comparable state laws, responsible parties for a regulated facility from which oil is discharged may be subject to strict, joint and several liability for removal costs and certain other consequences of an oil spill such as natural resource damages, where the spill is into navigable waters or along shorelines. We believe we are in substantial compliance with regulations pursuant to OPA and similar state laws. We follow the American Petroleum Institute's inspection, maintenance and repair standard applicable to our above ground storage tanks.

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        Under the authority of the federal Clean Water Act, the EPA imposes specific requirements for Spill Prevention, Control and Countermeasure plans that are designed to prevent, and minimize the impacts of, releases of oil and oil products from above ground storage tanks. We believe we are in substantial compliance with these requirements.

    Underground Storage Tanks

        We are required to make financial expenditures to comply with regulations governing underground storage tanks which store gasoline or other regulated substances adopted by federal, state and local regulatory agencies. Pursuant to RCRA, the EPA has established a comprehensive regulatory program for the detection, prevention, investigation and cleanup of leaking underground storage tanks. State or local agencies are often delegated the responsibility for implementing the federal program or developing and implementing equivalent or stricter state or local regulations. We have a comprehensive program in place for performing routine tank testing and other compliance activities which are intended to promptly detect and investigate any potential releases. In addition, the federal Clean Air Act and similar state laws impose requirements on emissions to the air from motor fueling activities in certain areas of the country, including those that do not meet state or national ambient air quality standards. These laws may require the installation of vapor recovery systems to control emissions of volatile organic compounds to the air during the motor fueling process. We believe we are in substantial compliance with applicable environmental requirements, including those applicable to our underground storage tanks. Compliance with existing and future environmental laws regulating underground storage tank systems of the kind we use may require significant capital expenditures in the future. These expenditures may include upgrades, modifications, and the replacement of underground storage tanks and related piping to comply with current and future regulatory requirements designed to ensure the detection, prevention, investigation and remediation of leaks and spills.

    Water Discharges

        The federal Clean Water Act imposes restrictions regarding the discharge of pollutants, including oil and refined petroleum products, renewable fuels and crude oil, into navigable waters. This law and comparable state laws require permits for discharging pollutants into state and federal waters and impose substantial liabilities and remedial obligations for noncompliance. EPA regulations also require us to obtain permits to discharge certain storm water runoff. Storm water discharge permits also may be required by certain states in which we operate. We believe that we hold the required permits and operate in material compliance with those permits. While we have experienced permit discharge exceedences at some of our terminals, we do not expect any noncompliance with existing permits and foreseeable new permit requirements to have a material adverse effect on our financial position, results of operations or cash available for distribution to our unitholders.

    Air Emissions

        Under the federal Clean Air Act and comparable state and local laws, permits are typically required to emit regulated air pollutants into the atmosphere. We believe that we currently hold or have applied for all necessary air permits and that we are in substantial compliance with applicable air laws and regulations. Although we can give no assurances, we are aware of no changes to air quality regulations that will have a material adverse effect on our financial condition, results of operations or cash available for distribution to our unitholders.

        Various federal, state and local agencies have the authority to prescribe product quality specifications for the refined petroleum products, renewable fuels and crude oil that we sell, largely in an effort to reduce air pollution. Failure to comply with these regulations can result in substantial penalties. Although we can give no assurances, we believe we are currently in substantial compliance with these regulations.

        Changes in product quality specifications could require us to incur additional handling costs or reduce our throughput volume. For instance, different product specifications for different markets could require the construction of additional storage. Also, states in which we operate have considered limiting the sulfur content of home heating oil. If such regulations are enacted, this could restrict the supply of available heating oil, which could increase our costs to purchase such oil or limit our ability to sell heating oil.

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        Efforts at the federal and state level are currently underway to reduce the levels of greenhouse gas ("GHG") emissions from various sources in the United States. Even in the absence of new federal legislation, GHG emissions have begun to be regulated by the EPA pursuant to the Clean Air Act. For example, in April 2010, the EPA set a new emissions standard for motor vehicles to reduce GHG emissions. In December 2010, the EPA issued its plan to update pollution standards for fossil fuel power plants and petroleum refineries. Under that agreement, the EPA intended to propose standards for refineries in December 2011. However, the EPA has yet to issue new regulations under the Clean Air Act limiting GHG emissions from oil refineries.

        New federal or state restrictions on emissions of GHGs that may be imposed in areas of the United States in which we conduct business and that apply to our operations could adversely affect the demand for our products.

        Under Subpart MM of the Mandatory Greenhouse Gas Reporting Rule ("MRR"), importers of petroleum products, including distillates, must report the GHG emissions that would result from the complete combustion of all imported products if such combustion would result in the emission of at least 25,000 metric tons of carbon dioxide per year. We currently report under Subpart MM because of the volume of petroleum products we typically import. Compliance with the MRR does not substantially impact our operations. However, any change in regulations based on GHG emissions reported in compliance with MRR may limit our ability to import petroleum products or increase our costs to import such products.

    Convenience Store Regulations

        Our convenience store operations are subject to extensive governmental laws and regulations that include, but are not limited to, legal restrictions on the sale of alcohol, tobacco and lottery products, food safety and health requirements and public accessibility, as well as sanitation, safety and fire standards. State and local regulatory agencies have the authority to approve, revoke, suspend or deny applications for, and renewals of, permits and licenses. Our operations are also subject to federal and state laws governing matters such as wage rates, overtime, working conditions and citizenship requirements. At the federal level, there are proposals under consideration from time to time to increase minimum wage rates and to introduce a system of mandated health insurance, each of which could adversely affect our results of operations. In June 2009, Congress gave the Food and Drug Administration ("FDA") broad authority to regulate tobacco products through passage of the Family Smoking Prevention and Tobacco Control Act ("FSPTCA"). Under the FSPTCA, the FDA has passed regulations that, among other things, prohibit the sale of cigarettes or smokeless tobacco to anyone under the age of 18 years (state laws are permitted to set a higher minimum age); prohibit the sale of single cigarettes or packs with less than 20 cigarettes; and prohibit the sale or distribution of non-tobacco items such as hats and t-shirts with tobacco brands, names or logos. Governmental actions and regulations, such as these, could materially impact our retail price of cigarettes, cigarette unit volume and revenues, merchandise gross profit and overall customer traffic, which could in turn have a material adverse effect on our results of operations.

    Ethanol Market

        The market for ethanol is dependent on several economic incentives to use ethanol, including federal tax incentives, ethanol use mandates and oxygenate blending requirements. For instance, the Renewable Fuels Standard ("RFS") requires that a certain amount of renewable fuels be utilized in the United States each year. Additionally, the EPA imposes oxygenate blending requirements for reformulated gasoline. The market for ethanol also has been affected by the Volumetric Ethanol Excise Tax Credit ("blender's credit"), which provided a volumetric tax credit of 4.5 cents per gallon of gasoline that contains at least 10% ethanol. The blender's credit expired on December 31, 2011. A reduction or waiver of the RFS mandate or the oxygenate blending requirements could adversely affect the availability and pricing of ethanol, which could result in reduced discretionary blending of ethanol. Discretionary blending is when gasoline blenders use ethanol to reduce the cost of blended gasoline.

        Recently, the EPA allowed the use of E15, gasoline which is blended at a rate of 15% ethanol and 85% gasoline, in vehicles manufactured in the model year 2007 and later as well as for cars and light duty trucks manufactured in the model years between 2001 and 2006. According to EPA estimates, flex-fuel vehicles make up only a small percentage of vehicles on the nation's roads and there are approximately 3,000 E85 stations in the U.S. The USDA is providing financial assistance to help implement more "blender pumps" in the U.S. in order to increase demand for ethanol and to help offset the cost of introducing mid-level ethanol blends into the U.S. retail gasoline market. However, blender pumps cost approximately $20,000 each, so it may take time before they become widely available in the retail gasoline market.

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    Environmental Insurance

        We maintain insurance which may cover, in whole or in part, certain costs relating to the clean up of releases of refined petroleum products, renewable fuels, blendstocks and crude oil. We maintain insurance policies with insurers in amounts and with coverage and deductibles as we believe are reasonable and prudent. These policies may not cover all environmental risks and costs and may not provide sufficient coverage in the event an environmental claim is made against us.

Security Regulation

        Since the September 11, 2001 terrorist attacks on the United States, the U.S. government has issued warnings that energy infrastructure assets may be future targets of terrorist organizations. These developments have subjected our operations to increased risks. Increased security measures taken by us as a precaution against possible terrorist attacks have resulted in increased costs to our business. Where required by federal or local laws, we have prepared security plans for the storage and distribution facilities we operate. Terrorist attacks aimed at our facilities and any global and domestic economic repercussions from terrorist activities could adversely affect our financial condition, results of operations and cash available for distribution to our unitholders. For instance, terrorist activity could lead to increased volatility in prices for home heating oil, gasoline and other products we sell.

        Insurance carriers are currently required to offer coverage for terrorist activities as a result of the federal Terrorism Risk Insurance Act of 2002 ("TRIA"). We purchased this coverage with respect to our property and casualty insurance programs, which resulted in additional insurance premiums. Pursuant to the Terrorism Risk Insurance Program Reauthorization Act of 2007, TRIA has been extended through December 31, 2014. Although we cannot determine the future availability and cost of insurance coverage for terrorist acts, we do not expect the availability and cost of such insurance to have a material adverse effect on our financial condition, results of operations or cash available for distribution to our unitholders.

Employee Safety

        We are subject to the requirements of the Occupational Safety and Health Act ("OSHA") and comparable state statutes that regulate the protection of the health and safety of workers. In addition, OSHA's hazard communication standards require that information be maintained about hazardous materials used or produced in operations and that this information be provided to employees, state and local government authorities and citizens. We believe that we are in substantial compliance with the applicable OSHA requirements.

        We operate a limited number of trucks for the transportation of refined petroleum products, as most of the trucks that distribute products we sell are owned and operated by third parties. We are subject to regulations promulgated under the Federal Motor Carrier Safety Act for those trucks that we do operate. These regulations cover the transportation of hazardous materials and are administered by the U.S. Department of Transportation. We conduct ongoing training programs to help ensure that our operations are in compliance with applicable regulations.

Title to Properties, Permits and Licenses

        We believe we have all of the assets needed, including leases, permits and licenses, to operate our business in all material respects. With respect to any consents, permits or authorizations that have not been obtained, we believe that the failure to obtain these consents, permits or authorizations will have no material adverse effect on our financial position, results of operations or cash available for distribution to our unitholders.

        We believe we have satisfactory title to all of our assets. Title to property, including certain sites within our Gasoline Distribution and Station Operations segment, may be subject to encumbrances, including repurchase rights and use, operating and environmental covenants and restrictions. We believe that none of these encumbrances will materially detract from the value of our properties or from our interest in these properties, nor will they materially interfere with the use of these properties in the operation of our business.

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        The name GLOBAL, our logos and the name Global Petroleum Corp. are our trademarks. In addition, we have trademarks for our premium fuels and additives, Diesel One®, Heating Oil Plus™ and SubZero® and a pending trademark for our Alltown convenience store locations.

Facilities

        We lease office space for our principal executive office in Waltham, Massachusetts. The lease expires on December 31, 2015.

Employees

        To carry out our operations, our general partner and certain of our operating subsidiaries employed 788 full-time employees as of December 31, 2012. We believe we have good relations with our employees.

        There are three collective bargaining agreements governing the employment of certain of the employees assigned to our terminal in Chelsea, Massachusetts. The drivers and terminal operators are employed under collective bargaining agreements that expire in 2014, and the dispatchers are employed under a collective bargaining agreement that expires in 2015. Certain of Global Petroleum Corp.'s employees at the Revere, Massachusetts facility are employed under a collective bargaining agreement that expires in 2014. Certain of the employees assigned to our terminals in Albany, Newburgh, Glenwood Landing and Inwood, New York are employed under collective bargaining agreements that expire in 2013 (with respect to Albany and one of our terminals in Newburgh), 2014 (with respect to Glenwood Landing and Inwood) and 2016 (with respect to our other terminals in Newburgh). We are negotiating collective bargaining agreements with respect to the collective bargaining agreements that expire in 2013. We do not believe the result of these negotiations will have a material adverse effect on our operations.

        Certain of the employees assigned to our terminal in Oyster Bay (Commander), New York are employed under a collective bargaining agreement that expires in 2014.

        Certain of the employees assigned to the Cascade Kelly facility in Clatskanie, Oregon are employed under a collective bargaining agreement that expires in 2014.

        We have a shared services agreement with Global Petroleum Corp. The services provided among these entities by any employees shared pursuant to these agreements do not limit the ability of such employees to provide all services necessary to properly run our business. Please read Item 13, "Certain Relationships and Related Transactions, and Director Independence—Shared Services Agreements." In connection with our acquisition of Alliance on March 1, 2012, we terminated our shared services agreement with Alliance effective as of March 9, 2012.

Item 1A.    Risk Factors.

Risks Related to Our Business

We may not have sufficient cash from operations to enable us to pay the minimum quarterly distribution or maintain distributions at current levels following establishment of cash reserves and payment of fees and expenses, including payments to our general partner.

        We may not have sufficient available cash each quarter to pay the minimum quarterly distribution or maintain distributions at current levels. The amount of cash we can distribute on our units principally depends upon the amount of cash we generate from our operations, which will fluctuate from quarter to quarter based on, among other things:

    competition from other companies that sell refined petroleum products, renewable fuels, natural gas and crude oil;

    demand for refined petroleum products, renewable fuels, natural gas and crude oil in the markets we serve;

    absolute price levels, as well as the volatility of prices, of refined petroleum products, renewable fuels, natural gas and crude oil in both the spot and futures markets;

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    supplier disruptions;

    seasonal variation in temperatures, which affects demand for home heating oil and residual oil to the extent that it is used for space heating;

    the level of our operating costs, including payments to our general partner; and

    prevailing economic conditions.

        In addition, the actual amount of cash we have available for distribution will depend on other factors such as:

    the level of capital expenditures we make;

    the restrictions contained in our credit agreement and the indenture governing our senior notes, including financial covenants, borrowing base limitations and advance rates;

    our debt service requirements;

    the cost of acquisitions;

    fluctuations in our working capital needs;

    our ability to borrow under our credit agreement to make distributions to our unitholders; and

    the amount of cash reserves established by our general partner.

The amount of cash we have available for distribution to unitholders depends on our cash flow and not solely on profitability.

        The amount of cash we have available for distribution depends primarily on our cash flow, including working capital borrowings, and not solely on profitability, which will be affected by non-cash items. As a result, we may make cash distributions during periods when we record losses and may not make cash distributions during periods when we record net income.

We may not be able to fully implement or capitalize upon planned growth projects.

        We have a number of organic growth projects that require the expenditure of significant amounts of capital. Many of these projects involve numerous regulatory, environmental, commercial and legal uncertainties that will be beyond our control. As these projects are undertaken, required approvals may not be obtained, may be delayed or may be obtained with conditions that materially alter the expected return associated with the underlying projects. Moreover, revenues associated with these organic growth projects will not increase immediately upon the expenditures of funds with respect to a particular project and these projects may be completed behind schedule or in excess of budgeted cost. We may pursue projects in anticipation of market demand that dissipates or market growth that never materializes. As a result of these uncertainties, the anticipated benefits associated with our capital projects may not be achieved.

Our acquisition strategy involves risks that could reduce our ability to make distributions to our unitholders.

        A principal focus of our business strategy is to grow and expand our business through acquisitions. Our ability to grow depends, in part, on our ability to make acquisitions that result in an increase in the cash generated per unit from operations. If we are unable to make these accretive acquisitions, either because we are (1) unable to identify attractive acquisition candidates or negotiate acceptable purchase contracts with them, (2) unable to obtain financing for these acquisitions on economically acceptable terms or (3) outbid by competitors, then our future growth and ability to increase distributions will be limited. Furthermore, even if we do make acquisitions that we believe will be accretive, these acquisitions may nevertheless result in a decrease in the cash generated from operations per unit.

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        Even if we consummate acquisitions that we believe will be accretive, they may in fact result in no increase or even a decrease in cash available for distribution to our unitholders. Any acquisition involves potential risks, including:

    performance from the acquired assets and businesses that is below the forecasts we used in evaluating the acquisition;

    mistaken assumptions about volumes, revenues and costs, including synergies;

    a significant increase in our indebtedness and working capital requirements;

    an inability to hire, train or retain qualified personnel to manage and operate our business and newly acquired assets;

    the inability to timely and effectively integrate the operations of recently acquired businesses or assets, particularly those in new geographic areas or in new lines of business;

    mistaken assumptions about the overall costs of equity or debt;

    the assumption of substantial unknown or unforeseen environmental and other liabilities arising out of the acquired businesses or assets, including liabilities arising from the operation of the acquired businesses or assets prior to our acquisition, for which we are not indemnified or for which the indemnity is inadequate;

    limitations on rights to indemnity from the seller;

    customer or key employee loss from the acquired businesses;

    unforeseen difficulties operating in new product areas or new geographic areas; and

    diversion of our management's and employees' attention from other business concerns.

        If any acquisitions we ultimately consummate do not generate expected increases in cash available for distribution to our unitholders, our ability to make such distributions will be reduced.

Our gasoline and gasoline blendstocks financial results are seasonal and generally lower in the first and fourth quarters of the calendar year.

        Due to the nature of our business and our customers' reliance, in part, on consumer travel and spending patterns, we may experience more demand for gasoline and gasoline blendstocks during the late spring and summer months than during the fall and winter. Travel and recreational activities are typically higher in these months in the geographic areas in which we operate, increasing the demand for gasoline and gasoline blendstocks that we distribute. Therefore, our volumes in gasoline and gasoline blendstocks are typically higher in the second and third quarters of the calendar year.

Our heating oil and residual oil financial results are seasonal and generally lower in the second and third quarters of the calendar year.

        Demand for some refined petroleum products, specifically home heating oil and residual oil for space heating purposes, is generally higher during November through March than during April through October. We obtain a significant portion of these sales during the winter months. Therefore, our results of operations in heating oil and residual oil for the first and fourth calendar quarters are generally better than for the second and third quarters.

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A significant decrease in demand for refined petroleum products, renewable fuels and crude oil in the areas we serve would reduce our ability to make distributions to our unitholders.

        A significant decrease in demand for refined petroleum products, renewable fuels and crude oil in the areas that we serve could significantly reduce our revenues and, therefore, reduce our ability to make or increase distributions to our unitholders. Factors that could lead to a decrease in market demand for refined petroleum products, renewable fuels and crude oil include:

    a recession or other adverse economic conditions or due to high prices caused by an increase in the market price of refined petroleum products, renewable fuels and crude oil or higher fuel taxes or other governmental or regulatory actions that increase, directly or indirectly, the cost of gasoline or other refined petroleum products, renewable fuels and crude oil;

    a shift by consumers to more fuel-efficient or alternative fuel vehicles or an increase in fuel economy of vehicles, whether as a result of technological advances by manufacturers, governmental or regulatory actions or otherwise; and

    conversion from consumption of home heating oil or residual oil to natural gas.

        Certain of our operating costs and expenses are fixed and do not vary with the volumes we store and distribute. These costs and expenses may not decrease ratably or at all should we experience a reduction in our volumes stored, distributed and sold. As a result, we may experience declines in our margin if our volumes decrease.

Our business is influenced by the overall forward market for refined petroleum products, renewable fuels and crude oil, and increases and/or decreases in the prices of these products may adversely impact our financial condition, results of operations and cash available for distribution to our unitholders and the amount of borrowing available for working capital under our credit agreement.

        Results from our purchasing, storing, terminalling, transporting, selling and logistics operations are influenced by prices for refined petroleum products, renewable fuels and crude oil, pricing volatility and the market for such products. Prices in the overall forward market for these products may affect our financial condition, results of operations and cash available for distribution to our unitholders. Our margins can be significantly impacted by the forward product pricing curve, often referred to as the futures market. We typically hedge our exposure to petroleum product and renewable fuel price moves with futures contracts and, to a lesser extent, swaps. In markets where futures prices are higher than current prices, referred to as contango, we may use our storage capacity to improve our margins by storing products we have purchased at lower prices in the current market for delivery to customers at higher prices in the future. In markets where futures prices are lower than current prices, referred to as backwardation, inventories can depreciate in value and hedging costs are more expensive. For this reason, we attempt to reduce our inventories in order to minimize these effects. When prices for the products we sell rise, some of our customers may have insufficient credit to purchase supply from us at their historical purchase volumes, and their customers, in turn, may adopt conservation measures which reduce consumption, thereby reducing demand for product. Furthermore, when prices increase rapidly and dramatically, we may be unable to promptly pass our additional costs on to our customers, resulting in lower margins for us which could adversely affect our results of operations. Higher prices for the products we sell may (1) diminish our access to trade credit support and/or cause it to become more expensive and (2) decrease the amount of borrowings available for working capital under our credit agreement as a result of total available commitments, borrowing base limitations and advance rates thereunder.

        When prices for the products we sell decline, our exposure to risk of loss in the event of nonperformance by our customers of our forward contracts may be increased as they and/or their customers may breach their contracts and purchase the products we sell at the then lower retail market price. A significant decrease in the price for crude oil could adversely affect the economics of the domestic crude oil production for the product which, in turn, could have an adverse effect on our crude oil logistics activities and sales.

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Our debt levels may limit our flexibility in obtaining additional financing and in pursuing other business opportunities.

        We have a significant amount of debt. As of December 31, 2012, our total debt outstanding under our credit agreement was approximately $846.5 million. We have the ability to incur debt, including the capacity to borrow up to $1.5 billion under our credit facilities, subject to limitations in our credit agreement. Our level of indebtedness could have important consequences to us, including the following:

    our ability to obtain additional financing, if necessary, for working capital, capital expenditures, acquisitions or other purposes may be impaired or such financing may not be available on favorable terms;

    covenants contained in our existing and future credit and debt arrangements will require us to meet financial tests that may affect our flexibility in planning for and reacting to changes in our business, including possible acquisition opportunities;

    we will need a substantial portion of our cash flow to make principal and interest payments on our indebtedness, reducing the funds that would otherwise be available for operations, future business opportunities and distributions to unitholders;

    our debt level will make us more vulnerable than our competitors with less debt to competitive pressures or a downturn in our business or the economy generally; and

    our debt level may limit our flexibility in responding to changing business and economic conditions.

        Our ability to service our indebtedness depends upon, among other things, our financial and operating performance, which will be affected by prevailing economic conditions and financial, business, regulatory and other factors, some of which are beyond our control. If our operating results are not sufficient to service our current or future indebtedness, we will be forced to take actions, such as reducing or eliminating distributions, reducing or delaying our business activities, acquisitions, investments and/or capital expenditures, selling assets, restructuring or refinancing our indebtedness, or seeking additional equity capital or bankruptcy protection. We may not be able to effect any of these remedies on satisfactory terms, or at all.

A significant increase in interest rates could adversely affect our ability to service our indebtedness.

        The interest rates on our credit agreement are variable; therefore, we have exposure to movements in interest rates. A significant increase in interest rates could adversely affect our ability to service our indebtedness. The increased cost could make the financing of our business activities more expensive. These added expenses could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.

We may not be able to obtain funding on acceptable terms or obtain additional requested funding in excess of total commitments under our credit agreement, which could have a material adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.

        In the recent past, global financial markets and economic conditions were disrupted and volatile. The debt and equity capital markets were exceedingly distressed. These issues, along with significant write-offs in the financial services sector, the re-pricing of credit risk and the economic conditions, had made and, along with any other potential future economic or market uncertainties, could make it difficult to obtain funding.

        As a result, the cost of raising money in the debt and equity capital markets could increase while the availability of funds from those markets could diminish. The cost of obtaining money from the credit markets could increase as many lenders and institutional investors increase interest rates, enact tighter lending standards and reduce and, in some cases, cease to provide funding to borrowers.

        In addition, we may be unable to obtain adequate funding under our credit agreement because (i) one or more of our lenders may be unable to meet its funding obligations or (ii) our borrowing base under our credit agreement, as redetermined from time to time, may decrease as a result of price fluctuations, counterparty risk, advance rates and borrowing base limitations and customer nonpayment or nonperformance.

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        Due to these factors, we cannot be certain that funding will be available if needed and to the extent required or requested on acceptable terms. If funding is not available when needed, or is available only on unfavorable terms, we may be unable to maintain our business as currently conducted, enhance our existing business, complete acquisitions or otherwise take advantage of business opportunities or respond to competitive pressures, any of which could have a material adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.

Our credit agreement and the indenture governing our senior notes each contain operating and financial restrictions and covenants that may restrict our business and financing activities.

        The operating and financial restrictions and covenants in our credit agreement and the indenture governing our senior notes and any future financing agreements could restrict our ability to finance future operations or capital needs or to engage, expand or pursue our business activities. For example, our credit agreement restricts our ability to:

    grant liens;

    make certain loans or investments;

    incur additional indebtedness or guarantee other indebtedness;

    make any material change to the nature of our business or undergo a fundamental change;

    make any material dispositions;

    acquire another company;

    enter into a merger, consolidation, sale leaseback transaction or purchase of assets;

    make distributions if any potential default or event of default occurs;

    modify borrowing base components and advance rates; or

    make capital expenditures in excess of specified levels.

        In addition, the indenture governing our senior notes limits our ability to, among other things:

    incur additional indebtedness;

    make distributions to equity owners;

    make certain investments;

    restrict distributions by our subsidiaries;

    create liens;

    enter into sale-leaseback transactions;

    sell assets; or

    merge with other entities.

        Our ability to comply with the covenants and restrictions contained in our credit agreement and the indenture may be affected by events beyond our control, including prevailing economic, financial and industry conditions. If market or other economic conditions deteriorate, our ability to comply with these covenants may be impaired. If we violate any of the restrictions, covenants, ratios or tests in our credit agreement or the indenture, a significant portion of our indebtedness may become immediately due and payable, and our lenders' commitment to make further loans to us may terminate. We might not have, or be able to obtain, sufficient funds to make these accelerated payments. In addition, our obligations under our credit agreement are secured by substantially all of our assets, and if we are unable to repay our indebtedness under our credit agreement, the lenders could seek to foreclose on such assets.

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Restrictions in our credit agreement and the indenture limit our ability to pay distributions upon the occurrence of certain events.

        Our credit agreement and the indenture limit our ability to pay distributions upon the occurrence of certain events. For example, each of our credit agreement and the indenture limits our ability to pay distributions upon the occurrence of the following events, among others:

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

    failure to perform or otherwise comply with the covenants in the credit agreement, the indenture or in other loan documents to which we are a borrower; and

    a bankruptcy or insolvency event involving us, our general partner or any of our subsidiaries.

        Any subsequent refinancing of our current debt or any new debt could have similar restrictions. For more information regarding our credit agreement and the indenture, please read Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Credit Agreement" and Note 8 of Notes to Consolidated Financial Statements.

We can borrow money under our credit agreement to pay distributions, which would reduce the amount of credit available to operate our business.

        Our partnership agreement allows us to borrow under our credit agreement to pay distributions. Accordingly, we can make distributions on all our units even though cash generated by our operations may not be sufficient to pay such distributions. For more information, please read Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources" and Note 8 of Notes to Consolidated Financial Statements.

The enactment of derivatives legislation could have an adverse effect on our ability to use derivative instruments to reduce the effect of commodity price, interest rate and other risks associated with our business.

        On July 21, 2010, new comprehensive financial reform legislation, known as the Dodd-Frank Wall Street Reform and Consumer Protection Act (the "Act"), was enacted that establishes federal oversight and regulation of the over-the-counter derivatives market and entities, such as us, that participate in that market. The Act requires the Commodities Futures Trading Commission ("CFTC"), the SEC and other regulators to promulgate rules and regulations implementing the new legislation. In its rulemaking under the Act, the CFTC has issued final regulations to set position limits for certain futures and option contracts in the major energy markets and for swaps that are their economic equivalents. Certain bona fide hedging transactions would be exempt from these position limits. The position limits rule was vacated by the United States District Court for the District of Columbia in September of 2012 although the CFTC has stated that it will appeal the District Court's decision. The CFTC also has finalized other regulations, including critical rulemakings on the definition of "swap," "security-based swap," "swap dealer" and "major swap participant." The Act and CFTC rules also will require us, in connection with certain derivatives activities, to comply with clearing and trade-execution requirements (or take steps to qualify for an exemption to such requirements). In addition, new regulations may require us to comply with margin requirements although these regulations are not finalized and their application to us is uncertain at this time. Other regulations also remain to be finalized, and the CFTC recently has delayed the compliance dates for various regulations already finalized. As a result, it is not possible at this time to predict with certainty the full effects of the Act and CFTC rules on us and the timing of such effects. The Act also may require the counterparties to our derivative instruments to spin off some of their derivatives activities to a separate entity, which may not be as creditworthy as the current counterparty.

        The Act and any new regulations could significantly increase the cost of derivative contracts (including from swap recordkeeping and reporting requirements and through requirements to post collateral which could adversely affect our available liquidity), materially alter the terms of derivative contracts, reduce the availability of some derivatives to protect against risks we encounter, reduce our

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ability to monetize or restructure our existing derivative contracts, and potentially increase our exposure to less creditworthy counterparties. If we reduce our use of derivatives as a result of the Act and regulations, our results of operations may become more volatile and our cash flows may be less predictable, which could adversely affect our ability to plan for and fund capital expenditures. Finally, the Act was intended, in part, to reduce the volatility of oil and natural gas prices, which some legislators attributed to speculative trading in derivatives and commodity instruments related to oil and natural gas. Our revenues could therefore be adversely affected if a consequence of the Act and regulations is to lower commodity prices. Any of these consequences could have material adverse effect on our financial condition, results of operations and cash available for distributions to our unitholders.

Our risk management policies cannot eliminate all commodity risk, basis risk, or the impact of adverse market conditions which can adversely affect our financial condition, results of operations and cash available for distribution to our unitholders. In addition, any noncompliance with our risk management policies could result in significant financial losses.

        While our hedging policies are designed to minimize commodity risk, some degree of exposure to unforeseen fluctuations in market conditions remains. For example, we change our hedged position daily in response to movements in our inventory. If we overestimate or underestimate our sales from inventory, we may be unhedged for the amount of the overestimate or underestimate. Also, significant increases in the costs of the products we sell can materially increase our costs to carry inventory. We use our credit facility as our primary source of financing to carry inventory and may be limited on the amounts we can borrow to carry inventory.

        Basis risk describes the inherent market price risk created when a commodity of certain grade or location is purchased, sold or exchanged as compared to a purchase, sale or exchange of a like commodity at a different time or place. Transportation costs and timing differentials are components of basis risk. For example, we use the NYMEX to hedge our commodity risk with respect to pricing of energy products traded on the NYMEX. Physical deliveries under NYMEX contracts are made in New York Harbor. To the extent we take deliveries in other ports, such as Boston Harbor, we may have basis risk. In a backward market (when prices for future deliveries are lower than current prices), basis risk is created with respect to timing. In these instances, physical inventory generally loses value as basis declines over time. Basis risk cannot be entirely eliminated, and basis exposure, particularly in backward or other adverse market conditions, can adversely affect our financial condition, results of operations and cash available for distribution to our unitholders.

        We monitor processes and procedures to prevent unauthorized trading and to maintain substantial balance between purchases and sales or future delivery obligations. We can provide no assurance, however, that these steps will detect and/or prevent all violations of such risk management policies and procedures, particularly if deception or other intentional misconduct is involved.

We are exposed to trade credit risk and risk associated with our trade credit support in the ordinary course of our business activities.

        We are exposed to risks of loss in the event of nonperformance by our customers and by counterparties of our forward and futures contracts, options and swap agreements and by our suppliers. Some of our customers, counterparties and suppliers may be highly leveraged and subject to their own operating and regulatory risks. The tightening of credit in the financial markets may make it more difficult for customers and counterparties to obtain financing and, depending on the degree to which it occurs, there may be a material increase in the nonpayment and nonperformance of our customers and counterparties. Even if our credit review and analysis mechanisms work properly, we may experience financial losses in our dealings with other parties. Any increase in the nonpayment or nonperformance by our customers and/or counterparties and the nonperformance by our suppliers could reduce our ability to make distributions to our unitholders.

        Additionally, our access to trade credit support could diminish and/or become more expensive. Our ability to continue to receive sufficient trade credit on commercially acceptable terms could be adversely affected by fluctuations in petroleum product and renewable fuel prices or disruptions in the credit markets or for any other reason. Any of these events could adversely affect our financial condition, results of operations and cash available for distribution to our unitholders.

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We are exposed to performance risk in our supply chain.

        We rely upon our suppliers to timely produce the volumes and types of refined petroleum products, renewable fuels and crude oil for which they contract with us. In the event one or more of our suppliers does not perform in accordance with its contractual obligations, we may be required to purchase product on the open market to satisfy forward contracts we have entered into with our customers in reliance upon such supply arrangements. We may purchase refined petroleum products, renewable fuels and crude oil from a variety of suppliers under term contracts and on the spot market. In times of extreme market demand, we may be unable to satisfy our supply requirements. Furthermore, a portion of our supply comes from other countries, which could be disrupted by political events. In the event such supply becomes scarce, whether as a result of political events, natural disaster, logistical issues associated with delivery schedules or otherwise, we may not be able to satisfy our supply requirements. If any of these events were to occur, we may be required to pay more for product that we purchase on the open market, which could result in financial losses and adversely affect our financial condition, results of operations and cash available for distribution to our unitholders.

Historical prices for certain products we sell have been volatile and significant changes in such prices in the future may adversely affect our financial condition, results of operations and cash available for distribution to our unitholders.

        Historical prices for certain products we sell were volatile. General political conditions, acts of war or terrorism and instability in oil producing regions, particularly in the Middle East, Russia, Africa and South America, could significantly impact crude oil supplies and wholesale motor fuel costs. Significant increases and volatility in wholesale gasoline costs could result in significant increases in the retail price of motor fuel products and in lower margins per gallon. Increases in the retail price of motor fuel products could impact consumer demand for motor fuel. This volatility makes it extremely difficult to predict the impact future wholesale cost fluctuations will have on our operating results and financial condition. Dramatic increases in crude oil prices squeeze fuel margins because fuel costs typically increase faster than can pass along such increases to customers. Higher fuel prices trigger higher credit card expenses, because credit card fees are calculated as a percentage of the transaction amount, not as a percentage of gallons sold. A significant change in any of these factors could materially impact our customer's motor fuel gallon volumes, gross profit and overall customer traffic, which in turn could have a material adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.

New technologies and alternative fuel sources as well as higher prices could reduce demand for our gasoline products.

        Technological advances and alternative fuel sources, such as electric, hybrid or battery powered motor vehicles, may adversely affect the demand for gasoline. We could face additional competition from alternative energy sources as a result of future government-mandated controls or regulations which promote the use of alternative fuel sources. A reduction in demand for our gasoline products could have an adverse effect on our financial condition, results of operations and cash available for distributions to our unitholders. In addition, higher prices could reduce the demand for gasoline and adversely impact our gasoline sales. A reduction in gasoline sales could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.

Energy efficiency, higher prices, new technology and alternative fuels could reduce demand for our products.

        Increased conservation and technological advances have adversely affected the demand for home heating oil and residual oil. Consumption of residual oil has steadily declined over the last three decades. We could face additional competition from alternative energy sources as a result of future government-mandated controls or regulation further promoting the use of cleaner fuels. End users who are dual-fuel users have the ability to switch between residual oil and natural gas. Other end users may elect to convert to natural gas. During a period of increasing residual oil prices relative to the prices of natural gas, dual-fuel customers may switch and other end users may convert to natural gas. During periods of increasing home heating oil prices relative to the price of natural gas, residential users of home heating oil may also convert to natural gas. Such switching or conversion could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders. In addition, higher prices and new technologies and alternative fuel sources, such as electric, hybrid or battery powered motor vehicles, could reduce the demand for gasoline and adversely impact our gasoline sales. A reduction in gasoline sales could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.

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Erosion of the Mobil brand could have an adverse impact on our sales of Mobil-branded gasoline.

        We believe that the success of our acquisitions of retail gasoline stations and supply rights from ExxonMobil in 2010 and our acquisition of Alliance in 2012 may be dependent, in part, upon the continuing favorable reputation of the Mobil brand. Erosion of the value of the Mobil brand could have a negative impact on our gasoline sales, which in turn may cause our acquisition to be less profitable.

We depend upon rail and marine transportation services for a substantial portion of our logistics business in transporting the products we sell. A disruption in rail and marine transportation services could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.

        Hurricanes, flooding and other severe weather conditions could cause a disruption in rail and marine transportation services that could affect the flow of service. In addition, labor disputes between the railroads and their union employees and labor renegotiations, or a work stoppage at railroads, could also disrupt rail service. These events could result in service disruptions and increased cost which could also adversely affect our financial condition, results of operations and cash available for distribution to our unitholders. Other disruptions, such as those due to an act of terrorism or war, could also adversely affect our business.

Changes in government usage mandates and tax credits could adversely affect the availability and pricing of ethanol, which could negatively impact our gasoline sales.

        Future demand for ethanol will be largely dependent upon the economic incentives to blend based upon the relative value of gasoline and ethanol, taking into consideration the EPA's regulations on the RFS program and oxygenate blending requirements. A reduction or waiver of the RFS mandate or oxygenate blending requirements could adversely affect the availability and pricing of ethanol, which in turn could adversely affect our future gasoline and ethanol sales.

We may not be able to obtain state fund or insurance reimbursement of our environmental remediation costs.

        Where releases of refined petroleum products, renewable fuels and crude oil have occurred, federal and state laws and regulations require that contamination caused by such releases be assessed and remediated to meet applicable standards. Our obligation to remediate this type of contamination varies, depending upon applicable laws and regulations and the extent of, and the facts relating to, the release. A portion of the remediation costs may be recoverable from the reimbursement fund of the applicable state (with respect to gasoline stations) and/or from third party insurance after any deductible has been met, but there are no assurances that such reimbursement funds or insurance proceeds will be available to us.

Future consumer or other litigation could adversely affect our financial condition and results of operations.

        Our retail gasoline and convenience store operations are characterized by a high volume of customer traffic and by transactions involving an array of products.

        These operations carry a higher exposure to consumer litigation risk when compared to the operations of companies operating in many other industries. Consequently, we may become a party to individual personal injury or products liability and other legal actions in the ordinary course of our retail gasoline and convenience store business. Any such action could adversely affect our financial condition and results of operations. Additionally, we are occasionally exposed to industry-wide or class action claims arising from the products we carry or industry-specific business practices. Our defense costs and any resulting damage awards or settlement amounts may not be fully covered by our insurance policies. An unfavorable outcome or settlement of one or more of these lawsuits could have a material adverse effect on our financial condition, results of operations and cash available for distributions.

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We depend upon a small number of suppliers for a substantial portion of our convenience store merchandise inventory. A disruption in supply or an unexpected change in our relationships with our principal merchandise suppliers could have an adverse effect on our convenience store results of operations.

        We purchase convenience store merchandise inventory from a small number of suppliers for our directly operated convenience stores. A change of merchandise suppliers, a disruption in supply or a significant change in our relationships with our principal merchandise suppliers could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.

We face intense competition in our purchasing, terminalling, transporting, storage and logistics activities. Competition from other providers of refined petroleum products, renewable fuels, crude oil and natural gas that are able to supply our customers with those products and services at a lower price and have capital resources many times greater than ours could reduce our ability to make distributions to our unitholders.

        We are subject to competition from distributors and suppliers of refined petroleum products, renewable fuels, crude oil and natural gas that may be able to supply our customers with the same or comparable products and terminalling, transporting and storage services and logistics on a more competitive basis. We compete with terminal companies, major integrated oil companies and their marketing affiliates, wholesalers, producers and independent marketers of varying sizes, financial resources and experience. In our Northeast market, we compete in various product lines and for all customers. In the residual oil markets, however, where product is heated when stored and cannot be delivered long distances, we face less competition because of the strategic locations of our residual oil storage facilities. We also compete with natural gas suppliers and marketers in our home heating oil and residual oil product lines. Bunkering requires facilities at ports to service vessels. In various other geographic markets, particularly the unbranded gasoline and distillates markets, we compete with integrated refiners, merchant refiners and regional marketing companies. Our retail gasoline stations compete with unbranded and branded retail gas stations as well as supermarket and warehouse stores that sell gasoline.

        Some of our competitors are substantially larger than us, have greater financial resources and control greater supplies of refined petroleum products, renewable fuels, natural gas and crude oil than we do. If we are unable to compete effectively, we may lose existing customers or fail to acquire new customers, which could have a material adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders. For example, if a competitor attempts to increase market share by reducing prices, our operating results and cash available for distribution to our unitholders could be adversely affected. We may not be able to compete successfully with these companies, and our ability to compete could be harmed by factors including, but not limited to, price competition and the availability of alternative and less expensive fuels.

We may not be able to renew our leases or our agreements for dedicated storage when they expire.

        The bulk terminals we own or lease or at which we maintain dedicated storage facilities play a key role in moving product to our customers. We lease the entirety of two bulk terminals that we operate exclusively for our business and maintain dedicated storage facilities at another nine bulk terminals. The agreements governing these arrangements are subject to expiration at various dates through 2019. These arrangements may not be renewed when they expire or, if renewed, may not be renewed at rates and on terms at least as favorable. If these agreements are not renewed or we are unable to renew these agreements at rates and on terms at least as favorable, it could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.

We may not be able to lease sites we own or sub-lease sites we lease on favorable terms and any such failure could adversely affect our financial condition, results of operations and cash available for distribution to our unitholders.

        We may lease certain sites to dealers where the rent expense is more than the lease payments. If we are unable to obtain tenants on favorable terms for sites we own or lease, the lease payments we receive may not be adequate to cover our rent expense for leased sites and may not be adequate to ensure that we meet our debt service requirements. We cannot provide any assurance that our gross margin from the sale of transportation fuels and related convenience store items at these sites will be adequate to offset unfavorable lease terms. The occurrence of these events could adversely affect our financial condition, results of operations and cash available for distribution to our unitholders.

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A material amount of our terminalling capacity is controlled by one of our affiliates. Loss of that capacity could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.

        We currently have an exclusive throughput arrangement for a terminal located in Revere, Massachusetts with one of our affiliates, Global Petroleum Corp. (which entity is owned by Alfred A. Slifka and Richard Slifka). As of December 31, 2012, this facility accounted for approximately 20% of our storage capacity. We store distillates and gasoline at this facility. The throughput agreement for this facility expires in 2014. After expiration of the agreement, we can provide no assurance that Global Petroleum Corp. will continue to grant us exclusive use of the terminal or that the terms of a renegotiated agreement will be as favorable to us as the agreement it replaces. If we are unable to renew the agreement or unable to renew on terms at least as favorable, it could have a material adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.

Some of our sales are generated under contracts that must be renegotiated or replaced periodically. If we are unable to successfully renegotiate or replace these contracts, our financial condition, results of operations and cash available for distribution to our unitholders could be adversely affected.

        Most of our arrangements with our customers are renegotiated or replaced periodically. As these contracts expire, they must be renegotiated or replaced. We may be unable to renegotiate or replace these contracts when they expire, and the terms of any renegotiated contracts may not be as favorable as the contracts they replace. Whether these contracts are successfully renegotiated or replaced is often subject to factors beyond our control. Such factors include fluctuations in refined petroleum product, renewable fuel and natural gas prices, counterparty ability to pay for or accept the contracted volumes and a competitive marketplace for the services offered by us. If we cannot successfully renegotiate or replace our contracts or renegotiate or replace them on less favorable terms, sales from these arrangements could decline, and our financial condition, results of operations and cash available for distribution to our unitholders could be adversely affected.

Due to our lack of asset and geographic diversification, adverse developments in the terminals we use or in our operating areas would reduce our ability to make distributions to our unitholders.

        We rely primarily on sales generated from products distributed from the terminals we own or control or to which we have access. Furthermore, the majority of our assets and operations are located in the Northeast. Due to our lack of diversification in asset type and location, an adverse development in these businesses or areas, including adverse developments due to catastrophic events or weather and decreases in demand for refined petroleum products, renewable fuels and crude oil, could have a significantly greater impact on our results of operations and cash available for distribution to our unitholders than if we maintained more diverse assets and locations.

Our operations are subject to operational hazards and unforeseen interruptions for which we may not be adequately insured.

        We are not fully insured against all risks incident to our business. Our operations are subject to operational hazards and unforeseen interruptions such as natural disasters, adverse weather, accidents, fires, explosions, hazardous materials releases, mechanical failures, disruptions in supply infrastructure or logistics and other events beyond our control. If any of these events were to occur, we could incur substantial losses because of personal injury or loss of life, severe damage to and destruction of property and equipment, and pollution or other environmental damage resulting in curtailment or suspension of our related operations.

        We store gasoline and renewable fuels in underground and above ground storage tanks and, in the near future, we expect to store propane. Our operations are also subject to significant hazards and risks inherent in storing gasoline. These hazards and risks include, but are not limited to, fires, explosions, spills, discharges and other releases, any of which could result in distribution difficulties and disruptions, environmental pollution, governmentally-imposed fines or clean-up obligations, personal injury or wrongful death claims and other damage to our properties and the properties of others.

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        Furthermore, we may be unable to maintain or obtain insurance of the type and amount we desire at reasonable rates. As a result of market conditions, premiums and deductibles for certain of our insurance policies have increased and could escalate further. In some instances, certain insurance could become unavailable or available only for reduced amounts of coverage. If we were to incur a significant liability for which we are not fully insured, it could have a material adverse effect on our financial condition, results of operations and cash available for distribution to unitholders.

New, stricter environmental laws and regulations could significantly increase our costs, which could adversely affect our results of operations and financial condition.

        Our operations are subject to federal, state and local laws and regulations regulating product quality specifications and other environmental matters. The trend in environmental regulation is towards more restrictions and limitations on activities that may affect the environment over time. Our business may be adversely affected by increased costs and liabilities resulting from such stricter laws and regulations. We try to anticipate future regulatory requirements that might be imposed and plan accordingly to remain in compliance with changing environmental laws and regulations and to minimize the costs of such compliance. However, there can be no assurances as to the timing and type of such changes in existing laws or the promulgation of new laws or the amount of any required expenditures associated therewith.

Our terminalling operations are subject to federal, state and local laws and regulations relating to environmental protection and operational safety that could require us to incur substantial costs.

        The risk of substantial environmental costs and liabilities is inherent in terminal operations, and we may incur substantial environmental costs and liabilities. Our terminalling operations involving the receipt, storage and redelivery of refined petroleum products, renewable fuels and crude oil are subject to stringent federal, state and local laws and regulations governing the discharge of materials into the environment, or otherwise relating to the protection of the environment, operational safety and related matters. Compliance with these laws and regulations increases our overall cost of business, including our capital costs to maintain and upgrade equipment and facilities. We utilize a number of terminals that are owned and operated by third parties who are also subject to these stringent federal, state and local environmental laws in their operations. Their compliance with these requirements could increase the cost of doing business with these facilities.

        In addition, our operations could be adversely affected if shippers of refined petroleum products, renewable fuels and crude oil incur additional costs or liabilities associated with environmental regulations. These shippers could increase their charges to us or discontinue service altogether.

        Various governmental authorities, including the EPA, have the power to enforce compliance with these regulations and the permits issued under them, and violators are subject to administrative, civil and criminal penalties, including fines, injunctions or both. Joint and several liability may be incurred, without regard to fault or the legality of the original conduct, under federal and state environmental laws for the remediation of contaminated areas at our facilities and those where we do business. Private parties, including the owners of properties located near our terminal facilities and those with whom we do business, also may have the right to pursue legal actions against us to enforce compliance with environmental laws, as well as seek damages for personal injury or property damage. We may also be held liable for damages to natural resources.

        The possibility exists that new, stricter laws, regulations or enforcement policies could significantly increase our compliance costs and the cost of any remediation that may become necessary, some of which may be material. Our insurance may not cover all environmental risks and costs or may not provide sufficient coverage in the event an environmental claim is made against us. We may incur increased costs because of stricter pollution control requirements or liabilities resulting from noncompliance with required operating or other regulatory permits. New environmental regulations, such as those related to the emissions of greenhouse gases, might adversely affect our products and activities, including the storage of refined petroleum products, renewable fuels and crude oil, as well as waste management and our control of air emissions. Enactment of laws and passage of regulations regarding GHG emissions, or other actions to limit carbon dioxide emissions may reduce demand for fossil fuels and impact our business. Federal and state agencies also could impose additional safety regulations to which we would be subject. Because the laws and regulations applicable to our operations are subject to change, we cannot provide any assurance that compliance with future laws and regulations will not have a material effect on our results of operations.

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Increased regulation of greenhouse gas emissions could result in increased operating costs and reduced demand for refined petroleum products as a fuel source, which could reduce demand for our products, decrease our revenues and reduce our profitability.

        Combustion of fossil fuels, such as the refined petroleum products we sell, results in the emission of carbon dioxide into the atmosphere. On December 15, 2009, the EPA published its findings that emissions of carbon dioxide and other greenhouse gases present an endangerment to public health and the environment because emissions of such gases are, according to the EPA, contributing to warming of the earth's atmosphere and other climatic changes, and the EPA has begun to regulate GHG emissions pursuant to the Clean Air Act. In addition, it is possible federal legislation could be adopted in the future to restrict GHG, as President Obama has expressed support for a mandatory cap and trade program to restrict or regulate emissions of greenhouse gases, and Congress considered various proposals to reduce GHG emissions. Many states and regions have adopted GHG initiatives. Please read "Items 1. and 2. Business and Properties—Environmental—Air Emissions."

        There are many regulatory approaches currently in effect or being considered to address greenhouse gases, including possible future U.S. treaty commitments, new federal or state legislation that may impose a carbon emissions tax or establish a cap-and-trade program and regulation by the EPA. Future international, federal and state initiatives to control carbon dioxide emissions could result in increased costs associated with refined petroleum products consumption, such as costs to install additional controls to reduce carbon dioxide emissions or costs to purchase emissions reduction credits to comply with future emissions trading programs. Such increased costs could result in reduced demand for refined petroleum products and some customers switching to alternative sources of fuel which could have a material adverse effect on our financial condition, results of operations and cash available for distributions to our unitholders.

We are subject to federal, state and local laws and regulations that govern the product quality specifications of the refined petroleum products and renewable fuels we purchase, store, transport and sell.

        Various federal, state and local government agencies have the authority to prescribe specific product quality specifications to the sale of commodities. Our business includes such commodities. Changes in product quality specifications, such as reduced sulfur content in refined petroleum products, or other more stringent requirements for fuels, could reduce our ability to procure product and our sales volume, require us to incur additional handling costs and/or require the expenditure of capital. For instance, different product specifications for different markets could require additional storage. If we are unable to procure product or recover these costs through increased sales, we may not be able to meet our financial obligations. Failure to comply with these regulations could result in substantial penalties.

We are subject to federal and state environmental regulations which could have a material adverse effect on our retail operations business.

        Our retail operations are subject to extensive federal and state laws and regulations, including those relating to the protection of the environment, waste management, discharge of hazardous materials, pollution prevention, as well as laws and regulations relating to public safety and health. Certain of these laws and regulations may require assessment or remediation efforts. Retail operations with underground storage tanks ("USTs") are subject to federal and state regulations and legislation. Compliance with existing and future environmental laws regulating USTs may require significant capital expenditures and increased operating and maintenance costs. The operation of USTs also poses certain other risks, including damages associated with soil and groundwater contamination. Leaks from USTs which may occur at one or more of our gas stations may impact soil or groundwater and could result in fines or civil liability for us. We may be required to make material expenditures to modify operations, perform site cleanups or curtail operations.

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We are subject to federal and state non-environmental regulations which could have an adverse effect on our convenience store business and results of operations.

        Our convenience store business is subject to extensive governmental laws and regulations that include, but are not limited to, legal restrictions on the sale of alcohol, tobacco and lottery products, food safety and health requirements and public accessibility. Furthermore, state and local regulatory agencies have the power to approve, revoke, suspend, or deny applications for and renewals of permits and licenses relating to the sale of alcohol, tobacco and lottery products or to seek other remedies. A violation of or change in such laws and/or regulations could have an adverse effect on our convenience store business and results of operations.

Any terrorist attacks aimed at our facilities and any global and domestic economic repercussions from terrorist activities and the government's response could adversely affect our financial condition, results of operations and cash available for distribution to our unitholders.

        Since the September 11, 2001 terrorist attacks on the United States, the U.S. government has issued warnings that energy assets may be future targets of terrorist organizations. These developments have subjected our operations to increased risks. We incurred costs for providing facility security and may incur additional costs in the future with respect to the receipt, storage and distribution of our products. Additional security measures could also restrict our ability to distribute refined petroleum products, renewable fuels and crude oil. Any future terrorist attack on our facilities, or those of our customers, could have a material adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.

        Terrorist activity could lead to increased volatility in prices for home heating oil, gasoline and other products we sell, which could decrease our customers' demand for these products. Insurance carriers are required to offer coverage for terrorist activities as a result of federal legislation. We purchased this coverage with respect to our property and casualty insurance programs. This additional coverage resulted in additional insurance premiums which could increase further in the future.

We depend on key personnel for the success of our business.

        We depend on the services of our senior management team and other key personnel. The loss of the services of any member of senior management or key employee could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders. We may not be able to locate or employ on acceptable terms qualified replacements for senior management or other key employees if their services were no longer available.

        Certain executive officers of our general partner perform services for certain of our affiliates pursuant to shared services agreements. Please read Item 13, "Certain Relationships and Related Transactions, and Director Independence—Relationship of Management with Global Petroleum Corp. and Alliance Energy LLC."

We depend on unionized labor for the operation of certain of our terminals and at the facility in Revere, Massachusetts which is controlled and operated by one of our affiliates. Any work stoppages or labor disturbances at these facilities could disrupt our business.

        Any work stoppages or labor disturbances by our unionized labor force at our facilities could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders. In addition, employees who are not currently represented by labor unions may seek representation in the future, and any renegotiation of collective bargaining agreements may result in terms that are less favorable to us.

We rely on our information technology systems to manage numerous aspects of our business, and a disruption of these systems could adversely affect our business.

        We depend on our information technology ("IT") systems to manage numerous aspects of our business and to provide analytical information to management. Our IT systems are an essential component of our business and growth strategies, and a serious disruption to our IT systems could significantly limit our ability to manage and operate our business effectively. These systems are vulnerable to, among other things, damage and interruption from power loss or natural disasters, computer system and network failures, loss of telecommunication services, physical and electronic loss of data, security breaches and computer viruses. We have a disaster recovery plan in place, but this plan may not entirely prevent delays or other complications that could arise from an IT systems failure. Any failure or interruption in our IT systems could have a negative impact on our operating results, cause our business and competitive position to suffer and damage our reputation.

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If we fail to maintain an effective system of internal controls, then we may not be able to accurately report our financial results or prevent fraud. As a result, current and potential unitholders could lose confidence in our financial reporting, which would harm our business and the trading price of our common units.

        Effective internal controls are necessary for us to provide reliable financial reports, prevent fraud and operate successfully as a public company. If our efforts to maintain internal controls are not successful or if we are unable to maintain adequate controls over our financial processes and reporting in the future or if we are unable to comply with our obligations under Section 404 of the Sarbanes-Oxley Act of 2002, our operating results could be harmed or we may fail to meet our reporting obligations. Ineffective internal controls also could cause investors to lose confidence in our reported financial information, which would likely have a negative effect on the trading price of our common units.

Risks Related to our Structure

Our general partner and its affiliates have conflicts of interest and limited fiduciary duties, which may permit them to favor their own interests to the detriment of our unitholders.

        As of March 12, 2013, affiliates of our general partner, including directors and executive officers of our general partner, owned 41.9% of our common units and the entire general partner interest. Although our general partner has a fiduciary duty to manage us in a manner beneficial to us and our unitholders, the directors and officers of our general partner have a fiduciary duty to manage our general partner in a manner beneficial to its owners. Furthermore, certain directors and officers of our general partner are directors or officers of affiliates of our general partner. Conflicts of interest may arise between our general partner and its affiliates, on the one hand, and us and our unitholders, on the other hand. As a result of these conflicts, our general partner may favor its own interests and the interests of its affiliates over the interests of our unitholders. Please read "—Our partnership agreement limits our general partner's fiduciary duties to unitholders and restricts the remedies available to unitholders for actions taken by our general partner that might otherwise constitute breaches of fiduciary duty." These conflicts include, among others, the following situations:

    Our general partner is allowed to take into account the interests of parties other than us, such as affiliates of its members, in resolving conflicts of interest, which has the effect of limiting its fiduciary duty to our unitholders.

    Affiliates of our general partner may engage in competition with us under certain circumstances. See "—Certain members of the Slifka family and their affiliates may engage in activities that compete directly with us."

    Neither our partnership agreement nor any other agreement requires owners of our general partner to pursue a business strategy that favors us. Directors and officers of our general partner's owners have a fiduciary duty to make these decisions in the best interest of such owners which may be contrary to our interests.

    Some officers of our general partner who provide services to us devote time to affiliates of our general partner.

    Our general partner has limited its liability and reduced its fiduciary duties under the partnership agreement, while also restricting the remedies available to our unitholders for actions that, without these limitations, might constitute breaches of fiduciary duty. As a result of purchasing common units, unitholders consent to some actions and conflicts of interest that might otherwise constitute a breach of fiduciary or other duties under applicable state law.

    Our general partner determines the amount and timing of asset purchases and sales, borrowings, issuances of additional partnership securities and reserves, each of which can affect the amount of cash available for distribution to our unitholders.

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    Our general partner determines the amount and timing of any capital expenditures and whether a capital expenditure is a maintenance capital expenditure, which reduces distributable cash flow, or a capital expenditure for acquisitions or capital improvements, which does not, and determination can affect the amount of cash distributed to our unitholders.

    In some instances, our general partner may cause us to borrow funds in order to permit the payment of cash distributions, even if the purpose or effect of the borrowing is to make incentive distributions.

    Our general partner determines which costs incurred by it and its affiliates are reimbursable by us.

    Our partnership agreement does not restrict our general partner from causing us to pay it or its affiliates for any services rendered on terms that are fair and reasonable to us or entering into additional contractual arrangements with any of these entities on our behalf.

    Our general partner intends to limit its liability regarding our contractual and other obligations.

    Our general partner may exercise its limited right to call and purchase common units if it and its affiliates own more than 80% of the common units.

    Our general partner controls the enforcement of obligations owed to us by it and its affiliates.

    Our general partner decides whether to retain separate counsel, accountants or others to perform services for us.

        Please read Item 13, "Certain Relationships and Related Transactions, and Director Independence—Omnibus Agreement."

Our partnership agreement limits our general partner's fiduciary duties to unitholders and restricts the remedies available to unitholders for actions taken by our general partner that might otherwise constitute breaches of fiduciary duty.

        Our partnership agreement contains provisions that reduce the standards to which our general partner would otherwise be held by state fiduciary duty law. For example, our partnership agreement:

    permits our general partner to make a number of decisions in its individual capacity, as opposed to in its capacity as our general partner. This entitles our general partner to consider only the interests and factors that it desires, and it has no duty or obligation to give any consideration to any interest of, or factors affecting, us, our affiliates or any limited partner. Examples include the exercise of its limited call right, its voting rights with respect to the units it owns, its registration rights and its determination whether or not to consent to any merger or consolidation of us;

    provides that our general partner shall not have any liability to us or our unitholders for decisions made in its capacity as general partner so long as it acted in good faith, meaning it believed that the decision was in our best interests;

    generally provides that affiliated transactions and resolutions of conflicts of interest not approved by the conflicts committee of the board of directors of our general partner and not involving a vote of unitholders must be on terms no less favorable to us than those generally being provided to or available from unrelated third parties or be "fair and reasonable" to us and that, in determining whether a transaction or resolution is "fair and reasonable," our general partner may consider the totality of the relationships between the parties involved, including other transactions that may be particularly advantageous or beneficial to us; and

    provides that our general partner and its officers and directors will not be liable for monetary damages to us, our limited partners or assignees for any acts or omissions unless there has been a final and non-appealable judgment entered by a court of competent jurisdiction determining that the general partner or those other persons acted in bad faith or engaged in fraud or willful misconduct.

        By purchasing a common unit, a common unitholder will become bound by the provisions of the partnership agreement, including the provisions described above.

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Unitholders have limited voting rights and are not entitled to elect our general partner or its directors or remove our general partner without its consent, which could lower the trading price of our common units.

        Unlike the holders of common stock in a corporation, unitholders have only limited voting rights on matters affecting our business and, therefore, limited ability to influence management's decisions regarding our business. Unitholders have no right to elect our general partner or its board of directors on an annual or other continuing basis. The board of directors of our general partner is chosen entirely by its members and not by the unitholders. Furthermore, if the unitholders are dissatisfied with the performance of our general partner, they have limited ability to remove our general partner. As a result of these limitations, the price at which the common units trade could diminish because of the absence or reduction of a takeover premium in the trading price.

        The unitholders are currently unable to remove our general partner without its consent because affiliates of our general partner own sufficient units to be able to prevent removal of our general partner. The vote of the holders of at least 662/3% of all outstanding common units voting is required to remove our general partner. As of March 12, 2013, affiliates of our general partner, including directors and executive officers of our general partner, owned 41.9% of our common units.

We may issue additional units without unitholder approval, which would dilute unitholders' ownership interests.

        At any time, we may issue an unlimited number of limited partner interests of any type without the approval of our unitholders. The issuance by us of additional common units or other equity securities of equal or senior rank will have the following effects:

    our unitholders' proportionate ownership interest in us will decrease;

    the amount of cash available for distribution on each unit may decrease;

    the relative voting strength of each previously outstanding unit may be diminished; and

    the market price of the common units may decline.

The market price of our common units could be adversely affected by sales of substantial amounts of our common units, including sales by our existing unitholders.

        As of March 12, 2013, we had 27,430,563 common units outstanding. A substantial number of our securities may be sold in the future either pursuant to Rule 144 under the Securities Act of 1933 (the "Securities Act") or pursuant to a registration statement filed with the SEC. Rule 144 under the Securities Act provides that after a holding period of six months, non-affiliates may resell restricted securities of reporting companies, provided that current public information for the reporting company is available. After a holding period of one year, non-affiliates may resell without restriction, and affiliates may resell in compliance with the volume, current public information and manner of sale requirements of Rule 144. Pursuant to our partnership agreement, members of the Slifka family have registration rights with respect to the common units owned by them. Pursuant to the Registration Rights Agreement, AE Holdings has registration rights with respect to units issued in connection with the Alliance acquisition.

        Sales by any of our existing unitholders of a substantial number of our common units, or the perception that such sales might occur, could have a material adverse effect on the price of our common units or could impair our ability to obtain capital through an offering of equity securities.

        In recent years, the securities market has experienced extreme price and volume fluctuations. This volatility has had a significant effect on the market price of securities issued by many companies for reasons unrelated to the operating performance of these companies. Future market fluctuations may result in a lower price of our common units.

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An increase in interest rates may cause the market price of our common units to decline.

        Like all equity investments, an investment in our common units is subject to certain risks. In exchange for accepting these risks, investors may expect to receive a higher rate of return than would otherwise be obtainable from lower-risk investments. Accordingly, as interest rates rise, the ability of investors to obtain higher risk-adjusted rates of return by purchasing government-backed debt securities may cause a corresponding decline in demand for riskier investments generally, including yield-based equity investments such as publicly-traded limited partnership interests. Reduced demand for our common units resulting from investors seeking other more favorable investment opportunities may cause the trading price of our common units to decline.

Our general partner has a limited call right that may require unitholders to sell their common units at an undesirable time or price.

        If at any time our general partner and its affiliates own more than 80% of the common units, our general partner will have the right, but not the obligation, which it may assign to any of its affiliates or to us, to acquire all, but not less than all, of the common units held by unaffiliated persons at a price not less than their then-current market price. As a result, unitholders may be required to sell their common units at an undesirable time or price and may not receive any return on their investment. Unitholders may also incur a tax liability upon a sale of their units. Our general partner is not obligated to obtain a fairness opinion regarding the value of the common units to be repurchased by it upon exercise of the limited call right. There is no restriction in our partnership agreement that prevents our general partner from issuing additional common units and exercising its call right. If our general partner exercises its limited call right, the effect would be to take us private and, if the units were subsequently deregistered, we would no longer be subject to the reporting requirements of the Securities Exchange Act of 1934.

Our partnership agreement restricts the voting rights of unitholders owning 20% or more of our common units.

        Our partnership agreement restricts unitholders' voting rights by providing that any units held by a person that owns 20% or more of any class of units then outstanding, other than our general partner, its affiliates, their transferees and persons who acquired such units with the prior approval of the board of directors of our general partner, cannot vote on any matter. Our partnership agreement also contains provisions limiting the ability of unitholders to call meetings or acquire information about our operations, as well as other provisions limiting the unitholders' ability to influence the manner or direction of management.

Cost reimbursements due to our general partner and its affiliates will reduce cash available for distribution to our unitholders.

        Prior to making any distribution on the common units, we reimburse our general partner and its affiliates for all expenses they incur on our behalf, which is determined by our general partner in its sole discretion. These expenses include all costs incurred by the general partner and its affiliates in managing and operating us, including costs for rendering corporate staff and support services to us. We are managed and operated by directors and executive officers of our general partner. In addition, the majority of our operating personnel are employees of our general partner. Please read Item 13, "Certain Relationships and Related Transactions, and Director Independence." The reimbursement of expenses and payment of fees, if any, to our general partner and its affiliates could adversely affect our ability to pay cash distributions to our unitholders.

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Unitholders may not have limited liability if a court finds that unitholder action constitutes control of our business.

        A general partner of a partnership generally has unlimited liability for the obligations of the partnership, except for those contractual obligations of the partnership that are expressly made without recourse to the general partner. Our partnership is organized under Delaware law, and we conduct business in a number of other states. The limitations on the liability of holders of limited partner interests for the obligations of a limited partnership have not been clearly established in some of the other states in which we do business. A unitholder could be liable for our obligations as if he were a general partner if:

    a court or government agency determined that we were conducting business in a state but had not complied with that particular state's partnership statute; or

    a unitholder's right to act with other unitholders to remove or replace the general partner, approve some amendments to our partnership agreement or take other actions under our partnership agreement constitute "control" of our business.

Unitholders may have liability to repay distributions.

        Under certain circumstances, unitholders may have to repay amounts wrongfully returned or distributed to them. Under Delaware law, we may not make a distribution to unitholders if the distribution would cause our liabilities to exceed the fair value of our assets. Delaware law provides that for a period of three years from the date of the impermissible distribution, limited partners who received the distribution and who knew at the time of the distribution that it violated Delaware law will be liable to the limited partnership for the distribution amount. Purchasers of units who become limited partners are liable for the obligations of the transferring limited partner to make contributions to us that are known to the purchaser of units at the time it became a limited partner and for unknown obligations if the liabilities could be determined from the partnership agreement. Liabilities to partners on account of their partnership interests and liabilities that are non-recourse to us are not counted for purposes of determining whether a distribution is permitted.

The control of our general partner may be transferred to a third party without unitholder consent.

        Our general partner may transfer its general partner interest to a third party in a merger or in a sale of all or substantially all of its assets without the consent of the unitholders. Furthermore, there is no restriction in the partnership agreement on the ability of the members of our general partner from transferring their respective membership interests in our general partner to a third party. The new members of our general partner would then be in a position to replace the board of directors and officers of our general partner with their own choices and control the decisions taken by the board of directors and officers of our general partner.

Certain members of the Slifka family and their affiliates may engage in activities that compete directly with us.

        Mr. Alfred A. Slifka, Mr. Richard Slifka and their affiliates (other than us) are subject to noncompetition provisions in the omnibus agreement and business opportunity agreement. In addition Mr. Eric Slifka's and Mr. Andrew Slifka's employment agreements contain noncompetition provisions. These agreements do not prohibit Messrs. Alfred A. Slifka, Richard Slifka, Eric Slifka and certain affiliates of our general partner from owning certain assets or engaging in certain businesses that compete directly or indirectly with us. Please read Item 13, "Certain Relationships and Related Transactions, and Director Independence—Omnibus Agreement and—Business Opportunity Agreement."

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Tax Risks

Our tax treatment depends on our status as a partnership for federal income tax purposes, as well as our not being subject to a material amount of entity-level taxation by individual states. If the Internal Revenue Service, or IRS, treats us as a corporation for U.S. federal income tax purposes or we become subject to additional amounts of entity-level taxation for state tax purposes, it would substantially reduce the amount of cash available for payments on the notes and our other debt obligations.

        Despite the fact that we are a limited partnership under Delaware law, it is possible in certain circumstances for a publicly traded partnership such as ours to be treated as a corporation rather than a partnership for U.S. federal income tax purposes. Although we do not believe based upon our current operations that we are so treated, a change in our business or a change in current law could cause us to be treated as a corporation for U.S. federal income tax purposes or otherwise subject us to taxation as an entity.

        If we were treated as a corporation for U.S. federal income tax purposes, we would pay U.S. federal tax on our taxable income at the corporate tax rate, which is currently a maximum of 35%, and would likely pay state income tax at varying rates in some states where we do not currently pay taxes. Therefore, our treatment as a corporation would result in a material reduction in our anticipated cash flow and could materially adversely affect our ability to make payments on the notes and our other debt obligations.

        Current law may change so as to cause us to be treated as a corporation for U.S. federal income tax purposes or otherwise subject us to entity-level taxation. For example, from time to time, members of the U.S. Congress propose and consider substantive changes to the federal income tax laws that affect publicly traded partnerships. Currently, one such legislative proposal would eliminate the exception upon which we rely for our treatment as a partnership for U.S. federal income tax purposes. We are unable to predict whether any of these changes, or other proposals, will be reconsidered or will ultimately be enacted. Any such changes could negatively impact the amount of cash available for payments on the notes and our other debt obligations. At the state level, because of widespread state budget deficits, several states are evaluating ways to subject partnerships to entity-level taxation through the imposition of state income, franchise and other forms of taxation. Imposition of such a tax on us by any additional state will reduce the cash available for payments on the notes and our other debt obligations.

If we were subjected to a material amount of additional entity-level taxation by individual states, it would reduce our cash available for distribution to our unitholders.

        Changes in current state law may subject us to additional entity-level taxation by individual states. Because of widespread state budget deficits and other reasons, several states are evaluating ways to subject partnerships to entity-level taxation through the imposition of state income, franchise or other forms of taxation. If any state were to impose a tax upon us as an entity, the cash available for distribution to unitholders would be reduced and, therefore, adversely affect the value of an investment in our units.

        Our partnership agreement provides that if a law is enacted or existing law is modified or interpreted in a manner that subjects us to additional amounts of entity-level taxation for state or local income tax purposes, the minimum quarterly distribution amount and the target distribution amounts will be adjusted to reflect the impact of that law on us.

The tax treatment of publicly traded partnerships or an investment in our common units could be subject to potential legislative, judicial or administrative changes and differing interpretations, possibly on a retroactive basis.

        The present federal income tax treatment of publicly traded partnerships, including us, or an investment in our common units may be modified by administrative, legislative or judicial interpretation at any time. For example, from time to time, members of Congress propose and consider substantive changes to the existing federal income tax laws that affect publicly traded partnerships. One such recent legislative proposal would have eliminated the qualifying income exception to the treatment of all publicly traded partnerships as corporations, upon which we rely for our treatment as a partnership for U.S. federal income tax purposes. Any modification to the federal income tax laws and interpretations thereof may or may not be applied retroactively and could make it more difficult or impossible to meet the "qualifying income" exception for us to be treated as a partnership for U.S. federal income tax purposes, affect or cause us to change our business activities, affect the tax considerations of an investment in us, change the character or treatment of portions of our income and adversely affect an investment in our common units. We are unable to predict whether any of these changes, or other proposals, will be introduced or will ultimately be enacted. Any such changes could negatively impact the value of an investment in our common units.

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        Our partnership agreement provides that if a law is enacted or existing law is modified or interpreted in a manner that subjects us to taxation as a corporation or otherwise subjects us to entity-level taxation for federal income tax purposes, the minimum quarterly distribution and the target distribution amounts may be adjusted to reflect the impact of that law on us.

We have a subsidiary that is treated as a corporation for federal income tax purposes and subject to corporate-level income taxes.

        We conduct substantially all of our operations of our end-user business through a subsidiary that is organized as a corporation. In addition, prior to the acquisition of Alliance, the corporation, acting through Alliance as its management agent, engaged in the retail sale of gasoline and operated convenience stores with respect to certain of the stations we acquired from ExxonMobil and collected rents on personal property leased to dealers at other stations we acquired from ExxonMobil. Upon the completion of the Alliance acquisition, the corporation engages in the retail sale of gasoline and/or operates convenience stores with respect to certain of the stations we acquired from ExxonMobil and Alliance and collects rents on personal property leased to dealers and commissioned agents at other stations we acquired from ExxonMobil and Alliance. We may elect to conduct additional operations through this corporate subsidiary in the future. This corporate subsidiary is subject to corporate-level tax, which reduces the cash available for distribution to us and, in turn, to unitholders. If the IRS were to successfully assert that this corporation has more tax liability than we anticipate or legislation were enacted that increased the corporate tax rate, our cash available for distribution to unitholders would be further reduced.

If the IRS contests the federal income tax positions we take, the market for our common units may be adversely impacted, and the costs of any IRS contest will reduce our cash available for distribution to unitholders.

        We have not requested a ruling from the IRS with respect to our treatment as a partnership for federal income tax purposes. The IRS may adopt positions that differ from the tax positions we take. It may be necessary to resort to administrative or court proceedings to sustain some or all of the positions we take. A court may not agree with the positions we take. Any contest with the IRS may materially and adversely impact the market for our common units and the price at which they trade. In addition, because the costs will be borne indirectly by our unitholders and our general partner, the costs of any contest with the IRS will result in a reduction in cash available for distribution.

Unitholders may be required to pay taxes on their share of our income even if they do not receive any cash distributions from us.

        Because unitholders are treated as partners to whom we allocate taxable income, which could be different in amount than the cash we distribute, unitholders may be required to pay any federal income taxes and, in some cases, state and local income taxes on their share of our taxable income even if they do not receive any cash distributions from us.

Tax gain or loss on the disposition of our common units could be more or less than expected.

        If a unitholder sells his common units, he will recognize a gain or loss equal to the difference between the amount realized and his tax basis in those common units. Because distributions to a unitholder in excess of the unitholder's allocable share of our net taxable income decreases the unitholder's tax basis in his common units, the amount, if any, of such prior excess distributions with respect to the units sold will, in effect, become taxable income to him if the common units are sold at a price greater than his tax basis in the common units, even if the price he receives is less than his original cost. Furthermore, a substantial portion of the amount realized, whether or not representing gain, may be taxed as ordinary income to the unitholder due to potential recapture items, including depreciation recapture. In addition, because the amount realized includes a unitholder's share of our non-recourse liabilities, if a unitholder sells his units, he may incur a tax liability in excess of the amount of cash he receives from the sale.

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Tax-exempt entities and non-U.S. persons face unique tax issues from owning our common units that may result in adverse tax consequences to them.

        Investment in common units by tax-exempt entities, such as employee benefit plans, individual retirement accounts (known as IRAs), and non-U.S. persons raises issues unique to them. For example, virtually all of our income allocated to organizations exempt from federal income tax, including IRAs and other retirement plans, will be unrelated business taxable income and will be taxable to them. Distributions to non-U.S. persons will be reduced by withholding taxes imposed at the highest applicable tax rate, and non-U.S. persons will be required to file U.S. federal tax returns and pay tax on their shares of our taxable income. If you are a tax exempt entity or a non-U.S. person, you should consult your tax advisor before investing in our common units.

We treat each purchaser of our common units as having the same tax benefits without regard to the actual common units purchased. The IRS may challenge this treatment, which could adversely affect the value of the common units.

        To maintain the uniformity of the economic and tax characteristics of our common units, we have adopted certain depreciation and amortization positions that may not conform to all aspects of existing Treasury Regulations. A successful IRS challenge to those positions could adversely affect the amount of taxable income or loss allocated to our unitholders. It also could affect the gain from a unitholder's sale of common units or result in audit adjustments to our unitholders' tax returns without the benefit of additional deductions. Consequently, a successful IRS challenge could have a negative impact on the value of our common units.

We prorate our items of income, gain, loss and deduction between transferors and transferees of our units each month based upon the ownership of our units on the first day of each month, instead of on the basis of the date a particular unit is transferred. The IRS may challenge this treatment, which could change the allocation of items of income, gain, loss and deduction among our unitholders.

        We prorate our items of income, gain, loss and deduction between transferors and transferees of our units based upon the ownership of our units on the first day of each month, instead of on the basis of the date a particular unit is transferred. The use of this proration method may not be permitted under existing Treasury Regulations, and although the U.S. Treasury Department issued proposed Treasury Regulations allowing a similar monthly simplifying convention, such regulations are not final and do not specifically authorize the use of the proration method we have adopted. Accordingly, our counsel is unable to opine as to the validity of this method. If the IRS were to challenge our proration method or new Treasury Regulations were issued, we may be required to change the allocation of items of income, gain, loss and deduction among our unitholders.

A unitholder whose units are loaned to a "short seller" to cover a short sale of units may be considered as having disposed of those units. If so, the unitholder would no longer be treated for tax purposes as a partner with respect to those units during the period of the loan and may recognize gain or loss from the disposition.

        Because a unitholder whose units are loaned to a "short seller" to cover a short sale of units may be considered as having disposed of the loaned units, he may no longer be treated for tax purposes as a partner with respect to those units during the period of the loan to the short seller and the unitholder may recognize gain or loss from such disposition. Moreover, during the period of the loan to the short seller, any of our income, gain, loss or deduction with respect to those units may not be reportable by the unitholder and any cash distributions received by the unitholder as to those units could be fully taxable as ordinary income. Unitholders desiring to assure their status as partners and avoid the risk of gain recognition from a loan to a short seller are urged to modify any applicable brokerage account agreements to prohibit their brokers from borrowing their units.

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We have adopted certain valuation methodologies for U.S. federal income tax purposes that may result in a shift of income, gain, loss and deduction between our general partner and the unitholders. The IRS may challenge this treatment, which could adversely affect the value of the common units.

        When we issue additional units or engage in certain other transactions, we determine the fair market value of our assets and allocate any unrealized gain or loss attributable to our assets to the capital accounts of our unitholders and our general partner. Although we may from time to time consult with professional appraisers regarding valuation matters, including the valuation of our assets, we make many of the fair market value estimates of our assets ourselves using a methodology based on the market value of our common units as a means to measure the fair market value of our assets. Our methodology may be viewed as understating the value of our assets. In that case, there may be a shift of income, gain, loss and deduction between certain unitholders and our general partner, which may be unfavorable to such unitholders. Moreover, under our current valuation methods, subsequent purchasers of common units may have a greater portion of their Internal Revenue Code Section 743(b) adjustment allocated to our tangible assets and a lesser portion allocated to our intangible assets. The IRS may challenge our valuation methods, or our allocation of the Section 743(b) adjustment attributable to our tangible and intangible assets, and allocations of income, gain, loss and deduction between our general partner and certain of our unitholders.

        A successful IRS challenge to these methods or allocations could adversely affect the amount of taxable income or loss being allocated to our unitholders. It also could affect the amount of taxable gain from our unitholders' sale of common units and could have a negative impact on the value of the common units or result in audit adjustments to our unitholders' tax returns without the benefit of additional deductions.

The sale or exchange of 50% or more of our capital and profits interests during any twelve-month period will result in the termination of our partnership for federal income tax purposes.

        We will be considered to have terminated as a partnership for federal income tax purposes if there is a sale or exchange of 50% or more of the total interests in our capital and profits within a twelve-month period. For purposes of determining whether the 50% threshold has been met, multiple sales of the same interest will be counted only once. Our termination would, among other things, result in the closing of our taxable year for all unitholders, which could result in us filing two tax returns for one calendar year. However, pursuant to an IRS relief procedure, the IRS may allow, among other things, a constructively terminated partnership to provide a single Schedule K-1 for the calendar year in which a termination occurs. Our termination could also result in a significant deferral of depreciation deductions allowable in computing our taxable income. In the case of a unitholder reporting on a taxable year other than a calendar year, the closing of our taxable year may also result in more than twelve months of our taxable income or loss being includable in his taxable income for the year of termination. Our termination would not affect our classification as a partnership for federal income tax purposes but instead, we would be treated as a new partnership for federal income tax purposes. If we were treated as a new partnership, we would be required to make new tax elections and could be subject to penalties if we were unable to determine that a termination occurred.

Unitholders may be subject to state and local taxes and return filing requirements in jurisdictions where they do not live as a result of investing in our common units.

        In addition to federal income taxes, unitholders will likely be subject to other taxes, including state, local and non-U.S. taxes, unincorporated business taxes and estate, inheritance or intangible taxes that are imposed by the various jurisdictions in which we conduct business or own property now or in the future, even if they do not live in any of those jurisdictions. Unitholders will likely be required to file state and local income tax returns and pay state and local income taxes in some or all of these various jurisdictions. Further, unitholders may be subject to penalties for failure to comply with those requirements. As of December 31, 2012, we conducted business in 32 states, some of which impose a personal income tax as well as an income tax on corporations and other entities. We may own property or conduct business in other states or non-U.S. countries in the future. It is the unitholder's responsibility to file all U.S. federal, state, local and non-U.S. tax returns.

Item 1B.    Unresolved Staff Comments.

        None.

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Item 3.    Legal Proceedings.

    General

        Although we may, from time to time, be involved in litigation and claims arising out of our operations in the normal course of business, we do not believe that we are a party to any litigation that will have a material adverse impact on our financial condition or results of operations. Except as described below, we are not aware of any significant legal or governmental proceedings against us, or contemplated to be brought against us. We maintain insurance policies with insurers in amounts and with coverage and deductibles as our general partner believes are reasonable and prudent. However, we can provide no assurance that this insurance will be adequate to protect us from all material expenses related to potential future claims or that these levels of insurance will be available in the future at economically acceptable prices.

    Environmental

        In connection with the December 2012 acquisition of six New England gasoline stations from Mutual Oil Company, we assumed certain environmental liabilities, including certain ongoing remediation efforts. As a result, we recorded a total environmental liability of approximately $0.6 million which was recorded as a long-term liability at December 31, 2012.

        In connection with the March 2012 acquisition of Alliance, we assumed Alliance's environmental liabilities, including ongoing environmental remediation at certain of the retail stations owned by Alliance and future remediation activities required by applicable federal, state or local law or regulation. Remedial action plans are in place, as may be applicable with the state agencies regulating such ongoing remediation. Based on reports from environmental engineers, our estimated cost of the ongoing environmental remediation for which Alliance was responsible and future remediation activities required by applicable federal, state or local law or regulation is estimated to be approximately $16.1 million to be expended over an extended period of time. Certain environmental remediation obligations at the retail stations acquired by Alliance from ExxonMobil in 2011 are being funded by ExxonMobil, and therefore cost estimates for such obligations at these stations are not included in this estimate. As a result, we recorded, on an undiscounted basis, total environmental liabilities of approximately $16.1 million. At December 31, 2012, this liability had a remaining balance of approximately $15.0 million.

        In connection with the September 2010 acquisition of the retail gasoline stations from ExxonMobil, we assumed certain environmental liabilities, including ongoing environmental remediation at and monitoring activities at certain of the acquired sites and future remediation activities required by applicable federal, state or local law or regulation. Remedial action plans are in place with the applicable state regulatory agencies for the majority of these locations, including plans for soil and groundwater treatment systems at eight sites. Based on consultations with environmental engineers, our estimated cost of the remediation is expected to be approximately $30.0 million to be expended over an extended period of time. As a result, we recorded, on an undiscounted basis, total environmental liabilities of approximately $30.0 million. At December 31, 2012, this liability had a remaining balance of approximately $26.6 million.

        In connection with the June 2010 acquisition of three refined petroleum products terminals in Newburgh, New York, we assumed certain environmental liabilities, including certain ongoing remediation efforts. As a result, we recorded, on an undiscounted basis, a total environmental liability of approximately $1.5 million, which was recorded as a long-term liability at December 31, 2012.

        In connection with the November 2007 acquisition of ExxonMobil's Glenwood Landing and Inwood, New York terminals, we assumed certain environmental liabilities, including the remediation obligations under remedial action plans submitted by ExxonMobil to and approved by the New York Department of Environmental Conservation ("NYDEC") with respect to both terminals. As a result, we recorded, on an undiscounted basis, total environmental liabilities of approximately $1.2 million. At December 31, 2012, this liability had a remaining balance of approximately $0.3 million.

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        In connection with the May 2007 acquisition of ExxonMobil's Albany and Newburgh, New York and Burlington, Vermont terminals, we assumed certain environmental liabilities, including the remediation obligations under a proposed remedial action plan submitted by ExxonMobil to NYDEC with respect to the Albany, New York terminal. As a result, we recorded, on an undiscounted basis, total environmental liabilities of approximately $8.0 million. In June 2008, we submitted a remedial action work plan to NYDEC, implementing NYDEC's conditional approval of the remedial action plan submitted by ExxonMobil. We responded to NYDEC's requests for additional information and conducted pilot tests for the remediation outlined in the work plan. Based on the results of such pilot tests, we changed our estimate and reduced the environmental liability by $2.8 million during the fourth quarter ended December 31, 2008. In July 2009, NYDEC approved the remedial action work plan, and we signed a Stipulation Agreement with NYDEC to govern implementation of the approved plan. The remedial action work has been implemented pursuant to the approved work plan, and the post-remediation stage of operation, monitoring and maintenance has commenced and is ongoing. As a result, we changed our estimate and reduced the environmental liability by $1.7 million during the second quarter ended June 30, 2011. At December 31, 2012, this liability had a remaining balance of approximately $0.1 million.

        For additional information regarding our environmental liabilities, see Note 9 of Notes to Consolidated Financial Statements included elsewhere in this report.

    Other

        We received from the EPA, by letters dated November 2, 2011 and March 9, 2012, reporting requirements and testing orders (collectively, the "Requests for Information") for information under the Clean Air Act. The Requests for Information are part of an EPA investigation to determine whether we have violated sections of the Clean Air Act at certain of our terminal locations in New England with respect to residual oil and asphalt. We are complying with the Requests for Information. We do not believe that a violation has occurred nor do we believe any adverse determination in connection with such investigation would have a material impact on our operations.

        On June 3, 2011, a complaint was filed against Alliance in Hartford, Connecticut Superior Court under the title Syed Sons, Inc., et al. v. Alliance Energy LLC, et al., Hartford Superior Court, Docket No.: HHD-X04-CV-11-6022516 S. The complaint was filed by six dealers operating, in the aggregate, 24 properties in connection with Alliance's purchase of gasoline stations from ExxonMobil in February 2011. Also named in the suit were Exxon Mobil Corporation, Citizens Bank, N.A., the Gasoline and Automotive and Service Dealers of America ("GASDA") and Michael J. Fox, the Executive Director of GASDA. The complaint alleged, among other things, failure to comply with the Connecticut franchise statute and violations of the Connecticut unfair trade practices statute. In April 2012, the action was withdrawn as to Citizens Bank, N.A. On July 3, 2012, five of the plaintiff dealers, who operated in the aggregate, 23 of the 24 properties at issue, executed a Confidential Settlement and Release Agreement (the "July Settlement Agreement") with Alliance and withdrew their action. On March 12, 2013, the remaining plaintiff dealer, who operated a single location at issue, executed a Confidential Settlement and Release Agreement (the "March Settlement Agreement") with Alliance and withdrew their action. Neither the July Settlement Agreement results nor the March Settlement Agreement results had a material adverse effect on our operations.

Item 4.    Mine Safety Disclosures

        Not applicable.

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PART II

Item 5.    Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities.

        Our common units trade on the New York Stock Exchange under the symbol "GLP." The closing sale price per common unit on March 8, 2013 was $36.20. At the close of business on March 8, 2013, based upon information received from our transfer agent and brokers and nominees, we had 10,111 common unitholders, including beneficial owners of common units held in street name. The following table sets forth the range of the daily high and low sales prices per common unit as quoted on the New York Stock Exchange and the cash distributions per common unit for the periods indicated.

 
  Price Range    
 
 
  Cash Distribution
Per Common Unit (a)
 
 
  High   Low  

2012

                   

Fourth Quarter

  $ 27.91   $ 21.93   $ 0.5700  (b)

Third Quarter

    26.40     22.22     0.5325  

Second Quarter

    23.84     20.01     0.5250  

First Quarter

    24.75     21.88     0.5000  

2011

                   

Fourth Quarter

  $ 22.71   $ 14.73   $ 0.5000  

Third Quarter

    27.20     16.76     0.5000  

Second Quarter

    28.08     21.90     0.5000  

First Quarter

    29.98     24.19     0.5000  

(a)
Represents cash distributions attributable to the quarter. Cash distributions declared in respect of a calendar quarter are paid in the following calendar quarter.

(b)
The cash distribution for this quarter was paid on February 14, 2013 to unitholders of record on February 5, 2013.

        We intend to make cash distributions to unitholders on a quarterly basis, although there is no assurance as to the future cash distributions since they are dependent upon future earnings, capital requirements, financial condition and other factors. Our credit agreement prohibits us from making cash distributions if any potential default or event of default, as defined in the credit agreement, occurs or would result from the cash distribution.

        Within 45 days after the end of each quarter, we will distribute all of our available cash (as defined in our partnership agreement) to unitholders of record on the applicable record date. The amount of available cash is all cash on hand on the date of determination of available cash for the quarter;

    less the amount of cash reserves established by our general partner to:

    provide for the proper conduct of our business;

    comply with applicable law, any of our debt instruments or other agreements; or

    provide funds for distributions to unitholders and to our general partner for any one or more of the next four quarters.

        We will make distributions of available cash from distributable cash flow for any quarter in the following manner: 99.17% to the common unitholders, pro rata, and 0.83% to the general partner, until we distribute for each outstanding common unit an amount equal to the minimum quarterly distribution for that quarter; and thereafter, cash in excess of the minimum quarterly distribution is distributed to the unitholders and the general partner based on the percentages as provided below.

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        As holder of the incentive distribution rights, the general partner is entitled to incentive distributions if the amount we distribute with respect to any quarter exceeds specified target levels shown below:

 
   
  Marginal Percentage
Interest in Distributions
 
 
  Total Quarterly Distribution
Target Amount
  Unitholders   General Partner  

Minimum Quarterly Distribution

  $0.4625     99.17%     0.83%  

First Target Distribution

  $0.4625     99.17%     0.83%  

Second Target Distribution

  above $0.4625 up to $0.5375     86.17%     13.83%  

Third Target Distribution

  above $0.5375 up to $0.6625     76.17%     23.83%  

Thereafter

  above $0.6625     51.17%     48.83%  

        The equity compensation plan information required by Item 201(d) of Regulation S-K in response to this item is incorporated by reference from Item 12, "Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters—Equity Compensation Plan Table."

Recent Sales of Unregistered Securities

        None.

Issuer Purchases of Equity Securities

        We did not repurchase any of our common units during the quarter ended December 31, 2012.

Item 6.    Selected Financial Data.

        The following table presents selected historical financial and operating data of Global Partners LP for the years and as of the dates indicated. The selected historical financial data is derived from the historical consolidated financial statements of Global Partners LP.

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        This table should be read in conjunction with Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations" and the historical consolidated financial statements of Global Partners LP and the notes thereto included elsewhere in this report. In addition, this table presents non-GAAP financial measures which we use in our business. These measures are not calculated or presented in accordance with generally accepted accounting principles in the United States ("GAAP"). We explain these measures and present reconciliations to their most directly comparable financial measures calculated in accordance with GAAP in Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations—Results of Operations—Key Performance Indicators."

 
  Year Ended December 31,  
 
  2012   2011   2010   2009   2008  
 
  (dollars in millions except per unit amounts)
 

Statement of Income Data:

                               

Sales

  $ 17,626.0   $ 14,835.7   $ 7,801.5   $ 5,818.4   $ 9,019.1  

Cost of sales

    17,292.5     14,626.1     7,634.8     5,668.6     8,899.3  
                       

Gross profit

    333.5     209.6     166.7     149.8     119.8  

Selling, general and administrative expenses

    101.5     78.6     66.1     61.0     42.1  

Operating expenses

    140.4     73.6     47.8     35.0     31.8  

Restructuring charges

        2.0              

Amortization expense

    7.0     4.8     3.5     3.0     2.9  
                       

Total operating costs and expenses

    248.9     159.0     117.4     99.0     76.8  
                       

Operating income

    84.6     50.6     49.3     50.8     43.0  

Interest expense

    (36.3 )   (31.2 )   (22.3 )   (15.2 )   (20.8 )
                       

Income before income tax expense

    48.3     19.4     27.0     35.6     22.2  

Income tax expense

    (1.6 )           (1.5 )   (1.1 )
                       

Net Income

    46.7     19.4     27.0     34.1     21.1  

Less: General partner's interest in net income

    (1.2 )   (0.7 )   (0.6 )   (0.8 )   (0.6 )
                       

Limited partners' interest in net income

  $ 45.5   $ 18.7   $ 26.4   $ 33.3   $ 20.5  
                       

Basic net income per limited partner unit (1)

  $ 1.73   $ 0.88   $ 1.61   $ 2.56   $ 1.57  
                       

Diluted net income per limited partner unit (1)

  $ 1.71   $ 0.87   $ 1.59   $ 2.51   $ 1.57  
                       

Basic weighted average limited partner' units outstanding

    26.4     21.3     16.3     13.0     13.1  
                       

Diluted weighted average limited partner' units outstanding

    26.6     21.5     16.6     13.3     13.1  
                       

Cash Flow Data:

                               

Net cash (used in) provided by

                               

Operating activities

  $ 232.4   $ (17.4 ) $ (87.2 ) $ (61.1 ) $ 99.2  

Investment activities

    (226.5 )   (13.4 )   (263.0 )   (9.1 )   (11.5 )

Financing activities

    (4.3 )   32.7     351.9     69.9     (88.9 )

Other Financial Data:

                               

EBITDA (2)

  $ 135.8   $ 85.7   $ 72.4   $ 66.7   $ 58.1  

Distributable cash flow (3)

    80.8     46.7     46.0     45.4     34.1  

Capital expenditures—acquisitions (4)

    188.7         248.4          

Capital expenditures—maintenance and expansion (4)

    44.9     16.0     14.7     9.1     11.5  

Cash distributions per limited partner unit (5)

    2.06     2.00     1.96     1.95     1.95  

Operating Data:

                               

Normal heating degree days (6)

    5,661     5,630     5,630     5,630     5,630  

Actual heating degree days

    4,754     5,137     5,049     5,656     5,426  

Variance from normal heating degree days

    (16% )   (9% )   (10% )   1%     (4% )

Variance from prior year actual degree days

    (7% )   2%     (11% )   4%     (4% )

Total gallons sold (in millions)

    6,100     5,217     3,650     3,404     3,550  

Variance in volume sold from prior year

    17%     43%     7%     (4% )   8%  

Balance Sheet Data (at period end):

                               

Cash and cash equivalents

  $ 6.0   $ 4.3   $ 2.4   $ 0.6   $ 0.9  

Property and equipment, net

    712.3     408.8     422.7     159.3     162.0  

Total assets

    2,329.8     1,876.6     1,672.3     1,052.7     889.3  

Total current liabilities

    1,045.2     778.8     751.7     567.6     494.7  

Long-term debt

    762.8     731.1     593.5     312.1     225.3  

Total debt

    846.5     793.9     786.7     533.8     433.5  

Total liabilities

    1,893.3     1,561.3     1,395.5     895.3     745.8  

Partners' equity

    436.5     315.3     276.8     157.4     143.5  

(1)
See Note 2 of Notes to Consolidated Financial Statements included elsewhere in this report for net income per limited partner unit calculation.

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(2)
Earnings before interest, taxes, depreciation and amortization ("EBITDA") is a non-GAAP financial measure which is discussed under "Results of Operations—Evaluating Our Results of Operations" and reconciled to its most directly comparable GAAP financial measures under "Results of Operations—Key Performance Indicators" in Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations."

(3)
Distributable cash flow is a non-GAAP financial measure which is discussed under "Results of Operations—Evaluating Our Results of Operations" and reconciled to its most directly comparable GAAP financial measures under "Results of Operations—Key Performance Indicators" in Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations."

(4)
Capital expenditures are discussed in Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources."

(5)
Cash distributions declared in one calendar quarter are paid in the following calendar quarter. This amount is based on cash distributions paid during each respective year. See Note 14 of Notes to Consolidated Financial Statements included elsewhere in this report.

(6)
Degree days is an industry measurement of temperature designed to evaluate energy demand and consumption which is further discussed under "Results of Operations—Evaluating Our Results of Operations" in Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations."

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Item 7.    Management's Discussion and Analysis of Financial Condition and Results of Operations.

        The following discussion and analysis of financial condition and results of operations of Global Partners LP should be read in conjunction with the historical consolidated financial statements of Global Partners LP and the notes thereto included elsewhere in this report.

Overview

    General

        We are one of the largest distributors of gasoline (including gasoline blendstocks such as ethanol and naphtha), distillates (such as home heating oil, diesel and kerosene), residual oil and renewable fuels to wholesalers, retailers and commercial customers in the New England states and New York. We are a major multi-brand gasoline distributor and have a portfolio of approximately 1,000 owned, leased and/or supplied gasoline stations primarily in the Northeast. We are a leader in the logistics of transporting and marketing crude oil and other products from the mid-continent region of the United States and Canada to the East Coast and, commencing February 2013, the West Coast (see "Items 1. and 2. Business and Properties—Recent Developments" for a further discussion). We are also a distributor of natural gas. We purchase refined petroleum products, renewable fuels and crude oil primarily from domestic and foreign refiners and ethanol producers, crude oil producers, major and independent oil companies and trading companies, and we sell these products in three reporting segments: (i) Wholesale, (ii) Gasoline Distribution and Station Operations and (iii) Commercial which are discussed below.

        Collectively, we sold approximately $17.5 billion of refined petroleum products, renewable fuels, crude oil and natural gas for the year ended December 31, 2012. In addition, we had other revenues of approximately $124.1 million, primarily from convenience store sales at our directly operated stores and gasoline station rental income. As of December 31, 2012, we owned, leased or maintained dedicated storage facilities at 25 refined petroleum product bulk terminals, each with the capacity of more than 50,000 barrels, including 23 located throughout the Northeast, that are supplied primarily by marine transport, pipeline, rail and/or truck and that collectively have approximately 10.5 million barrels of storage capacity. Additionally, we have storage capacity at our Albany, New York terminal to store crude oil and at select locations to store renewable fuels. In Columbus, North Dakota we constructed a 100,000 barrel tank and truck offloading facility as part of the development of a hub for the gathering, storage, rail transloading, transportation and marketing of crude oil and other products. We also have throughput and exchange agreements at numerous bulk terminals and inland storage facilities. In addition, we have storage agreements at several of our terminals granting storage rights to third parties for which we receive a fee.

        Like most independent marketers, we base our pricing on spot prices, fixed prices or indexed prices and routinely use the NYMEX, CME and ICE or other counterparties to hedge the risk inherent in buying and selling commodities. Through the use of regulated exchanges or derivatives, we seek to maintain a position that is substantially balanced between purchased volumes and sales volumes or future delivery obligations.

    Wholesale

        We own, control or have access to one of the largest terminal networks of refined petroleum products and renewable fuels in the Northeast. We also engage in the logistics of gathering, storage, transportation and marketing of refined petroleum products, renewable fuels and crude oil. Our strategically located terminal assets, logistics capabilities, transloading facilities and access to railroad and barge transportation provide a "virtual pipeline" solution for the transportation of crude oil, renewable fuels and other products from the mid-continent region of the United States and Canada to the East and West Coasts.

    Gasoline Distribution and Station Operations

        As of December 31, 2012, we had a portfolio of approximately 1,000 owned, leased and/or supplied gasoline stations primarily in the Northeast.

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        In September 2010, we completed the acquisition from ExxonMobil Corporation of 190 retail gasoline stations, together with the rights to (i) supply Mobil-branded fuel to those stations as well as an additional 31 existing locations in Massachusetts, New Hampshire and Rhode Island, and (ii) expand supply opportunities for Mobil-branded and Exxon-branded fuel in certain other New England states. This acquisition expanded our wholesale supply business and added vertical integration to our transportation fuel business in New England. On March 1, 2012, we acquired Alliance, a gasoline distributor and operator of gasoline stations and convenience stores. As of the date of the acquisition, Alliance's portfolio included approximately 540 gasoline stations in the Northeast, of which it owned or held under long-term lease approximately 250 stations, and had supply contracts for the remaining stations. The Alliance acquisition expanded our geographic footprint for gasoline stations to include Connecticut, New Jersey, New York, Pennsylvania, Maine and Vermont. Alliance is a top-tier distributor of multiple brands, including Exxon, Mobil, Shell, Sunoco, CITGO and Gulf. Prior to the closing of the acquisition, Alliance was wholly owned by AE Holdings which is approximately 95% owned by members of the Slifka family. See Note 3 of Notes to Consolidated Financial Statements for additional information.

        On April 26, 2012, we entered into an agreement with Getty Realty to supply and provide management services to more than 200 of its gasoline stations in New York and New Jersey. On November 19, 2012, we signed a long-term lease agreement with Getty Realty for approximately 90 of those 200 sites, which enables us to supply gasoline to and operate gasoline stations in the New York City boroughs of Queens, Manhattan and the Bronx as well as in Long Island and Westchester County. The lease with Getty Realty significantly expands our retail gasoline and fuel distribution presence in the New York metro region.

    Commercial

        This segment includes sales and deliveries to end user customers in the public sector and to commercial and industrial end users of unbranded gasoline, home heating oil, diesel, kerosene, residual oil, renewable fuels and natural gas. Our Commercial segment also includes sales of custom blended distillates and residual oil delivered by barge or from a terminal dock to ships through bunkering activity.

    Products and Operational Structure

        Our products primarily include gasoline, distillates, residual oil, renewable fuels, crude oil and natural gas. We sell gasoline to branded and unbranded gasoline stations and other resellers of transportation fuels, as well as to customers in the public sector. The distillates we sell are used primarily for fuel for trucks and off-road construction equipment and for space heating of residential and commercial buildings. We receive and move crude oil by rail from the mid-continent region of the United States and Canada to the East Coast and, as of February 2013, the West Coast and sell it to refiners. We sell residual oil to major housing units, such as public housing authorities, colleges and hospitals and large industrial facilities that use processed steam in their manufacturing processes. In addition, we sell bunker fuel, which we can custom blend, to cruise ships, bulk carriers and fishing fleets. We sell our natural gas to end users. We have increased our sales in the non-weather sensitive components of our business, such as transportation fuels; however, we are still subject to the impact that warmer weather conditions may have on our home heating oil and residual oil sales.

        Due to the nature of our business and our customers' reliance, in part, on consumer travel and spending patterns, we may experience more demand for gasoline and gasoline blendstocks during the late spring and summer months than during the fall and winter. Travel and recreational activities are typically higher in these months in the geographic areas in which we operate, increasing the demand for gasoline and gasoline blendstocks that we distribute. Therefore, our volumes in gasoline and gasoline blendstocks are typically higher in the second and third quarters of the calendar year. As demand for some of our refined petroleum products, specifically home heating oil and residual oil for space heating purposes, is generally greater during the winter months, heating oil and residual oil sales are generally higher during the first and fourth quarters of the calendar year. These factors may result in significant fluctuations in our quarterly operating results.

        Generally, our wholesale customers use their own vehicles or contract carriers to take delivery of the gasoline and distillate products at bulk terminals and inland storage facilities that we own or control or with which we have throughput or exchange arrangements. Our crude oil is aggregated by truck or pipeline in the mid-continent, transported on land by train and shipped to refineries on the East Coast in barges. Ethanol is shipped primarily by rail and by barge. For our commercial customers, we generally arrange the delivery of the product to the customer's designated location, typically hiring third-party common carriers to deliver the product.

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        For several reasons, including the size of the Alliance acquisition, our strategic focus on Gasoline Distribution and Station Operations which increased in significance with the Alliance acquisition, changes to our organizational structure of this operating segment under one divisional president, and how performance is reviewed and decisions are made, we determined that we have three operating segments. Commencing with the quarter ended March 31, 2012, our three operating segments, which are also our reporting segments, are the following:

    Wholesale.  This reportable segment includes sales of unbranded gasoline (including gasoline blendstocks such as ethanol and naphtha) and diesel to unbranded gasoline customers and other resellers of transportation fuels. We sell home heating oil, diesel, kerosene and residual oil to home heating oil retailers and wholesale distributors. We also sell crude oil to refiners.

    Gasoline Distribution and Station Operations.  This reportable segment includes sales of branded and unbranded gasoline to gasoline stations and other sub-jobbers. This segment also includes gasoline, convenience store, car wash and other ancillary sales at our directly operated stores, as well as rental income from dealer leased gas stations.

    Commercial.  This reportable segment includes sales and deliveries to end user customers in the public sector and to large commercial and industrial end users of unbranded gasoline, home heating oil, diesel, kerosene, residual oil, renewable fuels and natural gas. In the case of commercial and industrial end user customers, we sell our products primarily either through a competitive bidding process or through contracts of various terms. This segment also includes sales of custom blended fuels delivered by barges or from a terminal dock to ships through bunkering activity. For years ended December 31, 2012, 2011 and 2010, the Commercial operating segment did not meet the quantitative metrics for disclosure as a reportable segment on a stand-alone basis. However, we have elected to present segment disclosures for the Commercial operating segment as we believe such disclosures are meaningful to the user of our financial information.

    Outlook

        This section identifies certain risks and certain economic or industry-wide factors that may affect our financial performance and results of operations in the future, both in the short-term and in the long-term. Our results of operations and financial condition depend, in part, upon the following:

    Our business is influenced by the overall forward market for refined petroleum products, renewable fuels and crude oil, and increases and/or decreases in the prices of these products may adversely impact our financial condition, results of operations and cash available for distribution to our unitholders and the amount of borrowing available for working capital under our credit agreement Results from our purchasing, storing, terminalling, transporting and selling operations are influenced by prices for these products, pricing volatility and the market for such products. Prices in the overall forward market for these products may affect our financial condition, results of operations and cash available for distribution to our unitholders. Our margins can be significantly impacted by the forward product pricing curve, often referred to as the futures market. We typically hedge our exposure to petroleum product and renewable fuel price moves with futures contracts and, to a lesser extent, swaps. In markets where futures prices are higher than current prices, referred to as contango, we may use our storage capacity to improve our margins by storing products we have purchased at lower prices in the current market for delivery to customers at higher prices in the future. In markets where futures prices are lower than current prices, referred to as backwardation, inventories can depreciate in value and hedging costs are more expensive. For this reason, we attempt to reduce our inventories in order to minimize these effects. When prices for the products we sell rise, some of our customers may have insufficient credit to purchase supply from us at their historical purchase volumes, and their customers, in turn, may adopt conservation measures which reduce consumption, thereby reducing demand for product. Furthermore, when prices increase rapidly and dramatically, we may be unable to promptly pass our additional costs on to our customers, resulting in lower margins for us which could adversely affect our results of operations. Higher prices for the products we sell may (1) diminish our access to trade credit support and/or cause it to become more expensive and (2) decrease the amount of borrowings available for working capital under our credit agreement as a result of total available commitments, borrowing base limitations and advance rates thereunder. When prices for the products we sell decline, our exposure to risk of loss in the event of nonperformance by our customers of our forward contracts may be increased as they and/or their customers may breach their contracts and purchase the products we sell at the then lower retail market price. A significant decrease in the price for crude oil could adversely affect the economics of the domestic crude oil production for the product which, in turn, could have an adverse effect on our crude oil logistics activities and sales.

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    We commit substantial resources to pursuing acquisitions, although there is no certainty that we will successfully complete any acquisitions or receive the economic results we anticipate from completed acquisitions. Consistent with our business strategy, we are continuously engaged in discussions with potential sellers of terminalling, storage, logistics and/or marketing assets, including gasoline stations, and related businesses. Our growth largely depends on our ability to make accretive acquisitions. We may be unable to make such accretive acquisitions for a number of reasons, including, but not limited to, the following: (1) we are unable to identify attractive acquisition candidates or negotiate acceptable purchase contracts; (2) we are unable to raise financing for such acquisitions on economically acceptable terms; or (3) we are outbid by competitors. In addition, we may consummate acquisitions that at the time of consummation we believe will be accretive but that ultimately may not be accretive. If any of these events were to occur, our future growth would be limited. We can give no assurance that our acquisition efforts will be successful or that any such acquisition will be completed on terms that are favorable to us.

    The condition of credit markets may adversely affect our liquidity.  In the recent past, world financial markets experienced a severe reduction in the availability of credit. Possible negative impacts in the future could include a decrease in the availability of borrowings under our credit agreement, increased counterparty credit risk on our derivatives contracts and our contractual counterparties requiring us to provide collateral. In addition, we could experience a tightening of trade credit from our suppliers.

    We depend upon rail and marine transportation services for a substantial portion of our logistics business in transporting the products we sell. A disruption in rail and marine transportation services could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders. Hurricanes, flooding and other severe weather conditions could cause a disruption in rail and marine transportation services that could affect the flow of service. In addition, labor disputes between the railroads and their union employees and labor renegotiations, or a work stoppage at railroads, could also disrupt rail service. These events could result in service disruptions and increased cost which could also adversely affect our financial condition, results of operations and cash available for distribution to our unitholders. Other disruptions, such as those due to an act of terrorism or war, could also adversely affect our business.

    Our gasoline and gasoline blendstocks financial results are seasonal and generally lower in the first and fourth quarters of the calendar year. Due to the nature of our business and our customers' reliance, in part, on consumer travel and spending patterns, we may experience more demand for gasoline and gasoline blendstocks during the late spring and summer months than during the fall and winter. Travel and recreational activities are typically higher in these months in the geographic areas in which we operate, increasing the demand for gasoline and gasoline blendstocks that we distribute. Therefore, our results of operations in gasoline and gasoline blendstocks are typically lower in the first and fourth quarters of the calendar year.

    Our heating oil and residual oil financial results are seasonal and generally lower in the second and third quarters of the calendar year. Demand for some refined petroleum products, specifically home heating oil and residual oil for space heating purposes, is generally higher during November through March than during April through October. We obtain a significant portion of these sales during the winter months. Therefore, our results of operations in heating oil and residual oil for the first and fourth calendar quarters are generally better than for the second and third quarters.

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    Warmer weather conditions could adversely affect our results of operations and financial condition. Weather conditions generally have an impact on the demand for both home heating oil and residual oil. Because we supply distributors whose customers depend on home heating oil and residual oil for space heating purposes during the winter, warmer-than-normal temperatures during the first and fourth calendar quarters in the Northeast can decrease the total volume we sell and the gross profit realized on those sales.

    Energy efficiency, higher prices, new technology and alternative fuels could reduce demand for our products. Increased conservation and technological advances have adversely affected the demand for home heating oil and residual oil. Consumption of residual oil has steadily declined over the last three decades. We could face additional competition from alternative energy sources as a result of future government-mandated controls or regulation further promoting the use of cleaner fuels. End users who are dual-fuel users have the ability to switch between residual oil and natural gas. Other end users may elect to convert to natural gas. During a period of increasing residual oil prices relative to the prices of natural gas, dual-fuel customers may switch and other end users may convert to natural gas. During periods of increasing home heating oil prices relative to the price of natural gas, residential users of home heating oil may also convert to natural gas. Such switching or conversion could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders. In addition, higher prices and new technologies and alternative fuel sources, such as electric, hybrid or battery powered motor vehicles, could reduce the demand for gasoline and adversely impact our gasoline sales. A reduction in gasoline sales could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.

    Changes in government usage mandates and tax credits could adversely affect the availability and pricing of ethanol, which could negatively impact our gasoline sales. Future demand for ethanol will be largely dependent upon the economic incentives to blend based upon the relative value of gasoline and ethanol, taking into consideration the EPA's regulations on the Renewable Fuels Standard ("RFS") program and oxygenate blending requirements. A reduction or waiver of the RFS mandate or oxygenate blending requirements could adversely affect the availability and pricing of ethanol, which in turn could adversely affect our future gasoline and ethanol sales.

    New, stricter environmental laws and regulations could significantly increase our costs, which could adversely affect our results of operations and financial condition. Our operations are subject to federal, state and local laws and regulations regulating product quality specifications and other environmental matters. The trend in environmental regulation is towards more restrictions and limitations on activities that may affect the environment over time. Our business may be adversely affected by increased costs and liabilities resulting from such stricter laws and regulations. We try to anticipate future regulatory requirements that might be imposed and plan accordingly to remain in compliance with changing environmental laws and regulations and to minimize the costs of such compliance. However, there can be no assurances as to the timing and type of such changes in existing laws or the promulgation of new laws or the amount of any required expenditures associated therewith.

Results of Operations

    Evaluating Our Results of Operations

        Our management uses a variety of financial and operational measurements to analyze our performance. These measurements include: (1) net product margin, (2) gross profit, (3) EBITDA, (4) distributable cash flow, (5) selling, general and administrative expenses ("SG&A"), (6) operating expenses, (7) net income per diluted limited partner unit and (8) degree day.

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    Net Product Margin

        We view net product margin as an important performance measure of the core profitability of our operations. We review net product margin monthly for consistency and trend analysis. We define net product margin as our sales minus product costs. Sales primarily include sales of unbranded and branded gasoline, distillates, residual oil, renewable fuels, crude oil and natural gas, as well as convenience store sales and gasoline station rental income. Product costs include the cost of acquiring the refined petroleum products, renewable fuels, crude oil and natural gas and all associated costs including shipping and handling costs to bring such products to the point of sale as well as product costs related to convenience store items. We also look at net product margin on a per unit basis (net product margin divided by volume). Net product margin is a non-GAAP financial measure used by management and external users of our consolidated financial statements to assess our business. Net product margin should not be considered an alternative to net income, operating income, cash flow from operations, or any other measure of financial performance presented in accordance with GAAP. In addition, our net product margin may not be comparable to net product margin or a similarly titled measure of other companies.

    Gross Profit

        We define gross profit as our sales minus product costs and terminal and gasoline station related depreciation expense allocated to cost of sales. Sales primarily include sales of unbranded and branded gasoline, distillates, residual oil, renewable fuels, crude oil and natural gas. Product costs include the cost of acquiring the refined petroleum products, renewable fuels, crude oil and natural gas and all associated costs to bring such products to the point of sale.

    EBITDA

        EBITDA is a non-GAAP financial measure used as a supplemental financial measure by management and external users of our consolidated financial statements, such as investors, commercial banks and research analysts, to assess:

    our compliance with certain financial covenants included in our debt agreements;

    our financial performance without regard to financing methods, capital structure, income taxes or historical cost basis;

    our ability to generate cash sufficient to pay interest on our indebtedness and to make distributions to our partners;

    our operating performance and return on invested capital as compared to those of other companies in the wholesale, marketing, storing and distribution of refined petroleum products, renewable fuels and crude oil, without regard to financing methods and capital structure; and

    the viability of acquisitions and capital expenditure projects and the overall rates of return of alternative investment opportunities.

        EBITDA should not be considered as an alternative to net income, operating income, cash flow from operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. EBITDA excludes some, but not all, items that affect net income, and this measure may vary among other companies. Therefore, EBITDA may not be comparable to similarly titled measures of other companies.

    Distributable Cash Flow

        Distributable cash flow is an important non-GAAP financial measure for our limited partners since it serves as an indicator of our success in providing a cash return on their investment. Distributable cash flow means our net income plus depreciation and amortization minus maintenance capital expenditures, as well as adjustments to eliminate items approved by the audit committee of the board of directors of our general partner that are extraordinary or non-recurring in nature and that would otherwise increase distributable cash flow. Specifically, this financial measure indicates to investors whether or not we have generated sufficient earnings on a current or historic level that can sustain or support an increase in our quarterly cash distribution. Distributable cash flow is a quantitative standard used by the investment community with respect to publicly traded partnerships. Distributable cash flow should not be considered an alternative to net income, operating income, cash flow from operations, or any other measure of financial performance presented in accordance with GAAP. In addition, our distributable cash flow may not be comparable to distributable cash flow or similarly titled measures of other companies.

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    Selling, General and Administrative Expenses

        Our SG&A expenses include, among other things, marketing costs, corporate overhead, employee salaries and benefits, pension and 401(k) plan expenses, discretionary bonuses, non-interest financing costs, professional fees and information technology expenses. Employee-related expenses including employee salaries, discretionary bonuses and related payroll taxes, benefits, and pension and 401(k) plan expenses are paid by our general partner which, in turn, is reimbursed for these expenses by us.

    Operating Expenses

        Operating expenses are costs associated with the operation of the terminals and gasoline stations used in our business. Lease payments and storage expenses, maintenance and repair, utilities, taxes, labor and labor-related expenses comprise the most significant portion of our operating expenses. These expenses remain relatively stable independent of the volumes through our system but fluctuate slightly depending on the activities performed during a specific period.

    Net Income Per Diluted Limited Partner Unit

        We use net income per diluted limited partner unit to measure our financial performance on a per-unit basis. Net income per diluted limited partner unit is defined as net income, divided by the weighted average number of outstanding diluted common units, or limited partner units, during the period.

    Degree Day

        A "degree day" is an industry measurement of temperature designed to evaluate energy demand and consumption. Degree days are based on how far the average temperature departs from a human comfort level of 65°F. Each degree of temperature above 65°F is counted as one cooling degree day, and each degree of temperature below 65°F is counted as one heating degree day. Degree days are accumulated each day over the course of a year and can be compared to a monthly or a long-term (multi-year) average, or normal, to see if a month or a year was warmer or cooler than usual. Degree days are officially observed by the National Weather Service and officially archived by the National Climatic Data Center. For purposes of evaluating our results of operations, we use the normal heating degree day amount as reported by the National Weather Service at its Logan International Airport station in Boston, Massachusetts.

    Years Ended December 31, 2012, 2011 and 2010

    Significant Activities-2012

        During 2012, we continued to expand our Gasoline Distribution and Station Operations segment. On March 1, 2012, we acquired Alliance, a gasoline distributor and operator of gasoline stations and convenience stores. As of the date of the acquisition, Alliance's portfolio included approximately 540 gasoline stations in the Northeast, of which it owned or held under long-term lease approximately 250 stations, and had supply contracts for the remaining stations. The Alliance acquisition expanded our geographic footprint for gasoline stations to include Connecticut, New Jersey, New York, Pennsylvania, Maine and Vermont. Alliance is a top-tier distributor of multiple brands, including Exxon, Mobil, Shell, Sunoco, CITGO and Gulf.

        On April 26, 2012, we entered into an agreement with Getty Realty to supply and provide management services to more than 200 of its gasoline stations in New York and New Jersey. On November 19, 2012, we signed a long-term lease agreement with Getty Realty for approximately 90 of those 200 sites to supply and operate gasoline station in the New York City boroughs of Queens, Manhattan and the Bronx as well as in Long Island and Westchester County. The initial lease term for the locations is 15 years and includes multiple five-year renewal options. The lease with Getty Realty significantly expands our retail gasoline and fuel distribution presence in the New York metro region.

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        In our Wholesale segment, we continued our expansion into crude oil logistics, including the gathering, storage, transportation and marketing of crude oil. We completed construction on our new 100,000 barrel tank and truck offloading facility in Columbus, North Dakota as part of the development of that location as a hub for the gathering, storage, transportation and marketing of crude oil and other products. In addition, in Albany, New York, we completed a build-out project that increased rail receipts and throughput storage capacities of ethanol and crude oil and converted certain storage tanks for the handling of crude oil. This expansion increased our capacity to receive and distribute crude oil and other products from the mid-continent from 55,000 barrels per day to 160,000 barrels per day and allows the terminal to offload two 120-car unit trains in a 24-hour period. Our rail expansion serves to enhance our "virtual pipeline" solution for the transportation of crude oil and other products from the mid-continent region to Albany. Our rail shipments to Albany average four or five days, with some shipments completed in as little as two and a half days. From Albany, it is then a one to one and a half day trip by barge to the East Coast refineries.

        We continued the construction of a new rail-fed propane storage and distribution facility near our terminal in Albany, New York. This will be a single line rail haul facility serviced by Canadian Pacific. We believe this storage location, which will have an initial capacity of 540,000 gallons, will be an attractive source of cost-competitive mid-continent propane for wholesale customers in the Northeast. We expect this project to be completed during the second quarter of 2013.

        Also in 2012, we signed a purchase agreement to acquire a 60% membership interest in Basin Transload, which operates two transloading facilities in Columbus and Beulah, North Dakota for crude oil and other products, with a combined rail loading capacity of 160,000 barrels per day. We completed this transaction on February 1, 2013. Please read "Items 1. and 2. Business and Properties—Recent Developments" for a further discussion.

    Significant Activities-2011

        In 2011, we continued initiating organic expansion projects. For example, in part, we (i) converted 230,000 barrels of storage capacity at our Albany, New York terminal that are utilized for either distillates or gasoline; (ii) brought into service an additional 200,000 barrels of distillates and crude oil storage capacity at this facility and (iii) converted two tanks to handle bio-fuel at our Providence, Rhode Island terminal.

        In March 2011, and pursuant to our 15-year brand fee agreement with ExxonMobil, which provides us with the ability to provide Mobil-branded fuel to other authorized Mobil distributors ("Mobil Sub-jobbers"), we began supplying Mobil-branded fuel to Mobil Sub-jobbers, including Alliance, in Massachusetts, New Hampshire, Rhode Island and Maine.

        In November 2011, we initiated an expansion project at our Albany, New York terminal to increase our rail car receipt and offloading capacity of ethanol and crude oil.

        In the fourth quarter of 2011, we began buying mid-continent crude oil and transporting it by rail to our Albany, New York terminal for storage and subsequent sale in barge load quantities. We also initiated a project to store product in North Dakota.

    Significant Activities-2010

        In June 2010, we acquired three refined petroleum products terminals located in Newburgh, New York. We believe the acquisition strengthened our presence along the Hudson River in southeastern New York and enhanced terminal operating efficiencies with our adjacent facility.

        In September 2010, we acquired Mobil-branded retail gasoline stations located in Massachusetts, New Hampshire and Rhode Island and the right to supply Mobil-branded gasoline and diesel fuel to such stations and to Mobil-branded stations that are owned and operated by independent dealers. The acquisition expanded our wholesale supply business and added vertical integration to our transportation fuel business.

        In October 2010, we completed an ethanol and rail expansion project that added 180,000 barrels of ethanol storage at our Albany, New York terminal. The project included modifications that enabled the terminal to schedule the delivery of 80-car trains of ethanol and allows ethanol to be shipped directly on a single rail line from the Midwest. Beyond supplying our own business, we further invested in our Albany terminal by installing a marine vapor recovery system for barge/vessel-loading of ethanol and gasoline at the dock, and expanding the rack to allow for additional ethanol and gasoline sales. We believe the supply efficiencies gained through this project position us to be a premier cost effective supplier of gasoline and ethanol to the Northeast. In a separate and complementary project, we converted two distillate storage tanks to gasoline storage at the Albany facility. These initiatives, combined with the return to service of three previously out-of-service tanks, increased the total storage capacity of our Albany terminal to approximately 1.2 million barrels, up from 737,000 barrels when we acquired the terminal in May 2007.

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    Events That Impacted Results

        During the year ended December 31, 2012, we experienced the following events:

    In our Gasoline Distribution and Station Operations segment, our sales, volume and net product margin significantly increased due primarily to our acquisition of Alliance, as well as a full year of sales of Mobil-branded fuel to Mobil Sub-jobbers and to the Getty Realty agreements.

    In our Wholesale segment, our continued expansion into crude oil logistics, including the gathering, storage, transportation and marketing of crude oil, improved our Wholesale segment net product margin.

    We believe our wholesale gasoline business was negatively impacted by a challenging futures market, which increased our hedging costs for 2012, and less favorable buying opportunities which reduced our wholesale gasoline net product margin.

    We believe our wholesale distillate business was negatively impacted due to less favorable buying opportunities and warmer weather in 2012 compared to 2011.

    The price for heating oil at December 31, 2012 compared to the price at December 31, 2011 increased by 4%. We believe heating oil conservation and conversions to natural gas continued during 2012.

    Temperatures for 2012 were 16% warmer than normal and 7% warmer than 2011 which negatively affected demand for our weather-related products during the year.

    In connection with the acquisition of Alliance, we had one-time acquisition costs of approximately $4.0 million for 2012.

    Our interest expense increased by 17% for 2012, due primarily to additional borrowings associated with the acquisition of Alliance.

    In our Gasoline Distribution and Station Operations segment, declining gasoline prices typically improve our gasoline net product margins and rising gasoline prices typically compress our gasoline net product margins. Gasoline prices increased during the first and third quarters of 2012, which compressed our gasoline net product margins, and declined in the second and fourth quarters, which improved our gasoline net product margins.

    Our net product margins for 2012 were also affected by a variety of other factors, such as movement of products between Europe and the United States, weekly and monthly refinery output levels, changes in local, domestic and worldwide inventory levels, seasonality and supply disruptions.

        During 2011, we experienced the following events:

    Refined petroleum product and renewable fuel prices were higher during 2011 compared to 2010.

    Our aggregate volume of product sold increased by approximately 43% for 2011 compared to 2010, due to an increase in bulk supply and exchange activity, strong demand for blendstocks, primarily ethanol, and the growth in our gasoline business as a result of a full year of ownership of our 2010 acquisitions and the commencement of gasoline sales to Mobil Sub-jobbers under the brand fee agreement with ExxonMobil.

    Temperatures for 2011 were 9% warmer than normal.

    We increased our reserve for bad debts by approximately $1.9 million for 2011, substantially due to specific risks related to one customer.

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    We reduced our workforce by approximately 10% which resulted in restructuring charges of approximately $2.0 million for 2011.

    Our interest expense increased by 40% for 2011, primarily due to additional borrowings as a result of our 2010 acquisitions and to higher refined petroleum product and renewable fuel prices which increased our working capital requirements.

    We believe heating oil conservation and conversions to natural gas continued during 2011.

    Our operating expenses increased by $25.7 million for 2011 compared to 2010, primarily due to a full year of operations of the gasoline stations we acquired from ExxonMobil in September 2010.

    We continued to experience a decline in our residual oil sales and volumes.

    We believe our margins for 2011 were negatively impacted by less favorable market conditions and fewer advantageous purchasing opportunities in our distillates business and by a backward forward product pricing curve in our wholesale gasoline business.

    We believe our margins for 2011 were also affected by a variety of other factors, such as movement of products between Europe and the United States, weekly and monthly refinery output levels, changes in local, domestic and worldwide inventory levels, seasonality and supply dislocations.

        During the year ended December 31, 2010:

    Refined petroleum product prices increased during 2010.

    We increased our reserve for bad debts by approximately $1.1 million for 2010, substantially due to specific risks related to one customer.

    Temperatures for 2010 were 10% warmer than normal.

    We believe heating oil conservation and conversions to natural gas continued during 2010.

    We believe our results for the fourth quarter 2010 were negatively impacted due, in part, to adverse market conditions and fewer advantageous purchasing opportunities primarily in our distillates business. We believe that these market conditions and fewer purchasing opportunities did not adversely impact the performance of our gasoline business including the acquisition of retail gasoline stations and supply rights from ExxonMobil.

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        The following table provides the percentage increases (decreases) in refined petroleum product and natural gas prices at the end of each quarter in 2012 as compared to each comparable quarter in 2011 and at the end of each quarter in 2011 as compared to each comparable quarter in 2010:

Period:
  Heating
Oil
$ per
gallon (1)
  Gasoline
$ per
gallon (1)
  Residual
Oil
$ per
gallon (2)
  Natural
Gas
$ per gallon
equivalent (3)

2012 compared to 2011

               

At March 31, 2011

  $3.09   $3.11   $2.45   $0.73

At March 31, 2012

  $3.17   $3.39   $2.82   $0.40

Change

  3%   9%   15%   (45%)

At June 30, 2011

 

$2.93

 

$3.03

 

$2.51

 

$0.73

At June 30, 2012

  $2.70   $2.73   $2.24   $0.75

Change

  (8%)   (10%)   (11%)   3%

At September 30, 2011

 

$2.79

 

$2.63

 

$2.29

 

$0.62

At September 30, 2012

  $3.17   $3.34   $2.50   $0.49

Change

  14%   27%   9%   (21%)

At December 31, 2011

 

$2.93

 

$2.69

 

$2.36

 

$0.61

At December 31, 2012

  $3.05   $2.81   $2.34   $1.61

Change

  4%   4%   (1%)   163%

2011 compared to 2010

               

At March 31, 2010

  $2.16   $2.31   $1.76   $0.63

At March 31, 2011

  $3.09   $3.11   $2.45   $0.73

Change

  43%   35%   39%   16%

At June 30, 2010

 

$1.98

 

$2.06

 

$1.61

 

$0.75

At June 30, 2011

  $2.93   $3.03   $2.51   $0.73

Change

  48%   47%   56%   (3%)

At September 30, 2010

 

$2.24

 

$2.04

 

$1.74

 

$0.62

At September 30, 2011

  $2.79   $2.63   $2.29   $0.62

Change

  25%   29%   32%  

At December 31, 2010

 

$2.54

 

$2.45

 

$1.86

 

$0.76

At December 31, 2011

  $2.93   $2.69   $2.36   $0.61

Change

  15%   9%   27%   (19%)

(1)
Source: New York Mercantile Exchange (closing price)

(2)
Source: Platts Oilgram Price Report (6-1% New York Harbor; average)

(3)
Source: Platts Gas Daily Report (Tennessee zone delivered)

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    Key Performance Indicators

        The following table provides a summary of some of the key performance indicators that may be used to assess our results of operations. These comparisons are not necessarily indicative of future results (in thousands, except per unit data):

 
  Year Ended December 31,  
 
  2012   2011 (1)   2010 (1)  

Net income

  $ 46,743   $ 19,352   $ 27,038  

Net income per diluted limited partner unit (2)

 
$

1.71
 
$

0.87
 
$

1.59
 

EBITDA (3)

 
$

135,799
 
$

85,711
 
$

72,437
 

Distributable cash flow (4)

 
$

80,769
 
$

46,741
 
$

46,035
 

Wholesale Segment:

                   

Volume (gallons)

    4,793,538     4,436,117     3,251,933  

Sales

                   

Gasoline and gasoline blendstocks

  $ 8,827,621   $ 8,660,412   $ 4,270,844  

Other oils and related products (5)

    4,933,289     3,936,505     2,720,082  
               

Total

  $ 13,760,910   $ 12,596,917   $ 6,990,926  

Net product margin

                   

Gasoline and gasoline blendstocks

  $ 54,639   $ 56,224   $ 54,065  

Other oils and related products (5)

    90,790     67,609     90,346  
               

Total

  $ 145,429   $ 123,833   $ 144,411  

Gasoline Distribution and Station Operations Segment:

                   

Volume (gallons)

    954,315     442,879     149,027  

Sales (6)

                   

Gasoline

  $ 3,024,775   $ 1,404,988   $ 353,448  

Station operations (7)

    124,131     58,786     16,105  
               

Total

  $ 3,148,906   $ 1,463,774   $ 369,553  

Net product margin

                   

Gasoline

  $ 139,706   $ 56,690   $ 14,017  

Station operations (7)

    66,384     31,491     8,885  
               

Total

  $ 206,090   $ 88,181   $ 22,902  

Commercial Segment:

                   

Volume (gallons)

    352,210     338,210     249,481  

Sales

  $ 716,181   $ 775,038   $ 441,080  

Net product margin

  $ 18,652   $ 21,975   $ 15,033  

Combined sales and net product margin:

                   

Sales

  $ 17,625,997   $ 14,835,729   $ 7,801,559  

Net product margin (8)

  $ 370,171   $ 233,989   $ 182,346  

Depreciation allocated to cost of sales

    36,683     24,391     15,628  
               

Combined gross profit

  $ 333,488   $ 209,598   $ 166,718  
               

Weather conditions:

                   

Normal heating degree days

    5,661     5,630     5,630  

Actual heating degree days

    4,754     5,137     5,049  

Variance from normal heating degree days

    (16% )   (9% )   (10% )

Variance from prior period actual heating degree days

    (7% )   2%     (11% )

(1)
Segment reporting results for the prior periods have been reclassified to conform to our current presentation.

(2)
See Note 2 of Notes to Consolidated Financial Statements for net income per diluted limited partner unit calculation.

(3)
EBITDA is a non-GAAP financial measure which is discussed above under "—Evaluating Our Results of Operations." The table below presents reconciliations of EBITDA to the most directly comparable GAAP financial measures.

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(4)
Distributable cash flow is a non-GAAP financial measure which is discussed above under "—Evaluating Our Results of Operations." The table below presents reconciliations of distributable cash flow to the most directly comparable GAAP financial measures.

(5)
Other oils and related products primarily consist of distillates, residual oil and, commencing in the fourth quarter ended December 31, 2011, crude oil.

(6)
On March 1, 2012, we completed our acquisition of Alliance (see Note 3 of Notes to Consolidated Financial Statements). As these assets were not in place for a portion of the year ended December 31, 2012 or for any portion of the years ended December 31, 2011 and 2010, the above results are not directly comparable for periods prior to March 1, 2012.

(7)
Station operations primarily consist of convenience store sales at our directly operated stores and gasoline station rental income.

(8)
Net product margin is a non-GAAP financial measure which is discussed above under "—Evaluating Our Results of Operations." The table above includes a reconciliation of net product margin on a combined basis to gross profit, a directly comparable GAAP financial measure.

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        The following table presents reconciliations of EBITDA to the most directly comparable GAAP financial measures on a historical basis (in thousands):

 
  Year Ended December 31,  
 
  2012   2011   2010  

Reconciliation of net income to EBITDA:

                   

Net income

  $ 46,743   $ 19,352   $ 27,038  

Depreciation and amortization and amortization of deferred financing fees

    51,211     35,082     23,089  

Interest expense

    36,268     31,209     22,310  

Income tax expense

    1,577     68      
               

EBITDA

  $ 135,799   $ 85,711   $ 72,437  
               

Reconciliation of net cash provided by (used in) operating activities to EBITDA:

                   

Net cash provided by (used in) operating activities

  $ 232,452   $ (17,357 ) $ (87,194 )

Net changes in operating assets and liabilities and certain non-cash items

    (134,498 )   71,791     137,321  

Interest expense

    36,268     31,209     22,310  

Income tax expense

    1,577     68      
               

EBITDA

  $ 135,799   $ 85,711   $ 72,437  
               

        The following table presents reconciliations of distributable cash flow to the most directly comparable GAAP financial measures on a historical basis (in thousands):

 
  Year Ended December 31,  
 
  2012   2011   2010  

Reconciliation of net income to distributable cash flow:

                   

Net income

  $ 46,743   $ 19,352   $ 27,038  

Depreciation and amortization and amortization of deferred financing fees

    51,211     35,082     23,089  

Amortization of routine bank refinancing fees (1)

    (4,073 )   (3,467 )    

Maintenance capital expenditures

    (13,112 )   (4,226 )   (4,092 )
               

Distributable cash flow

  $ 80,769   $ 46,741   $ 46,035  
               

Reconciliation of net cash provided by (used in) operating activities to distributable cash flow:

                   

Net cash provided by (used in) operating activities

  $ 232,452   $ (17,357 ) $ (87,194 )

Net changes in operating assets and liabilities and certain non-cash items

    (134,498 )   71,791     137,321  

Amortization of routine bank refinancing fees (1)

    (4,073 )   (3,467 )    

Maintenance capital expenditures

    (13,112 )   (4,226 )   (4,092 )
               

Distributable cash flow

  $ 80,769   $ 46,741   $ 46,035  
               

(1)
Commencing with the quarter ended March 31, 2011, our calculation of distributable cash flow excludes non-cash amortization of deferred financing fees related to routine bank refinancing fees. Amortization of deferred financing fees in connection with our expansion-related activities will continue to be included. We believe that this provides a more conservative methodology to this non-GAAP financial measure. Had this methodology been used previously, it would not have affected distribution decisions or the outcome of the conversion of subordinated units to common units. Had this methodology been used for the year ended December 31, 2010, distributable cash flow would have been lower by approximately $2.5 million.

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    Consolidated Sales

        Our total sales for 2012 increased by $2.8 billion, or 19%, to $17.6 billion compared to $14.8 billion for 2011 due to an increase in volume sold. Our aggregate volume of product sold was 6.1 billion gallons for 2012 compared to 5.2 billion gallons for 2011, an increase of 0.9 billion gallons, or 17%. The increase in volume sold includes increases of approximately 511 million gallons in our gasoline distribution business, primarily due to our acquisition in March 2012 of Alliance, 357 million gallons in our wholesale business, primarily due to the expansion of crude oil and to an increase in gasoline, offset by a decrease in distillates due to warmer temperatures year over year, and 14 million gallons in our commercial business. The number of actual heating degree days decreased 7% to 4,754 for 2012 compared to 5,137 for 2011. Our gross profit for 2012 was $333.5 million, an increase of $123.9 million, or 59%, compared to $209.6 million for 2011, due primarily to the Alliance acquisition and to the expansion of crude oil. Notwithstanding the increase, our gross profit was negatively impacted by a challenging futures market, primarily backwardation in the gasoline futures market for most of 2012, and less favorable buying opportunities in wholesale gasoline and gasoline blendstocks and in distillates.

        Our total sales for 2011 increased by $7.0 billion, or 90%, to $14.8 billion compared to $7.8 billion for 2010. The increase was primarily due to higher refined petroleum product prices for 2011 compared to 2010 and to an increase in volume sold. Our aggregate volume of product sold was 5.2 billion gallons for 2011 compared to 3.7 billion for 2010, an increase of approximately 1.6 billion gallons, or 43%. The increase in volume sold primarily includes an increase of approximately 1.2 billion gallons in our wholesale business due to our June 2010 acquisition of three refined petroleum products terminals in Newburgh, New York and to increases in gasoline due to a strong demand for gasoline blendstocks, primarily ethanol, distillates due to an increase in non-weather related distillates and to slightly colder temperatures during 2011 compared to 2010 and, to a lesser extent, the addition of crude oil. We also had increases of 294 million gallons in our gasoline distribution business, primarily due to our September 2010 acquisition of retail gasoline stations and supply rights from ExxonMobil, and 88 million gallons in our commercial business. The number of actual heating degree days increased 2% to 5,137 for 2011 compared to 5,049 for 2010. Our gross profit for 2011 was $209.6 million, an increase of $42.9 million, or 26%, compared to $166.7 million for 2010, due primarily to our 2010 acquisitions.

    Wholesale Segment

        Gasoline and Gasoline Blendstocks.    Sales from wholesale gasoline and gasoline blendstocks were $8.8 billion for 2012 compared to $8.7 billion for 2011. The increase of $0.1 billion, or 2%, was due to an increase in volume sold attributable to an increase in demand for gasoline and gasoline blendstocks. Our net product margin from wholesale gasoline and gasoline blendstocks sales decreased by $1.6 million to $54.6 million for 2012 compared to $56.2 million for 2011, due primarily to a challenging futures market, mainly backwardation which increased hedging costs, less favorable buying opportunities, lower margins in gasoline blendstocks and increased competition.

        Sales from wholesale gasoline and gasoline blendstocks for 2011 were $8.7 billion compared to $4.3 billion for 2010. The increase of $4.4 billion, or 102%, was due primarily to higher gasoline prices and an increase in volume sold due to an increase in bulk supply and exchange activity and a strong demand for gasoline blendstocks, primarily ethanol. For these same reasons, our net product margin from wholesale gasoline and gasoline blendstocks sales increased by $2.1 million to $56.2 million for 2011 compared to $54.1 million for 2010. Despite the increase, our net product margin for gasoline and gasoline blendstocks was adversely impacted due to less favorable market conditions, primarily a backward forward product pricing curve.

        Other Oils and Related Products.    Sales from other oils and related products (primarily distillates, residual oil and crude oil) were $4.9 billion compared to $3.9 billion for 2011. The increase of $1.0 billion, or 25%, was primarily due to increases in volume sold, primarily crude oil, and in petroleum product prices. Our net product margin increased by $23.2 million to $90.8 million for 2012 compared to $67.6 million for 2011. These results include the addition of crude oil, which we began offering during the fourth quarter ended December 31, 2011 and, therefore, not offered during the first nine months of 2011 and, to a lesser extent, an improved distillate net product margin for 2012. Despite the increase in net product margin, our wholesale distillate business was negatively impacted due to less favorable buying opportunities and warmer weather in 2012 compared to 2011.

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        Sales from other oils and related products were $3.9 billion for 2011compared to $2.7 billion for 2010. The increase of $1.2 billion, or 45%, was primarily due to increases in refined petroleum product prices and in distillate volume sold due to an increase in non-weather related distillates and to slightly colder temperatures compared to 2010. The increase in sales also reflects the addition of crude oil, which we began offering during the fourth quarter ended December 31, 2011. The overall increase in sales was offset by a decrease in residual oil sales as a result of continued conservation, economic conditions and fuel switching related to lower prices for natural gas relative to residual oil prices. Despite the increase in sales, our net product margin decreased by $22.7 million, or 25%, to $67.6 million for 2011 compared to $90.3 million for 2010 primarily due to less favorable market conditions, a less favorable forward product pricing curve, and fewer advantageous purchasing opportunities in distillate, offset by our crude oil activity due to favorable market conditions and, to a lesser extent, the physical product margin.

    Gasoline Distribution and Station Operations Segment

        Gasoline Distribution.    Sales from gasoline distribution were $3.0 billion for 2012 compared to $1.4 billion for 2011. The increase of $1.6 billion, or 115%, was due primarily to an increase in volume sold as a result of our acquisition of Alliance and to a full year of sales of Mobil-branded fuel to Mobil Sub-jobbers pursuant to our brand fee agreement with ExxonMobil, which began in March 2011, as well as the Getty Realty agreements. For these same reasons, our net product margin from gasoline distribution increased by $83.0 million to $139.7 million for 2012 compared to $56.7 million for 2011.

        Sales from gasoline distribution were $1.4 billion for 2011 compared to $0.4 billion for 2010, an increase of $1.0 billion, or 297%. The increase was due primarily to higher gasoline prices and an increase in volume sold due to our September 2010 acquisition of retail gasoline stations and supply rights from ExxonMobil, as well as additional sales of Mobil-branded fuel to Mobil Sub-jobbers pursuant to our brand fee agreement. Primarily for these same reasons, our net product margin from gasoline distribution increased by $42.7 million to $56.7 million for 2011 compared to $14.0 million for 2010.

        Station Operations.    Our station operations, which consist primarily of convenience stores sales at our directly operated stores and gasoline station rental income, collectively generated revenues of approximately $124.1 million for 2012 compared to $58.8 million for 2011. Our net product margin from station operations was $66.4 million for 2012 compared to $31.5 million for 2011. The increases in revenues and net product margin for 2012 compared to 2011 are due primarily to the Alliance acquisition.

        Our station operations generated revenues of approximately $58.8 million and $16.1 million and net product margin of $31.5 million and $8.9 million for the years ended December 31, 2011 and 2010, respectively. The increases in revenues and net product margin year-over-year reflect a full year of operations of our 2010 acquisition of retail gasoline stations from ExxonMobil.

    Commercial Segment

        Our commercial sales were $0.7 billion, $0.8 billion and $0.4 billion for 2012, 2011 and 2010, respectively. Our commercial net product margins were $18.7 million, $22.0 million and $15.0 million for 2012, 2011 and 2010, respectively. In our Commercial segment, residual oil accounted for approximately 41%, 47% and 55% of our total commercial volume sold for 2012, 2011 and 2010, respectively. Distillates, gasoline and natural gas accounted for the remainder of the total commercial sales and volume sold.

    Selling, General and Administrative Expenses

        SG&A expenses increased by $22.9 million, or 29%, to $101.5 million for 2012 compared to $78.6 million for 2011, primarily due to the addition of Alliance. The increase includes increases of $12.7 million in overhead expenses, $4.0 million in one-time acquisition costs related to the acquisition of Alliance, $3.6 million in bank fees, $2.0 million in accrued incentive compensation and $5.3 million in various other SG&A expenses, offset by decreases of $2.2 million in management fees related to management agreements with Alliance which agreements terminated as a result of the Alliance acquisition, $1.1 million in bad debt expense and $1.4 million in professional fees.

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        SG&A expenses increased by $12.5 million, or 19%, to $78.6 million for 2011 compared to $66.1 million for 2010. The increase was primarily due to increases of $5.7 million in management costs and other expenses related to a full year of operations of the retail gasoline stations and supply rights acquired from ExxonMobil, $4.2 million in incentive compensation, $4.2 million in bank fees and amortization of deferred financing fees, $1.1 million in overhead (including information technology, natural gas personnel and project management), $1.1 million of one-time acquisition costs associated with the acquisition of Alliance and $0.8 million in bad debt expense. The overall increase was offset by decreases of approximately $3.2 million in professional and consulting fees and $1.4 million in various other SG&A expenses. The $4.2 million increase in bank fees and amortization of deferred financing fees was largely due to increased letter of credit fees related to the growth in our gasoline business and higher refined petroleum product prices, and to the expansion of our credit facilities.

    Operating Expenses

        Operating expenses increased by $66.9 million, or 91%, to $140.4 million for 2012 compared to $73.5 million for 2011. The increase was primarily due to $61.8 million in costs related to the operations of the gasoline stations acquired from Alliance and expenses associated with management of the Getty Realty locations and includes $21.5 million in overhead expenses, $15.3 million in credit card fees, $9.9 million in service station direct expenses, $6.7 million in various maintenance expenses, $5.1 million in rent expense and $3.3 million in property taxes. The increase in operating expenses also includes $2.3 million related to the Albany, New York terminal, $0.9 million related to the Newburgh, New York terminals, and $0.2 million in various other operating expenses. In addition, during the second quarter of 2011, we had a $1.7 million one-time reduction in our environmental reserve with respect to the Albany, New York terminal, which was recorded as a reduction to operating expenses.

        Operating expenses increased by $25.7 million, or 54%, to $73.5 million for 2011 compared to $47.8 million for 2010. The increase was primarily due to $25.1 million in increased costs related to a full year of operations of the retail gasoline stations acquired from ExxonMobil, $1.1 million in costs related to our Revere, Massachusetts terminal, $0.9 million in costs related to the Albany, New York terminal and $0.3 million in various other operating expenses. For 2011, the increase in operating expenses was partially offset by a decrease of approximately $1.7 million related to a change in estimate of our environmental reserve with respect to the Albany, New York terminal, which was recorded as a reduction to operating expenses. The $25.1 million in increased costs related to the retail gasoline stations primarily includes increases of $6.5 million in staff costs reimbursed to our management company, Alliance, $4.9 million in service station direct expenses, $4.3 million in credit card fees, $4.4 million in various maintenance expenses, $2.6 million in property taxes and $2.4 million in gasoline station rent expense.

    Amortization Expense

        Amortization expense related to our intangible assets was $7.0 million, $4.8 million and $3.5 million for 2012, 2011 and 2010, respectively. The increase of $2.2 million for 2012 compared to 2011 was due to $31.1 million of intangible assets acquired in the Alliance acquisition, and the increase of $1.3 million for 2011 compared to 2010 was primarily the result of a full year of amortization related to intangible assets recognized as part of our 2010 acquisitions.

    Restructuring Charges

        During the third quarter of 2011, we reduced our workforce by approximately 10% which resulted in restructuring charges of approximately $2.0 million for 2011. These restructuring charges consist principally of severance and outplacement costs for terminated employees. We paid a total of $1.6 million in restructuring charges through December 31, 2012. There were no similar reductions in workforce in 2012 or 2010. See Note 19 of Notes to Consolidated Financial Statements for additional information.

    Interest Expense

        Interest expense for 2012 increased by $5.1 million, or 16%, to $36.3 million compared to $31.2 million for 2011. The increase is primarily attributed to additional borrowings related to the acquisition of Alliance.

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        Interest expense for 2011 increased by $8.9 million, or 40%, to $31.2 million compared to $22.3 million for 2010. We attribute the increase primarily to additional borrowings as a result of our 2010 acquisitions and to higher average balances on our working capital revolving credit facility from carrying higher average dollar values of inventories and accounts receivable reflecting increased refined petroleum product prices. In addition, the costs of borrowings under the credit agreement were increased in connection with the May and August 2010 amendments to the credit agreement.

Liquidity and Capital Resources

    Liquidity

        Our primary liquidity needs are to fund our working capital requirements, capital expenditures and distributions and to service our indebtedness. Cash generated from operations and our working capital revolving credit facility provide our primary sources of liquidity. Working capital decreased by $180.1 million to $461.7 million at December 31, 2012 compared to $641.8 million at December 31, 2011.

        On February 14, 2012, we paid a cash distribution to our common unitholders and our general partner of approximately $11.0 million for the fourth quarter of 2011. On May 15, 2012, we paid a net cash distribution to our common unitholders and our general partner of approximately $12.1 million, which reflects an adjustment made in connection with the acquisition of Alliance on March 1, 2012 and the issuance to the seller of 5,850,000 common units. Specifically, the acquisition agreement provided that any declared distribution for the first quarter of 2012 reflect the seller's actual period of ownership during that quarter. The payment by the seller of $1.9 million reflects the timing of the transaction (March 1), seller's 31 days of actual unit ownership in the 91 days of the quarter and the net receipt by seller ($1.0 million) of a pro-rated portion of the quarterly cash distribution of $0.50 per unit paid on the newly issued 5,850,000 common units. On August 14, 2012, we paid a cash distribution to our common unitholders and our general partner of approximately $14.8 million for the second quarter of 2012. On November 14, 2012, we paid a cash distribution to our common unitholders and our general partner of approximately $15.0 million for the third quarter of 2012. On February 14, 2013, we paid a cash distribution to our common unitholders and our general partner of approximately $16.3 million for the fourth quarter of 2012.

    Contractual Obligations

        We have contractual obligations that are required to be settled in cash. The amounts of our contractual obligations at December 31, 2012 were as follows (in thousands):

 
  Payments due by period  
 
  Total   Less than
1 year
  1-3 years   4-5 years   More than
5 years
 

Revolver loan obligations (1)

  $ 892,130   $ 87,120   $ 805,010   $   $  

Operating lease obligations (2)

    319,450     57,089     82,024     67,268     113,069  

Capital lease obligations

    446     66     132     248      

Other long-term liabilities (3)

    243,286     36,431     67,468     65,372     74,015  
                       

Total

  $ 1,455,312   $ 180,706   $ 954,634   $ 132,888   $ 187,084  
                       

(1)
Includes principal and interest on our working capital revolving credit facility and our revolving credit facility at December 31, 2012 and assumes a ratable payment through the expiration date. The credit agreement has a contractual maturity of May 14, 2015 and no principal payments are required prior to that date. However, we repay amounts outstanding and reborrow funds based on our working capital requirements. Therefore, the current portion of the working capital revolving credit facility included in the accompanying balance sheets is the amount we expect to pay down during the course of the year, and the long-term portion of the working capital revolving credit facility is the amount we expect to be outstanding during the entire year.

(2)
Includes operating lease obligations related to leases for office space and computer equipment, land, terminals and throughputs, gasoline stations, railcars and a lease with a related party.

(3)
Includes amounts related to our 15-year brand fee agreement entered into in 2010 with ExxonMobil, minimum freight requirements on the transportation of ethanol to our Albany, New York terminal and pension and deferred compensation obligations.

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        In addition to the obligations described in the above table, we had minimum volume purchase requirements at December 31, 2012. Pricing is based on spot prices at the time of purchase. Please read Note 13 of Notes to Consolidated Financial Statements with respect to purchase commitments and sublease information related to certain lease agreements.

    Capital Expenditures

        Our operations require investments to expand, upgrade and enhance existing operations and to meet environmental and operations regulations. We categorize our capital requirements as either maintenance capital expenditures or expansion capital expenditures. Maintenance capital expenditures represent capital expenditures to repair or replace partially or fully depreciated assets to maintain the operating capacity of, or revenues generated by, existing assets and extend their useful lives. Maintenance capital expenditures include expenditures required to maintain equipment reliability, tankage and pipeline integrity and safety and to address certain environmental regulations. We anticipate that maintenance capital expenditures will be funded with cash generated by operations. We had approximately $13.1 million, $4.2 million and $4.1 million in maintenance capital expenditures for the years ended December 31, 2012, 2011 and 2010, respectively, which are included in capital expenditures in the accompanying consolidated statements of cash flows. The increase in maintenance capital expenditures in 2012 compared to 2011 and 2010 was primarily due to additional expenditures related to our gasoline stations. Repair and maintenance expenses associated with existing assets that are minor in nature and do not extend the useful life of existing assets are charged to operating expenses as incurred.

        Expansion capital expenditures include expenditures to acquire assets to grow our business or expand our existing facilities, such as projects that increase our operating capacity or revenues by increasing tankage, diversifying product availability at various terminals and adding terminals. We have the ability to fund our expansion capital expenditures through cash from operations or our credit agreement or by issuing debt securities or additional equity. We had approximately $332.5 million, $11.7 million and $258.9 million in expansion capital expenditures for the years ended December 31, 2012, 2011 and 2010, respectively.

        Specifically, for 2012, expansion capital expenditures included acquisitions of approximately $294.5 million associated with the purchase of Alliance, a portion of which was funded through equity and a portion was funded with cash, and $6.3 million associated with the acquisition of six gasoline stations from Mutual Oil Company. In addition we had $31.7 million in non-acquisition related expansion capital expenditures. The $31.7 million consists of $8.2 million in costs associated with a build-out project to increase the rail receipt and throughput storage capacities of ethanol and crude oil and converting certain storage tanks for the handling of crude oil at our Albany, New York terminal, $7.8 million in site expansion and improvements at certain retail gasoline stations, $6.7 million in costs associated with the building of a propane storage and distribution facility in Albany, New York, $5.3 million in costs related to tank construction at a transloading facility in North Dakota for the storage and handling of crude oil, $1.7 million in costs related to information technology, including increases in storage and computing capacity, $0.5 million in costs to acquire land for future development and $1.5 million in other expansion capital expenditures.

        In 2011, expansion capital expenditures included $2.7 million in costs related to our Albany, New York terminal including $1.8 million in costs associated with converting certain storage tanks for the handling of crude oil, $2.0 million in costs related to tank construction in North Dakota for the handling of crude oil, $1.8 million in costs related to propane tanks for future installation, $1.6 million in costs related to information technology, including increases in storage and computing capacity and hardware and software related to our branded gasoline business, $1.2 million in gasoline station equipment, $1.1 million in costs related to our three refined petroleum products terminals in Newburgh, New York, $0.6 million in bio-fuel conversion costs at our Providence, Rhode Island

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terminal, $0.6 million in costs at our Revere, Massachusetts terminal and $0.1 million in other expansion capital expenditures.

        In 2010, expansion capital expenditures included approximately $248.3 million in acquisition costs including $202.3 million for the purchase of retail gasoline stations and supply rights from ExxonMobil and $46.0 million in terminal acquisition costs related to the acquisition of three refined petroleum products terminals in Newburgh, New York. In addition, we had $10.6 million in expansion capital expenditures which consisted of $7.7 million in expenditures related to our Albany, New York terminal and ethanol expansion project, $1.8 million in terminal and computer equipment at our three refined petroleum products terminals in Newburgh, New York, $0.5 million in bio-fuel conversion costs at our Chelsea, Massachusetts terminal and $0.6 million in other expansion capital expenditures. The $7.7 million in expenditures related to our Albany terminal include costs related to our program to bring previously out-of-permit tanks back online, the installation of a marine vapor recovery system to allow for barge/vessel loading of gasoline and ethanol and the effort to convert two distillate storage tanks to gasoline.

        We believe that we will have sufficient cash flow from operations, borrowing capacity under our credit agreement and the ability to issue additional common units and/or debt securities to meet our financial commitments, debt service obligations, contingencies and anticipated capital expenditures. However, we are subject to business and operational risks that could adversely affect our cash flow. A material decrease in our cash flows would likely produce an adverse effect on our borrowing capacity as well as our ability to issue additional common units and/or debt securities.

    Cash Flow

 
  Year Ended December 31,  
 
  2012   2011   2010  
 
  (in thousands)
 

Net cash provided by (used in) operating activities

  $ 232,452   $ (17,357 ) $ (87,194 )

Net cash used in investing activities

  $ (226,488 ) $ (13,369 ) $ (262,997 )

Net cash (used in) provided by financing activities

  $ (4,315 ) $ 32,693   $ 351,890  

        Cash flow from operating activities generally reflects our net income, depreciation and amortization, balance sheet changes arising from inventory purchasing patterns, the timing of collections on our accounts receivable, the seasonality of part of our business, fluctuations in petroleum product prices, working capital requirements and general market conditions.

        Net cash provided by operating activities was $232.4 million for 2012 compared to net cash used in operating activities of $17.4 million for 2011, for a year-over-year increase in cash provided by operating activities of $249.8 million. Net cash provided by operating activities includes $46.7 million in net income for 2012.

        Exclusive of balances related to Alliance as of the acquisition date (see Note 3 of Notes to Consolidated Financial Statements), we had an increase in the carrying value of accounts payable of $183.9 million due to higher prices year over year and to the expansion of our crude oil activities. We also had an increase in the carrying value of accrued expenses and other current liabilities of $30.1 million offset by an increase in accounts receivable of $75.1 million due to increased prices year over year and to the growth in our gasoline distribution business. Inventories decreased by $29.5 million due to carrying lower levels of inventory.

        In addition, through the use of regulated exchanges or derivatives, we maintain a position that is substantially hedged with respect to our inventories. Specifically, due to market direction, the contracts supporting our forward fixed price hedge program required margin payments to the NYMEX of $9.8 million and $10.9 million for 2012 and 2011, respectively.

        Net cash used in operating activities was $17.4 million for 2011 compared to $87.2 million for 2010, for a year-over-year decrease in cash used in operating activities of $69.8 million.

        During 2011, we experienced increases in refined petroleum product and renewable fuel prices compared to 2010 and, as a result, we funded additional working capital requirements. Primarily due to the rise in prices, we had increases in the carrying values in inventories of $77.3 million, accounts receivable of $68.6 million and accounts payable of $132.3 million. Net cash used in operating activities was offset by $19.4 million in net income for 2011.

        In addition, through the use of regulated exchanges or derivatives, we seek to maintain a position that is substantially hedged with respect to our inventories. Specifically, for 2011, the contracts supporting our forward fixed price hedge program required margin payments of $10.9 million to the NYMEX due to market direction, compared to $10.8 million for 2010.

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        Net cash used in investing activities was $227.1 million for 2012 and included $181.9 million and $6.8 million in cash used to fund the acquisitions of Alliance and of six gasoline stations from Mutual Oil Company, respectively, $31.7 million in expansion capital expenditures and $13.1 million in maintenance capital expenditures, offset by $7.1 million in proceeds from the sale of property and equipment.

        Net cash used in investing activities was $13.4 million for 2011 and included $4.2 million in maintenance capital expenditures and $11.7 million in expansion capital expenditures, offset by approximately $2.5 million in proceeds from the sale of property and equipment.

        Net cash used in investing activities was $263.0 million for 2010 and included $4.1 million in maintenance capital expenditures and $258.9 million in expansion capital expenditures.

        See "—Capital Expenditures" for a discussion of our expansion capital expenditures for the years ended December 31, 2012, 2011 and 2010.

        Net cash used in financing activities was $4.3 million for 2012 and primarily included $164.4 million in payments on our working capital revolving credit facility, $54.7 million in cash distributions to our common unitholders and our general partner and $2.2 million in the repurchase of common units pursuant to our repurchase program for future satisfaction of our general partner's obligations, offset by $217.0 million in borrowings from our revolving credit facility.

        Net cash provided by financing activities was $32.7 million for 2011 and primarily included $102.2 million in borrowings from our working capital revolving credit facility and $69.6 million in net proceeds from our February 2011 public offering of common units, offset by $95.0 million in payments on our revolving credit facility, $42.8 million in cash distributions to our common and subordinated unitholders and our general partner, $0.7 million in repurchased units held for tax obligations related to units distributed under the LTIP, and $0.6 million in the repurchase of common units pursuant to our repurchase program for future satisfaction of our general partner's obligations. Our general partner's obligations include anticipated obligations to deliver common units under the LTIP and meeting the general partner's obligations under existing employment agreements and other employment related obligations of the general partner.

        Net cash provided by financing activities was $351.9 million for 2010 and included $228.8 million in borrowings from our revolving credit facility, $132.2 million on net proceeds from our public offerings of common units and $24.1 million in borrowings from our working capital revolving credit facility, offset by $31.9 million in cash distributions to our common and subordinated unitholders and our general partner, $0.9 million in the repurchases of common units pursuant to our repurchase program for future satisfaction of our general partner's obligations and $0.4 million in repurchased units held for tax obligations related to units distributed under the LTIP.

    Credit Agreement

        We entered into an amended and restated credit agreement dated May 14, 2010, as amended. Total commitments under our credit agreement are $1.5 billion. We repay amounts outstanding and reborrow funds based on our working capital requirements and, therefore, classify as a current liability the portion of the working capital revolving credit facility we expect to pay down during the course of the year. The long-term portion of the working capital revolving credit facility is the amount we expect to be outstanding during the entire year. The credit agreement will mature on May 14, 2015.

        As of December 31, 2012, there were two facilities under our credit agreement:

    a working capital revolving credit facility to be used for working capital purposes and letters of credit in the principal amount equal to the lesser of our borrowing base and $1.0 billion; and

    a $500.0 million revolving credit facility to be used for acquisitions and general corporate purposes.

        In addition, the credit agreement has an accordion feature whereby we may request on the same terms and conditions of our then existing credit agreement, provided no Event of Default (as defined in the credit agreement) then exists, an increase to the working capital revolving credit facility, the revolving credit facility or both by up to another $250.0 million, in the aggregate, for a total credit facility of up to $1.75 billion. Any such request for an increase by us must be in a minimum amount of $5.0 million. We cannot provide assurance, however, that our lending group will agree to fund any request by us for additional amounts in excess of the total available commitments of $1.5 billion.

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        In addition, the credit agreement includes a swing line pursuant to which Bank of America, N.A., as the swing line lender, may make swing line loans in an aggregate amount equal to the lesser of (a) $35.0 million and (b) the Aggregate WC Commitments (as defined in the credit agreement). Swing line loans will bear interest at the Base Rate (as defined in the credit agreement). The swing line is a sub-portion of the working capital revolving credit facility and is not an addition to the total available commitments of $1.5 billion.

        Availability under our working capital revolving credit facility is subject to a borrowing base which is redetermined from time to time and based on specific advance rates on eligible current assets. Under the credit agreement, our borrowings under the working capital revolving credit facility cannot exceed the then current borrowing base. Availability under our borrowing base may be affected by events beyond our control, such as changes in petroleum product prices, collection cycles, counterparty performance, advance rates and limits and general economic conditions. These and other events could require us to seek waivers or amendments of covenants or alternative sources of financing or to reduce expenditures. We can provide no assurance that such waivers, amendments or alternative financing could be obtained, or, if obtained, would be on terms acceptable to us.

        Commencing November 16, 2012, borrowings under the working capital revolving credit facility bear interest at (1) the Eurodollar rate plus 2.00% to 2.50%, (2) the cost of funds rate plus 2.00% to 2.50%, or (3) the base rate plus 1.00% to 1.50%, each depending on the Utilization Amount (as defined in the credit agreement). From 2010 through November 15, 2012, borrowings under the working capital revolving credit facility bore interest at (1) the Eurodollar rate plus 2.50% to 3.00%, (2) the cost of funds rate plus 2.50% to 3.00%, or (3) the base rate plus 1.50% to 2.00%, each depending on the pricing level provided in the credit agreement, which in turn depended upon the Utilization Amount (as defined in the credit agreement).

        Commencing November 16, 2012, borrowings under the revolving credit facility bear interest at (1) the Eurodollar rate plus 2.50% to 3.50%, (2) the cost of funds rate plus 2.50% to 3.50%, or (3) the base rate plus 1.50% to 2.50%, each depending on the Combined Total Leverage Ratio (as defined in the Credit Agreement). From 2010 through November 15, 2012, borrowings under the revolving credit facility bore interest at (1) the Eurodollar rate plus 3.00% to 3.875%, (2) the cost of funds rate plus 3.00% to 3.875%, or (3) the base rate plus 2.00% to 2.875%, each depending on the pricing level provided in the credit agreement, which in turn depended upon the Combined Total Leverage Ratio (as defined in the credit agreement).

        The average interest rates for the credit agreement were 4.0%, 4.1% and 3.7% for the years ended December 31, 2012, 2011 and 2010, respectively.

        We incur a letter of credit fee of 2.00% - 2.50% per annum for each letter of credit issued. In addition, we incur a commitment fee on the unused portion of each facility under the credit agreement, ranging from 0.375% to 0.50% per annum.

        As of December 31, 2012, we had total borrowings outstanding under the credit agreement of $846.5 million, including $422.0 million outstanding on our revolving credit facility. In addition, we had outstanding letters of credit of $434.6 million. Subject to borrowing base limitations, the total remaining availability for borrowings and letters of credit was $218.9 million and $215.9 million at December 31, 2012 and 2011, respectively.

        The credit agreement imposes financial covenants that require us to maintain certain minimum working capital amounts, capital expenditure limits, a minimum combined interest coverage ratio, a maximum senior secured leverage ratio and a maximum total leverage ratio. We were in compliance with the foregoing covenants at December 31, 2012. The credit agreement also contains a representation whereby there can be no event or circumstance, either individually or in the aggregate, that has had or could reasonably be expected to have a Material Adverse Effect (as defined in the credit agreement). In addition, the credit agreement limits distributions by us to our unitholders to the amount of our Available Cash (as defined in the partnership agreement).

        Our obligations under the credit agreement are secured by substantially all of our assets and the assets of our operating company and operating subsidiaries.

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        On January 25, 2013, we entered into a Ninth Amendment (the "Ninth Amendment") to our credit agreement. The Ninth Amendment provides for a term loan in the amount of up to $115.0 million (the "Term Loan") in connection with, and provides for certain other modifications relating to, (i) our acquisition of a 60% membership interest in Basin Transload, and/or (ii) our acquisition of 100% of the membership interests in Cascade Kelly (see "Items 1. and 2. Business and Properties—Recent Developments" and Note 1 of Notes to Consolidated Financial Statements). We utilized the full amount available under the Term Loan.

        Pursuant to the Ninth Amendment, the interest rate on amounts outstanding under the Term Loan will be either the Eurodollar rate or the cost of funds rate, in each case plus 3.50%, or the base rate plus 2.50%. Any proceeds from the issuance of equity or debt by us will be used to repay amounts outstanding under the Term Loan. The Term Loan will mature on January 31, 2014.

        The Ninth Amendment also amends certain terms, provisions and covenants to take into account the acquisitions of our interests in Basin Transload and Cascade Kelly. The Ninth Amendment (1) increases the permitted Combined Senior Secured Leverage Ratio (as defined in the credit agreement) for each quarter in the year ending December 31, 2013 and (2) increases the permitted Combined Total Leverage Ratio (as defined in the Credit Agreement) for the quarters ending March 31, 2013 and June 30, 2013.

Senior Notes

        On February 14, 2013, we entered into a Note Purchase Agreement (the "Purchase Agreement") with FS Energy and Power Fund ("FS Energy"), with respect to the issue and sale by us to FS Energy of an aggregate principal amount of $70.0 million of unsecured 8.00% Senior Notes due 2018 (the "Notes"). The Notes were issued in a private placement exempt from registration under the Securities Act of 1933, as amended (the "Securities Act") and have not been registered under the Securities Act or any state securities laws, and may not be offered or sold except pursuant to an exemption from the registration requirements of the Securities Act and applicable state laws.

        Closing of the offering occurred on February 14, 2013. The Notes were sold to FS Energy at 97% of their face amount, resulting in net proceeds to us of approximately $67.9 million. Additionally, we separately paid fees and offering expenses. On February 15, 2013, we used the net proceeds from the offering, after paying fees and offering expenses, together with a portion of the $115.0 million Term Loan to finance our acquisition of all of the outstanding membership interests in Cascade Kelly and to pay related transaction costs.

        The Notes were issued pursuant to an indenture dated as of February 14, 2013 (the "Indenture") among us, our subsidiary guarantors and FS Energy. The Notes will mature on February 14, 2018. Interest on the Notes will accrue from February 14, 2013 and be paid semi-annually on February 14 and August 14 of each year, beginning on August 14, 2013. We may redeem all or some of the Notes at any time or from time to time pursuant to the terms of the Indenture. The Notes are also subject to optional or mandatory exchange for HY Bonds (as such term is defined in the Indenture) at the time and on the terms specified in the Indenture. The holders of the Notes may require us to repurchase the Notes following certain asset sales or a Change of Control (as defined in the Indenture) at the prices and on the terms specified in the Indenture.

        The Notes are guaranteed on a senior, unsecured basis by certain of our wholly owned subsidiaries. The Indenture contains covenants that are no more restrictive to us in the aggregate than the terms, conditions, covenants and defaults contained in our credit agreement and will limit our ability to, among other things, incur additional indebtedness, make distributions to equity owners, make certain investments, restrict distributions by our subsidiaries, create liens, enter into sale-leaseback transactions, sell assets or merge with other entities. Events of default under the Indenture include (i) a default in payment of principal of, or interest or premium, if any, on, the Notes, (ii) breach of our covenants under the Indenture, (iii) certain events of bankruptcy and insolvency, (iv) any payment default or acceleration of indebtedness of ours or certain subsidiaries if the total amount of such indebtedness unpaid or accelerated exceeds $15.0 million and (v) failure to pay within 60 days uninsured final judgments exceeding $15.0 million.

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Deferred Financing Fees

        We incur bank fees related to our credit agreement. These deferred financing fees are amortized over the life of the credit agreement. Amortization expense of approximately $5.8 million, $4.7 million and $3.0 million for the years ended December 31, 2012, 2011 and 2010, respectively, are included in selling, general and administrative expenses in the accompanying consolidated statements of income.

    Off-Balance Sheet Arrangements

        We have no off-balance sheet arrangements.

Impact of Inflation

        Inflation in the United States has been relatively low in recent years and did not have a material impact on our results of operations for the years ended December 31, 2012, 2011 and 2010.

Environmental Matters

        Our business of supplying refined petroleum products, renewable fuels and crude oil involves a number of activities that are subject to extensive and stringent environmental laws. For a complete discussion of the environmental laws and regulations affecting our business, please read Items 1 and 2, "Business and Properties—Environmental." For additional information regarding our environmental liabilities, see Note 9 of Notes to Consolidated Financial Statements included elsewhere in this report.

Critical Accounting Policies and Estimates

        A summary of the significant accounting policies that we have adopted and followed in the preparation of our consolidated financial statements is detailed in Note 2 of Notes to Consolidated Financial Statements. Certain of these accounting policies require the use of estimates. These estimates are based on our knowledge and understanding of current conditions and actions that we may take in the future. Changes in these estimates will occur as a result of the passage of time and the occurrence of future events. Subsequent changes in these estimates may have a significant impact on our financial condition and results of operations and are recorded in the period in which they become known. We have identified the following estimates that, in our opinion, are subjective in nature, require the exercise of judgment and involve complex analysis:

    Inventory

        Except for our convenience store inventory, we hedge substantially all of our inventory, primarily through futures contracts. These futures contracts are entered into when inventory is purchased and are designated as fair value hedges against the inventory on a specific barrel basis. Changes in the fair value of these contracts, as well as the offsetting gain or loss on the hedged inventory item, are recognized in earnings as an increase or decrease in cost of sales. All hedged inventory is valued using the lower of cost, as determined by specific identification, or market. Prior to sale, hedges are removed from specific barrels of inventory, and the then unhedged inventory is sold and accounted for on a first-in, first-out basis. In addition to our own inventory, we have exchange agreements with unrelated third party suppliers, whereby we may draw inventory from these other suppliers and suppliers may draw inventory from us. Positive exchange balances are accounted for as accounts receivable. Negative exchange balances are accounted for as accounts payable. Exchange transactions are valued using current inventory levels. In addition, we have convenience store inventory which is carried at the lower of historical cost or market.

    Leases

        We have a throughput agreement with Global Petroleum Corp., one of our affiliates, with respect to its terminal in Revere, Massachusetts. This agreement is accounted for as an operating lease. Please read Item 13, "Certain Relationships and Related Transactions, and Director Independence—Throughput Agreement with Global Petroleum Corp." We also have entered into terminal and throughput lease arrangements with various unrelated oil terminals and third parties, certain of which arrangements have minimum usage requirements. Please read Items 1 and 2, "Business and Properties—Storage." In addition, we lease certain gasoline stations from third parties under long-term arrangements with various expiration dates. We have a long-term lease agreement with Getty Realty which enables us to supply and operate certain Getty Realty gasoline station sites. The initial lease term for the locations is 15 years and includes multiple five-year renewal options. In addition, we lease railcars pursuant to various lease arrangements with various expiration dates.

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        We have future commitments, principally for office space and computer equipment, under the terms of operating lease arrangements. We have rental income from gasoline stations and lease income from space leased to several unrelated third parties at several of our terminals. Additionally, we have capital leases for other computer equipment and leasehold improvements. Accounting and reporting guidance for leases requires that leases be evaluated and classified as operating or capital leases for financial reporting purposes. The lease term used for lease evaluation includes option periods only in instances in which the exercise of the option period can be reasonably assured and failure to exercise such options would result in an economic penalty.

    Revenue Recognition

        Sales relate primarily to the sale of refined petroleum products, renewable fuels, crude oil and natural gas and are recognized along with the related receivable upon delivery, net of applicable provisions for discounts and allowances. We may also provide for shipping costs at the time of sale, which are included in cost of sales. The amounts recorded for bad debts are generally based upon a specific analysis of aged accounts while also factoring in any new business conditions that might impact the historical analysis, such as market conditions and bankruptcies of particular customers. Bad debt provisions are included in selling, general and administrative expenses. We also recognize convenience store sales of gasoline, grocery and other merchandise and commissions on lottery at the time of the sale to the customer. Gasoline station rental income is recognized on a straight-line basis over the term of the lease.

        Revenue is not recognized on exchange agreements, which are entered into primarily to acquire various refined petroleum products, renewable fuels and crude oil of a desired quality or to reduce transportation costs by taking delivery of products closer to our end markets. Any net differential for exchange agreements is recorded as a nonmonetary adjustment of inventory costs.

        We collect trustee taxes, which consist of various pass through taxes collected from customers on behalf of taxing authorities, and remits such taxes directly to those taxing authorities. As such, it is our policy to exclude trustee taxes from revenues and cost of sales and account for them as current liabilities.

    Derivative Financial Instruments

        Accounting and reporting guidance for derivative instruments and hedging activities requires that an entity recognize derivatives as either assets or liabilities on the balance sheet and measure the instruments at fair value. Changes in the fair value of the derivative are to be recognized currently in earnings, unless specific hedge accounting criteria are met. We principally uses derivative instruments to hedge the commodity risk associated with our inventory and product purchases and sales and to hedge variable interest rates associated with our credit facilities.

        Fair Value Hedges—We enter into futures contracts in the normal course of business to the reduce risk of loss of inventory value, which could result from fluctuations in market prices. These futures contracts are designated as fair value hedges against the inventory with specific futures contracts matched to specific barrels of inventory. As a result of our hedge designation on these transactions, the futures contracts are recorded on our consolidated balance sheet and marked to market through the use of independent markets based on the prevailing market prices of such instruments at the date of valuation. Likewise, the underlying inventory being hedged is also marked to market. Changes in the fair value of the futures contracts, as well as the change in the fair value of the hedged inventory, are recognized in the consolidated statement of income through cost of sales. These futures contracts are settled on a daily basis by us through brokerage margin accounts.

        Cash Flow Hedges—We utilize various interest rate derivative instruments to hedge variable interest rate on our debt. These derivative instruments are designated as cash flow hedges of the underlying debt. To the extent such hedges are effective, the changes in the fair value of the derivative instrument are reported as a component of other comprehensive income (loss) and reclassified into interest expense or interest income in the same period during which the hedged transaction affects earnings.

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        In September 2008, we executed a zero premium interest rate collar with a major financial institution. The collar, which became effective on October 2, 2008 and expires on October 2, 2013, is used to hedge the variability in cash flows in monthly interest payments made on $100.0 million of one-month LIBOR-based borrowings on the working capital revolving credit facility (and subsequent refinancings thereof) due to changes in the one-month LIBOR rate.

        In October 2009, we executed an interest rate swap with a major financial institution. The swap, which became effective on May 16, 2011 and expires on May 16, 2016, is used to hedge the variability in interest payments due to changes in the one-month LIBOR swap curve with respect to $100.0 million of one-month LIBOR-based borrowings on the revolving credit facility at a fixed rate of 3.93%.

        In April 2011, we executed an interest rate cap with a major financial institution. The rate cap, which became effective on April 13, 2011 and expires on April 13, 2016, is used to hedge the variability in interest payments due to changes in the one-month LIBOR rate above 5.5% with respect to $100.0 million of one-month LIBOR-based borrowings on the working capital revolving credit facility.

    Other Derivative Activity

        We use futures contracts, and occasionally swap agreements, to hedge our commodity exposure under forward fixed price purchase and sale commitments on our products. These derivatives are not designated by us as either fair value hedges or cash flow hedges. Rather, the forward fixed price purchase and sales commitments, which meet the definition of a derivative, are reflected in our consolidated balance sheet. The related futures contracts (and swaps, if applicable) are also reflected in our consolidated balance sheet, thereby creating an economic hedge. Changes in the fair value of the futures contracts (and swaps, if applicable), as well as offsetting gains or losses due to the change in the fair value of forward fixed price purchase and sale commitments, are recognized in the consolidated statement of income through cost of sales. These futures contracts are settled on a daily basis by us through brokerage margin accounts.

        While we seek to maintain a position that is substantially balanced within our product purchase activities, we may experience net unbalanced positions for short periods of time as a result of variances in daily sales and transportation and delivery schedules as well as other logistical issues inherent in the business, such as weather conditions. In connection with managing these positions, maintaining a constant presence in the marketplace, and managing the futures market outlook for future anticipated inventories, which are necessary for our business, we engage in a controlled trading program for up to an aggregate of 250,000 barrels of products at any one point in time. Any derivatives not involved in a direct hedging activity are marked to market and recognized in the consolidated statement of income through cost of sales.

        We also market and sell natural gas by entering into forward purchase commitments for natural gas when we enter into arrangements for the forward sale commitment of product for physical delivery to third-party users. We reflect the fair value of forward fixed purchase and sales commitments in our consolidated balance sheet. Changes in the fair value of the forward fixed price purchase and sale commitments are recognized in the consolidated statement of income through cost of sales.

        During the year ended December 31, 2012, we entered into forward currency contracts to hedge certain foreign denominated (Canadian) product purchases. These forward contracts are not designated and are reflected in the consolidated balance sheet. Changes in the fair values of these forward currency contracts are reflected in cost of sales.

    Valuation of Intangibles and Other Long-Lived Assets

        Our long-lived assets include property and equipment and intangible assets. We assess the carrying value of our long-lived assets, including intangible assets, whenever events or changes in circumstances indicate that the carrying value may not be recoverable. Accordingly, we evaluate for impairment whenever indicators of impairment are identified. Factors we consider important include, but are not limited to, significant underperformance relative to historical or projected future results, significant negative industry factors and significant changes in strategy or operations that negatively affect the utilization of our long-lived assets. If indicators of impairment are present, we assess impairment by comparing the undiscounted projected future cash flows from the long-lived assets to their carrying value. If the undiscounted cash flows are less than the carrying value, the long-lived assets will be reduced to their fair value. The cash flows that are used contain our best estimates, using appropriate and customary assumptions and projections at the time. If the cash flow estimates or the significant operating assumptions upon which they are based change in the future, we may be required to record additional impairment charges.

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    Goodwill

        Goodwill represents the future economic benefits arising from assets acquired in a business combination that are not individually identified and separately recognized. All of our goodwill is allocated to the Gasoline Distribution and Station Operations reporting unit. Goodwill is tested for impairment annually as of October 1 or when events or changes in circumstances indicate that the carrying amount of goodwill may not be recoverable. The impairment test first includes a qualitative assessment in order to conclude if it is more likely than not that the reporting unit's fair value exceeds its carrying value. If necessary, we would then complete a two-step quantitative assessment.

        Factors included in the quantitative assessment include both macro-economic conditions and industry specific conditions. For the quantitative assessment, the reporting unit's fair value is estimated using a weighted average of discounted cash flow approach and market comparables approach. In the quantitative assessment, we compare the fair value of the reporting unit to its carrying value. If the fair value of the reporting unit exceeds the carrying value, goodwill is not impaired and no further testing is required. If the carrying value exceeds the fair value, then the second step must be performed to determine the implied fair value of the reporting unit. If the carrying value exceeds the implied fair value then we would record an impairment loss equal to the difference.

    Environmental and Other Liabilities

        We record accrued liabilities for all direct costs associated with the estimated resolution of contingencies at the earliest date at which it is deemed probable that a liability has been incurred and the amount of such liability can be reasonably estimated. Costs accrued are estimated based upon an analysis of potential results, assuming a combination of litigation and settlement strategies and outcomes.

        Estimated losses from environmental remediation obligations generally are recognized no later than completion of the remedial feasibility study. Loss accruals are adjusted as further information becomes available or circumstances change. Costs of future expenditures for environmental remediation obligations are not discounted to their present value. Recoveries of environmental remediation costs from other parties are recognized as assets when their receipt is deemed probable.

        We are subject to other contingencies, including legal proceedings and claims arising out of our businesses that cover a wide range of matters, including, among others, environmental matters and contract and employment claims. Environmental and other legal proceedings may also include matters with respect to businesses we previously owned. Further, due to the lack of adequate information and the potential impact of present regulations and any future regulations, there are certain circumstances in which no range of potential exposure may be reasonably estimated. Please read Item 3, "Legal Proceedings."

    Related Party Transactions

        A discussion of related party transactions is included in Note 16 of Notes to Consolidated Financial Statements included elsewhere in this report.

Recent Accounting Pronouncements

        A description and related impact expected from the adoption of certain new accounting pronouncements is provided in Note 2 of Notes to Consolidated Financial Statements included elsewhere in this report.

Item 7A.    Quantitative and Qualitative Disclosures about Market Risk.

        Market risk is the risk of loss arising from adverse changes in market rates and prices. The principal market risks to which we are exposed are interest rate risk and commodity risk. We utilize an interest rate collar, an interest rate swap and an interest rate cap to manage exposure to interest rate risk and various derivative instruments to manage exposure to commodity risk.

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    Interest Rate Risk

        We utilize variable rate debt and are exposed to market risk due to the floating interest rates on our credit agreement. Therefore, from time to time, we utilize interest rate collars, swaps and caps to hedge interest obligations on specific and anticipated debt issuances.

        On November 16, 2012, we entered into an Eighth Amendment to our credit agreement. Total commitments under the credit agreement are $1.5 billion. Please read Item 7, "Management's Discussion and Analysis—Liquidity and Capital Resources——Credit Agreement" for information on interest rates related to our borrowings.

        As of December 31, 2012, we had total borrowings outstanding under the credit agreement of $846.5 million. The impact of a 1% increase in the interest rate on this amount of debt would have resulted in an increase in interest expense, and a corresponding decrease in our results of operations, of approximately $8.5 million annually, assuming, however, that our indebtedness remained constant throughout the year.

        In September 2008, we executed a zero premium interest rate collar with a major financial institution. The collar, which became effective on October 2, 2008 and expires on October 2, 2013, is used to hedge the variability in cash flows in monthly interest payments made on $100.0 million of one-month LIBOR-based borrowings on the working capital revolving credit facility (and subsequent refinancings thereof) due to changes in the one-month LIBOR rate.

        In October 2009, we executed an interest rate swap with a major financial institution. The swap, which became effective on May 16, 2011 and expires on May 16, 2016, is used to hedge the variability in interest payments due to changes in the one-month LIBOR swap curve with respect to $100.0 million of one-month LIBOR-based borrowings on the revolving credit facility at a fixed rate of 3.93%.

        In April 2011, we executed an interest rate cap with a major financial institution. The rate cap, which became effective on April 13, 2011 and expires on April 13, 2016, is used to hedge the variability in interest payments due to changes in the one-month LIBOR rate above 5.5% with respect to $100.0 million of one-month LIBOR-based borrowings on the working capital revolving credit facility.

        See Notes 2 and 4 of Notes to Consolidated Financial Statements for additional information on our derivative instruments.

    Commodity Risk

        We hedge our exposure to price fluctuations with respect to refined petroleum products, renewable fuels, crude oil and gasoline blendstocks in storage and expected purchases and sales of these commodities. The derivative instruments utilized consist primarily of futures contracts traded on the NYMEX, CME and ICE and over-the-counter transactions, including swap agreements entered into with established financial institutions and other credit-approved energy companies. Our policy is generally to purchase only products for which we have a market and to structure our sales contracts so that price fluctuations do not materially affect our profit. While our policies are designed to minimize market risk, as well as inherent basis risk, exposure to fluctuations in market conditions remains. Except for the controlled trading program discussed below, we do not acquire and hold futures contracts or other derivative products for the purpose of speculating on price changes that might expose us to indeterminable losses.

        While we seek to maintain a position that is substantially balanced within our product purchase activities, we may experience net unbalanced positions for short periods of time as a result of variances in daily sales and transportation and delivery schedules as well as other logistical issues inherent in the business, such as weather conditions. In connection with managing these positions, maintaining a constant presence in the marketplace and managing the futures market outlook for future anticipated inventories, which are necessary for our business, we engage in a controlled trading program for up to an aggregate of 250,000 barrels of products at any one point in time. Any derivatives not involved in a direct hedging activity are marked to market and recognized in the consolidated statement of income through cost of sales. In addition, because a portion of our crude oil business is conducted in Canadian dollars, we may use foreign currency derivatives to minimize the risks of unfavorable exchange rates. These instruments include foreign currency exchange contracts and forwards. In conjunction with entering into the commodity derivative, we may enter into a foreign currency derivative to hedge the resulting foreign currency risk. These foreign currency derivatives are generally short-term in nature and not designated for hedge accounting.

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        We utilize futures contracts and other derivative instruments to minimize or hedge the impact of commodity price changes on our inventories and forward fixed price commitments. Any hedge ineffectiveness is reflected in our results of operations. We utilize regulated exchanges, including the NYMEX, CME and ICE, which are regulated exchanges for the commodities that each trades, thereby reducing potential delivery and supply risks. Generally, our practice is to close all exchange positions rather than to make or receive physical deliveries. With respect to other energy products such as ethanol, which may not have a correlated exchange contract, we enter into derivative agreements with counterparties that we believe have a strong credit profile, in order to hedge market fluctuations and/or lock-in margins relative to our commitments.

        At December 31, 2012, the fair value of all of our commodity risk derivative instruments and the change in fair value that would be expected from a 10% price increase or decrease are shown in the table below (in thousands):

 
   
  Gain (Loss)  
 
  Fair Value at
December 31,
2012
  Effect of 10%
Price Increase
  Effect of 10%
Price Decrease
 

Futures contracts

  $ 9,273   $ (51,604 ) $ 51,604  

Swaps, options and other, net

    125     (2,792 )   2,132  
               

  $ 9,398   $ (54,396 ) $ 53,736  
               

        The fair values of the futures contracts are based on quoted market prices obtained from the NYMEX and the CME. The fair value of the swaps and option contracts are estimated based on quoted prices from various sources such as independent reporting services, industry publications and brokers. These quotes are compared to the contract price of the swap, which approximates the gain or loss that would have been realized if the contracts had been closed out at December 31, 2012. For positions where independent quotations are not available, an estimate is provided, or the prevailing market price at which the positions could be liquidated is used. All hedge positions offset physical exposures to the physical market; none of these offsetting physical exposures are included in the above table. Price-risk sensitivities were calculated by assuming an across-the-board 10% increase or decrease in price regardless of term or historical relationships between the contractual price of the instruments and the underlying commodity price. In the event of an actual 10% change in prompt month prices, the fair value of our derivative portfolio would typically change less than that shown in the table due to lower volatility in out-month prices. We have a daily margin requirement to maintain a cash deposit with our brokers based on the prior day's market results on open futures contracts. The balance of this deposit will fluctuate based on our open market positions and the commodity exchange's requirements. The brokerage margin balance was $54.7 million at December 31, 2012.

        We are exposed to credit loss in the event of nonperformance by counterparties of futures contracts, forward contracts and swap agreements. We anticipate some nonperformance by some of these counterparties which, in the aggregate, we do not believe at this time will have a material adverse effect on our financial condition, results of operations or cash available for distribution to our unitholders. Futures contracts, the primary derivative instrument utilized, are traded on regulated exchanges, greatly reducing potential credit risks. Exposure on swap and certain option agreements is limited to the amount of the recorded fair value as of the balance sheet dates. We utilize primarily two clearing brokers, both major financial institutions, for all NYMEX derivative transactions and the right of offset exists. Accordingly, the fair value of all derivative instruments is displayed on a net basis.

Item 8.    Financial Statements and Supplementary Data.

        The information required here is included in the report as set forth in the "Index to Financial Statements" on page F-1.

Item 9.    Changes in and Disagreements With Accountants on Accounting and Financial Disclosure.

        None.

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Item 9A.    Controls and Procedures.

    Disclosure Controls and Procedures

        We maintain disclosure controls and procedures that are designed to ensure that the information required to be disclosed by us in the reports we file or submit under the Securities Exchange Act of 1934 (the "Exchange Act") is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms and that information is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure. Under the supervision and with the participation of our principal executive officer and principal financial officer, management evaluated the effectiveness of our disclosure controls and procedures (as defined in Rules 13a-15(e) or 15d-15(e) of the Exchange Act). Based on that evaluation, our principal executive officer and principal financial officer concluded that our disclosure controls and procedures were effective as of December 31, 2012.

    Internal Control Over Financial Reporting

    Management's Annual Report

        We are responsible for establishing and maintaining adequate internal control over financial reporting (as defined in Rules 13a-15(f) or 15d-15(f) of the Exchange Act). Internal control over financial reporting is the process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with GAAP. There are inherent limitations in the effectiveness of internal control over financial reporting, including the possibility that misstatements may not be prevented or detected. Accordingly, even effective internal controls over financial reporting can provide only reasonable assurance with respect to financial statement preparation.

        Under the supervision and with the participation of our principal executive officer and principal financial officer, management conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on that evaluation, management believes that our internal control over financial reporting was effective as of December 31, 2012.

        Ernst & Young LLP, our independent registered public accounting firm, has issued an attestation report on management's assessment of the effectiveness of our internal control over financial reporting, as stated in their report which is included herein.

    Changes in Internal Control

        There has not been any change in our internal control over financial reporting that occurred during the quarter ended December 31, 2012 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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Report of Independent Registered Public Accounting Firm

The Board of Directors of Global GP LLC
and Unitholders of Global Partners LP

        We have audited Global Partners LP's internal control over financial reporting as of December 31, 2012, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (the COSO criteria). Global Partners LP's management is responsible for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting included in the accompanying Management's Annual Report. Our responsibility is to express an opinion on the partnership's internal control over financial reporting based on our audit.

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

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

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

        In our opinion, Global Partners LP maintained, in all material respects, effective internal control over financial reporting as of December 31, 2012, based on the COSO criteria.

        We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheets of Global Partners LP, as of December 31, 2012 and 2011, and the related consolidated statements of income and comprehensive income, partners' equity and cash flows for each of the three years in the period ended December 31, 2012, and our report dated March 15, 2013 expressed an unqualified opinion thereon.

                        /s/ ERNST & YOUNG LLP  

Boston, Massachusetts
March 15, 2013

Item 9B.    Other Information.

        None.

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PART III

Item 10.    Directors, Executive Officers and Corporate Governance.

        Global GP LLC, our general partner, manages our operations and activities on our behalf. Our general partner is not elected by our unitholders and is not subject to re-election in the future. Affiliates of the Slifka family own 100% of the ownership interests in our general partner. Our general partner is controlled by Alfred A. Slifka and Richard Slifka directly and through their beneficial ownership of entities that own ownership interests in our general partner. Eric Slifka beneficially owns an interest in our general partner. Unitholders are not entitled to elect the directors of our general partner or directly or indirectly participate in our management or operation. Our general partner is liable, as general partner, for all of our debts (to the extent not paid from our assets), except for indebtedness or other obligations that are made specifically nonrecourse to it. Whenever possible, our general partner intends to incur indebtedness or other obligations that are nonrecourse.

        Three members of the board of directors of our general partner serve on a conflicts committee to review specific matters that the board believes may involve conflicts of interest. The conflicts committee determines if the resolution of the conflict of interest is fair and reasonable to us. Members of the conflicts committee may not be officers or employees of our general partner or directors, officers or employees of its affiliates and must meet the independence and experience standards established by the New York Stock Exchange ("NYSE") and the Securities Exchange Act of 1934. Any matters approved by the conflicts committee will be conclusively deemed to be fair and reasonable to us, approved by all of our partners and not a breach by our general partner of any duties it may owe us or our unitholders. In addition, we have a separately-designated standing audit committee established in accordance with the Securities Exchange Act of 1934 and a compensation committee. The three independent members of the board of directors of our general partner, Messrs. McKown, McCool and Watchmaker, serve as the sole members of the conflicts, audit and compensation committees.

        Even though most companies listed on the NYSE are required to have a majority of independent directors serving on the board of directors of the listed company and establish and maintain an audit committee, a compensation committee and a nominating/corporate governance committee, each consisting solely of independent directors, the NYSE does not require a listed limited partnership like us to have a majority of independent directors on the board of directors of our general partner or establish a compensation committee or a nominating/corporate governance committee.

        No member of the audit committee is an officer or employee of our general partner or director, officer or employee of any affiliate of our general partner. Furthermore, each member of the audit committee is independent as defined in the listing standards of the NYSE. The board of directors of our general partner has determined that a member of the audit committee, namely Kenneth Watchmaker, is an "audit committee financial expert" as defined by the SEC.

        Among other things, the audit committee is responsible for reviewing our external financial reporting, including reports filed with the SEC, engaging and reviewing our independent auditors and reviewing procedures for internal auditing and the adequacy of our internal accounting controls.

        We are managed and operated by the directors and executive officers of our general partner. Our operating personnel are employees of our general partner or certain of our operating subsidiaries.

        All of our executive officers devote substantially all of their time to managing our business and affairs, but from time to time perform services for certain of our affiliates. Please read Item 13, "Certain Relationships and Related Transactions, and Director Independence—Relationship of Management with Global Petroleum Corp., AE Holdings Corp. and Alliance Energy LLC." Our non-management directors devote as much time as is necessary to prepare for and attend board of directors and committee meetings.

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        Set forth below are the names, ages (as of March 12, 2013) and titles of persons currently serving as directors and executive officers of our general partner.

Name
  Age   Position with Global GP LLC

Alfred A. Slifka

    80   Chairman

Richard Slifka

    72   Vice Chairman

Eric Slifka

    47   President, Chief Executive Officer and Director

Andrew Slifka

    44   Executive Vice President and Director

Thomas J. Hollister

    58   Chief Operating Officer, Chief Financial Officer and Director

Edward J. Faneuil

    60   Executive Vice President, General Counsel and Secretary

Charles A. Rudinsky

    65   Executive Vice President and Chief Accounting Officer

David K. McKown

    75   Director

Robert J. McCool

    74   Director

Kenneth I. Watchmaker

    70   Director

        Alfred A. Slifka was elected Chairman of the Board of our general partner in March 2005. He had been employed with Global Companies LLC or its predecessors for over fifty years. Mr. Slifka served as Chairman of the board of directors of Global Companies LLC since its formation in December 1998. Currently Mr. Slifka is a shareholder and serves as Chairman of the board of directors of AE Holdings Corp., a privately held affiliated company. Mr. Slifka also is a shareholder, a director and the President of Global Petroleum Corp., a privately held affiliated company that owns, operates and leases to us our petroleum products storage terminal located in Revere, Massachusetts. Mr. Slifka currently serves on the boards of the New England Fuel Institute, Morse Life, Hebrew Senior Life, and Children's Hospital. He is a past member of the boards of directors of numerous other civic and charitable organizations. Mr. Slifka's extensive knowledge of the oil industry in general and of our history, customers and suppliers make him uniquely qualified to serve as our Chairman of the Board.

        Richard Slifka was elected Vice Chairman of the Board of our general partner in March 2005. He had been employed with Global Companies LLC or its predecessors since 1963. Mr. Slifka served as Treasurer and a director of Global Companies LLC since its formation in December 1998. Currently Mr. Slifka is a shareholder and serves as Vice Chairman of the board of directors of AE Holdings Corp., a privately held affiliated company. Mr. Slifka also is a shareholder, a director and the Treasurer of Global Petroleum Corp., a privately held affiliated company that owns, operates and leases to us our petroleum products storage terminal located in Revere, Massachusetts. Mr. Slifka currently serves on the boards of directors of New England Fuel Institute and Independent Fuel Terminal Operators Association. He also currently serves on the board of directors of St. Francis House and the board of trustees of Boston Medical Center. He has been a director of the National Multiple Sclerosis Society since 1988. Mr. Slifka's extensive knowledge of the oil industry in general and of our history, customers and suppliers make him uniquely qualified to serve as our Vice Chairman of the Board. Alfred A. Slifka and Richard Slifka are brothers.

        Eric Slifka was elected President, Chief Executive Officer and a director of our general partner in March 2005. He has been employed with Global Companies LLC or its predecessors since 1987. Mr. Slifka served as President and Chief Executive Officer and a director of Global Companies LLC since July 2004 and as Chief Operating Officer and a director of Global Companies LLC from its formation in December 1998 to July 2004. Prior to 1998, Mr. Slifka held various senior positions in the accounting, supply, distribution and marketing departments of the predecessors to Global Companies LLC. Mr. Slifka is a member of the board of directors and a shareholder of AE Holdings Corp., a privately held affiliated company. He currently serves as a member of the board of directors of the New York Oil Heat Association, the National Oilheat Research Alliance, New England Fuel Institute and the Energy Policy Research Foundation. He also is a member of the boards of directors of Massachusetts General Hospital Presidents Council, Massachusetts Youth Committed to Winning and Buckingham, Browne & Nichols. Mr. Slifka's extensive experience in all aspects of our business and his position as President and Chief Executive Officer of our general partner make him uniquely qualified to serve as a director of our general partner. Mr. Slifka is the son of Alfred A. Slifka and the nephew of Richard Slifka.

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        Andrew Slifka was elected to serve as a director of our general partner in April 2012. He has served as Executive Vice President of our general partner and as President of our Alliance Gasoline Division effective March 1, 2012. Prior to our acquisition of Alliance Energy LLC, he had been employed with Alliance Energy LLC or its predecessor, Alliance Energy Corp., in the following capacities: as President from November 2007 to March 2012, as Executive Vice President from 2003 to 2007, and as Vice President and General Manager for the Northeast Region from 1999 to 2003. Prior to 1999, Mr. Slifka held various positions in the supply, distribution and marketing departments of the predecessors to Global Companies LLC. He currently serves on the boards of directors of Independent Oil Marketers Association and CF&MS Fund Foundation and is a senior-level participant in various regional major branded petroleum programs, including serving as a representative to the Shell Regional Council. Mr. Slifka is the son of Richard Slifka and the nephew of Alfred A. Slifka.

        Thomas J. Hollister was elected to serve as a director of our general partner in August 2009. He has served as Chief Operating Officer and Chief Financial Officer of our general partner since January 2007 and Chief Financial Officer of our general partner since July 2006, when he was first employed with our general partner. From 2005 to March 2006, Mr. Hollister served as Vice Chairman of Citizens Financial Group and as Chairman, President and Chief Executive Officer of Citizens Capital, Inc., Citizens Financial Group's private equity and venture capital business. From 2004 to 2005, he served as President and Chief Executive Officer of Charter One Bank. From 1998 to 2004 he served as President and Chief Executive Officer of Citizens Bank of Massachusetts. He is chair of the board of Tufts Medical Center and chair of the board of Wheaton College. Mr. Hollister currently serves on the board of directors of Brookline Bancorp, where he serves as audit chair. He is the former board chair of the Greater Boston Chamber of Commerce, the Initiative for a New Economy and the Massachusetts Community & Banking Council. He previously served on the boards of directors of the Massachusetts Bankers Association, Macomber Construction Company, the Massachusetts Housing Investment Corporation, and Savings Bank Life Insurance of Massachusetts. His extensive financial and executive experience, as well as his broad community ties, are assets for our board of directors.

        Edward J. Faneuil was elected Executive Vice President, General Counsel and Secretary of our general partner in March 2005. He has been employed with Global Companies LLC or its predecessors since 1991. Mr. Faneuil served as General Counsel and Secretary of Global Companies LLC since its formation in December 1998. He currently serves on the board of directors of New England Fuel Institute and Independent Oil Marketers Association.

        Charles A. Rudinsky was elected Senior Vice President and Chief Accounting Officer of our general partner in March 2005 and was named Executive Vice President and Treasurer in February 2007. Mr. Rudinsky continues to serve as Chief Accounting Officer and Co-Director of Mergers & Acquisitions. He has been employed with Global Companies LLC or its predecessors since 1988. Mr. Rudinsky served as Assistant Controller from 1988 to 1997 and as the Senior Controller and Chief Accounting Officer of Global Companies LLC since its formation in December 1998.

        David K. McKown was elected to serve as a director of our general partner and as a member of the conflicts committee, the compensation committee and the audit committee of the board of directors of our general partner in October 2005. He has been a Senior Advisor to the Bank Loan Fund of Eaton Vance Management, whose principal business is creating, marketing and managing investment funds and providing investment management services to institutions and individuals, since 2000. In this capacity, he serves as a credit analyst and a research source for many of the changes in the accounting area, such as marked to market valuations, changes in bank lending rules and understanding of new financial products and derivatives. Mr. McKown retired in March 2000 having served as a Group Executive with BankBoston since 1993. Mr. McKown has been in the banking industry for over 40 years, where he acquired extensive accounting, financial structuring and negotiation skills, having worked at BankBoston for over 33 years as a Senior Credit Officer, the head of a workout unit, the head of BankBoston's energy lending group and the head of BankBoston's real estate and corporate finance departments. He also was a managing director of BankBoston's private equity unit. Mr. McKown has served on the boards of four public companies and four private companies in a variety of industries. He currently serves as a director of Safety Insurance Group, Newcastle Investment Co. and several private companies. Mr. McKown previously served as a member of the board of directors of Equity Office Properties. Mr. McKown's extensive financial expertise and longstanding work in BankBoston's energy practice make him well qualified to serve as a director of our general partner.

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        Robert J. McCool was elected to serve as a director of our general partner, the chair of the conflicts committee of the board of directors of our general partner, and a member of the compensation and audit committees of the board of directors of our general partner in October 2005. He has been an Advisor to Tetco Inc., a privately held company in the energy industry, since 1967. Mr. McCool has been in the refined petroleum industry for over 40 years. He worked for Mobil Oil for 33 years in various positions including manager, planning and financial analysis, controller, manager U.S. lubricants operations and manager, budget and controls for U.S. acquisitions. Mr. McCool retired in 1998 having served as Executive Vice President responsible for Mobil Oil's North and South America marketing and refining business. Mr. McCool's extensive experience with the financial, accounting and managerial aspects of the refined petroleum products industry make him well qualified to serve as a director of our general partner.

        Kenneth I. Watchmaker was elected to serve as a director of our general partner, a member of the conflicts and compensation committees of the board of directors of our general partner, and chair of the audit committee of the board of directors of our general partner in October 2005. He subsequently became chair of our general partner's compensation committee as well. He served as Executive Vice President and Chief Financial Officer of Reebok International Ltd. from 1995 until March 2006. Mr. Watchmaker joined Reebok International Ltd. in July 1992 as Executive Vice President, Operations and Finance, of the Reebok Brand. Prior to joining Reebok International Ltd., he was an audit partner at Ernst & Young LLP., where he had various responsibilities including partner in charge of merger and acquisition services, regional partner in charge of bankruptcy and insolvency services and regional partner in charge of retail industry services. Mr. Watchmaker also serves as a director and the chair of the audit committee of American Biltrite Inc. Mr. Watchmaker's broad audit and accounting experience, as well as his significant corporate and financial experience as a senior executive with public companies, make him a valuable member of our board of directors.

Section 16(a) Beneficial Ownership Reporting Compliance

        Section 16(a) of the Securities Exchange Act of 1934 requires directors and executive officers of our general partner and persons who beneficially own more than 10% of a class of our equity securities registered pursuant to Section 12 of the Securities Exchange Act of 1934 to file certain reports with the SEC and the NYSE concerning their beneficial ownership of such securities. Based solely upon a review of the copies of reports on Forms 3, 4 and 5 and amendments thereto furnished to us, or written representations that no reports on Form 5 were required, we believe that during the year ended December 31, 2012, the officers and directors of our general partner and beneficial owners of more than 10% of our equity securities registered pursuant to Section 12 were in compliance with the applicable requirements of Section 16(a).

Executive Sessions

        The board of directors of our general partner holds executive sessions for the non-management directors on a regular basis without management present. Since the non-management directors include directors who are not independent directors, the independent directors also meet in separate executive sessions without the other directors or management at least once each year to discuss such matters as the independent directors consider appropriate. In addition, any director may call for an executive session of non-management or independent directors at any board meeting. A majority of the independent directors selects a presiding director for any such executive session.

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Communications with Unitholders, Employees and Others

        Unitholders, employees and other interested persons who wish to communicate with the board of directors of our general partner, non-management or independent directors as a group, a committee of the board or a specific director may do so by transmitting correspondence addressed to the Board of Directors, Name of Director, Group or Committee, c/o Corporate Secretary, Global Partners LP, P.O. Box 9161, 800 South Street, Suite 200, Waltham, MA 02454-9161, Fax: 781-398-4165.

        Letters addressed to the board of directors of our general partner in general will be reviewed by the corporate secretary and relayed to the chairman of the board or the chair of the appropriate committee. Letters addressed to the non-management or independent directors in general will be relayed unopened to the chair of the audit committee. Letters addressed to a committee of the board of directors or a specific director will be relayed unopened to the chair of the committee or the specific director to whom they are addressed. All letters regarding accounting, accounting policies, internal accounting controls and procedures, auditing matters, financial reporting processes or disclosure controls and procedures are to be forwarded by the recipient director to the chair of the audit committee.

Code of Ethics

        Our general partner has adopted a code of business conduct and ethics that applies to all officers, directors and employees of our general partner, including the principal executive officer, principal financial officer and principal accounting officer, and to our subsidiaries and their officers, directors and employees.

        A copy of the code of business conduct and ethics is available on our website at www.globalp.com or may be obtained without charge upon written request to the General Counsel at: Global Partners LP, P.O. Box 9161, 800 South Street, Suite 200, Waltham, MA 02454-9161.

Corporate Governance Matters

        The NYSE requires the Chief Executive Officer of each listed company to certify annually that he is not aware of any violation by the company of the NYSE corporate governance listing standards as of the date of the certification, qualifying the certification to the extent necessary. The Chief Executive Officer of our general partner provided such certification to the NYSE in 2012.

        The certifications of our general partner's Chief Executive Officer and Chief Financial Officer required by the Securities Exchange Act of 1934 are included as exhibits to this Annual Report on Form 10-K.

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Item 11.    Executive Compensation.

        All of our executive officers and substantially all of our employees are employed by our general partner, except for our gasoline station and convenience store employees and certain union personnel, who are employed by Global Montello Group Corp. ("GMG"). Our general partner does not receive any management fee or other compensation for its management of Global Partners LP. Our general partner and its affiliates are reimbursed for expenses incurred on our behalf. These expenses include the costs of employee, executive officer and director compensation and benefits properly allocable to Global Partners LP. Our partnership agreement provides that our general partner will determine the expenses that are allocable to Global Partners LP.

Compensation Discussion and Analysis

        We are managed and operated by the executive officers of our general partner. Executive officers of our general partner receive compensation in the form of base salaries, short-term incentive awards (contractual and/or discretionary) and long-term incentive awards. They are also eligible to participate in employee benefit plans and arrangements sponsored by our general partner or its affiliates, including plans that may be established by our general partner or its affiliates in the future. Our named executive officers (defined below) serve as executive officers of our general partner and each of our wholly owned subsidiaries. The compensation described herein reflects their total compensation for services to us, our general partner and our subsidiaries.

        Our "named executive officers" include Mr. Eric Slifka, our Chief Executive Officer ("CEO"), Mr. Thomas J. Hollister, our Chief Financial Officer ("CFO") and Chief Operating Officer ("COO"), and the three other most highly compensated executive officers during 2012, who were Mr. Andrew Slifka, our Executive Vice President and President of our Alliance Gasoline Division, Mr. Charles A. Rudinsky, our Executive Vice President and Chief Accounting Officer, and Mr. Edward J. Faneuil, our Executive Vice President and General Counsel. Messrs. Eric Slifka, Andrew Slifka, Hollister and Faneuil each have employment agreements with our general partner. Mr. Rudinsky is an employee at-will and does not have an employment agreement.

        The compensation committee of the board of directors of our general partner (the "Compensation Committee") has direct responsibility for the compensation of our CEO based upon (i) contractual obligations pursuant to the employment agreement between our CEO and our general partner, and (ii) compensation parameters established by the Compensation Committee with respect to salary adjustments, incentive plans and discretionary bonuses, if any. The Compensation Committee also has oversight and approval authority for the compensation of our named executive officers other than our CEO based upon our CEO's recommendations, including awards under any incentive plans in which the named executive officers participate, and our general partner's contractual obligations pursuant to employment agreements with three of our named executive officers.

Compensation Objectives

        The objectives of our compensation program with respect to our executive officers are to attract, engage and retain individuals with the requisite knowledge, experience and skill sets required for our future success. Our compensation program is intended to motivate and inspire employee behavior that fosters high performance, and to support our overall business objectives. To achieve these objectives, we aim to provide each executive officer with a competitive total compensation program. We currently utilize the following compensation components:

    Base salaries and benefits designed to attract and retain high caliber employees;

    Short-term, performance-based incentives and discretionary bonus awards designed to focus employees on key business objectives for a particular year; and

    Long-term, equity-based and/or performance-based cash incentive awards designed to support the achievement of our long-term business objectives and the retention of key personnel.

Compensation Methodology

        Our general partner uses third-party compensation consultants to study and supply market comparable compensation data and to assist our management and the Compensation Committee in formulating competitive compensation plans. The Compensation Committee retained BDO USA, LLP ("BDO") as an outside compensation consultant during 2012.

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        Under our executive compensation structure, our goal is for our named executive officers' total compensation to fall between the median (50th percentile) and 75th percentile of competitive total compensation levels, as identified by our compensation consultant's benchmarking results, following any adjustments made to marketplace pay levels in order to account for significant responsibilities that are assigned to our named executive officers and that exceed the scope of responsibilities generally associated with the external benchmark positions to which they are compared, specifically:

    Our CFO also serves as our COO and, as such, has responsibilities for many operational areas that are not commonly assigned to chief financial officer positions;

    Our Executive Vice President and General Counsel is responsible for all our environmental compliance functions, many of our human resources matters, many operational activities as determined by our CEO and many of our business transactions that he manages in an executive as well as a legal capacity;

    Our Executive Vice President and Chief Accounting Officer, who also serves as co-director of our mergers and acquisitions activities, is responsible for our financial analyses in connection with our acquisition due diligence; and

    Our Executive Vice President who also serves as President of our Alliance Gasoline Division has executive responsibilities as well as primary oversight of our gasoline and convenience store business.

        During 2012, our named executive officers' total compensation generally fell between the targeted range described above based upon the results of benchmarking analyses performed by BDO in prior years, which included (i) data from the Watson Wyatt Worldwide Executive Compensation Survey; (ii) data with respect to a group of more than 220 companies with market capitalizations of $200 million to $600 million, a range which was comparable to our market capitalization at the time of the study; and (iii) data with respect to a multi-factor based group of 17 energy and non-energy companies which had market capitalizations of $200 million to $600 million and between 100 to 600 employees.

        In 2012 and the first calendar quarter of 2013, BDO worked with our Compensation Committee to revisit earlier benchmarking criteria and update them to better reflect a peer group of companies consistent with the size and scope of our business as it transformed during 2012, with our expanded product lines, increased focus on transportation logistics and growth in our gasoline station and convenience store business. In connection with this evaluation, BDO updated competitive pay level analyses for our named executive officers and analyzed competitive compensation levels for independent members of our general partner's board of directors for use during 2013 and future years. Analyses regarding competitive pay practices for named executive officers were updated based on information contained in proxies filed by several groups of companies with various characteristics comparable and relevant to our current size and scope of operations, including: 227 companies with comparable market capitalization and employees; 131 companies with comparable market capitalization and total assets; 32 oil and gas distribution and storage companies; 11 additional companies with comparable market capitalization, assets and related business operations; and nine companies in related businesses. Competitive methods and levels of compensation for non-employee members of our general partner's board of directors were analyzed using the proxy filings from same external groups of companies described above.

        In addition, BDO has continued to work with our Compensation Committee in 2013 to update the performance targets and associated levels of payouts contained in our 2013 short-term incentive plan for our named executive officers. Plan modifications were made to incorporate the increased scope of our operations and to ensure the plan is fully aligned with and consistent with our efforts to achieve critical business objectives. A complete description of changes made to the short-term incentive plan is included in the next section,—Elements of Compensation.

Elements of Compensation

        Our executive compensation structure utilizes complementary components to align our compensation with the needs of our business and to provide for desired levels of pay that competitively compensate our executive management personnel. We administer the program on the basis of total compensation. As described above, our goal is to target total compensation levels (i.e., base salary plus short and long-term incentives) for our named executive officers to fall between the median (50th percentile) and 75th percentile compensation levels in our competitive marketplace. When we perform above or below our performance goals, we expect that result will be reflected in our compensation levels.

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        The elements of the 2012 executive officer compensation of our general partner are base salaries, discretionary bonuses, short-term incentive awards, retirement and health benefits, and perquisites consistent with those provided to executive officers generally and as may be approved by the Compensation Committee from time to time.

        A description of the components of the compensation program and principles used to guide their administration appears below:

Base Salaries

        Each named executive officer's base salary is a fixed component of compensation for each year. Base salary is designed to compensate executives for the responsibility of the level of the position they hold and sustained individual performance (including experience, scope of responsibility, results achieved and future potential). Base salaries for four of our five named executive officers are set by the terms of their respective employment agreements. Salaries for our named executive officers were not changed during 2012.

Short-Term Incentive Awards—Contractual

        Thomas Hollister, our COO and CFO, is entitled to annual contractual bonuses under his employment agreement with our general partner based upon our achievement of specific targets established by the Compensation Committee. In 2009, the Compensation Committee implemented our general partner's initial Short-Term Incentive Plan, and in 2012 our general partner's Short-Term Incentive Plan was redesigned (see Short-Term Incentive Plans). Prior to the Compensation Committee's determination of Mr. Hollister's awards for each of 2010, 2011 and 2012 under our general partner's then applicable Short-Term Incentive Plan, Mr. Hollister waived his annual contractual bonuses for those years. For each of 2010, 2011 and 2012, Mr. Hollister was paid a bonus under our general partner's then applicable Short-Term Incentive Plan in an amount in excess of what he would have received as a contractual bonus under his employment agreement with our general partner.

Short-Term Incentive Plans

        Our general partner established a cash bonus pool for 2012 to fund short-term incentive awards for each of our named executive officers. Target awards under our general partner's short-term incentive plan for 2012 (the "STIP") included a performance-based component, for which 50% of the cash bonus pool was available (the "STIP Performance Component"), and a discretionary component, for which the other 50% of the cash bonus pool was available (the "STIP Discretionary Component"). Incentive awards earned under the STIP were based on the Partnership's actual performance in relation to a specified objective for distributable cash flow established by our Compensation Committee in March 2012 (the "DCF objective"), as adjusted by the Compensation Committee to reflect our acquisition of Alliance Energy LLC ("Alliance"), which occurred after the named executive officers' incentive targets were set by our Compensation Committee. Under our general partner's Short-Term Incentive Plan, for purposes of determining whether a specified target was achieved, "distributable cash flow" (a non-GAAP financial measure used by management) means our net income plus depreciation and amortization, less our maintenance capital expenditures ("DCF"). DCF is discussed under "Results of Operations—Evaluating Our Results of Operations" and reconciled to its most directly comparable GAAP financial measures under "Results of Operations—Key Performance Indicators" in Item 7, "Management's Discussion and Analysis of Financial Conditions and Results of Operations."

        Under the STIP, each of our named executive officers was assigned an incentive target value expressed as a percentage of his base salary. The 2012 incentive target values were: 100% (or $800,000) for Mr. Eric Slifka; 58% (or $337,500) for Mr. Hollister; 47% (or $200,000) for Mr. Andrew Slifka; 37% (or $137,500) for Mr. Faneuil; and 41% or ($112,500) for Mr. Rudinsky. 50% of the target value for each named executive officer was allocated to his STIP Performance Component (the "50% Performance-Based Payout Target"), and 50% was allocated to his STIP Discretionary Component (the "50% Discretionary Payout Target").

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        STIP Performance Component (50% of the incentive target value):    Under the terms of the STIP, 100% of the STIP Performance Component is earned when the DCF objective is achieved. However, the STIP also provides for an increased payout under the STIP Performance Component when the DCF objective is exceeded, a reduced payout under the STIP Performance Component when the DCF objective is not achieved, and no payout if the STIP Performance Component minimum threshold is not achieved. Such increases and reductions in payouts are determined in accordance with an award payout grid adopted by the Compensation Committee at the time that the STIP was established. We exceeded our DCF objective for 2012 of $53.1million (which DCF objective was established in March 2012), and therefore the full 50% Performance Component was earned. The Partnership earned $80.8 million of DCF in 2012, which was adjusted to $75.0 million by the Compensation Committee to reflect (i) an additional approximately $4.0 million of one-time charges that occurred during 2012 related to our acquisition of Alliance, and (ii) a reduction of approximately $9.8 million of distributions paid on the common units that were issued to AE Holdings Corp. as payment of the purchase price for Alliance. After such adjustments and in accordance with the terms of the STIP , the STIP Performance Component of the named executive officers' 2012 awards was adjusted upward to 150% of each named executive officer's 50% Performance-Based Payout Target.

        STIP Discretionary Component (50% of the incentive target value):    The STIP Discretionary Component is intended to be used as a discretionary award, allowing the Compensation Committee to supplement the performance metric by analyzing other factors that it may elect to use for determining the STIP Performance Component. Such factors include, without limitation, market factors and significant acquisitions, developments and ventures accomplished by us and, as may be applicable, the contributions of any or all of the named executive officers. The Compensation Committee awarded a range of 87% to 200% of the STIP Discretionary Component for 2012 as follows: 200% (or $800,000) for Mr. Eric Slifka; 87% (or $146,875) for Mr. Hollister; 150% (or $150,000) for Mr. Andrew Slifka; 200% (or $137,500) for Mr. Faneuil; and 102% or ($57,125) for Mr. Rudinsky.

        Each of our named executive officers earned a short-term incentive award for 2012. A summary of these awards appears in the table below:

Name
   
  Target
Value as a
%
of Salary
  Target
Value
($)
  2012 Award
Value as a %
of Target
Value
  2012
Award
Payouts
($)
 

Eric Slifka

  Total Award     100%     800,000     175%     1,400,000  

  Performance     50%     400,000     150%     600,000  

  Discretionary     50%     400,000     200%     800,000  

Thomas J. Hollister

 

Total Award

   
58%
   
337,500
   
119%
   
400,000
 

  Performance     29%     168,750     150%     253,125  

  Discretionary     29%     168,750     87%     146,875  

Andrew P. Slifka

 

Total Award

   
47%
   
200,000
   
150%
   
300,000
 

  Performance     23.5%     100,000     150%     150,000  

  Discretionary     23.5%     100,000     150%     150,000  

Edward J. Faneuil

 

Total Award

   
37%
   
137,500
   
175%
   
240,625
 

  Performance     18.5%     68,750     150%     103,125  

  Discretionary     18.5%     68,750     200%     137,500  

Charles A. Rudinsky

 

Total Award

   
41%
   
112,500
   
126%
   
141,500
 

  Performance     20.5%     56,250     150%     84,375  

  Discretionary     20.5%     56,250     102%     57,125  

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        2013 Short-Term Incentive Plan.    In 2013 the Compensation Committee, with the advice of its compensation consultant, updated our 2013 Short-Term Incentive Plan. The Compensation Committee revised the DCF performance levels and incentive award opportunities associated with them based on the business objectives established for 2013. The 2013 STIP establishes a target incentive percentage for each participant ranging from 41% to 100% of base salary, which reflects an increase of 155% for Mr. Faneuil and the same target percentages used during 2012 for the other named executive officers. Awards under the 2013 STIP may range from 0% to 200% of each participant's target incentive percentage. The weightings of the 2013 STIP's Performance Component and Discretionary Component remain 50% and 50%, respectively, the same as in the 2012 plan.

    The 2013 Performance Component (50% of the incentive target value)—The Compensation Committee increased the DCF objective for 2013, subject to adjustment by the Compensation Committee for certain acquisitions and events during 2013 that the Compensation Committee in its sole discretion determines to have caused unusual, one-time increases or decreases in DCF. Awards granted by the Compensation Committee may range from 0% to 200% of a plan participant's 2013 Performance Component. A minimum of 92% of the 2013 DCF objective must be achieved before plan participants would earn any portion of the 2013 Performance Component. Under the 2013 STIP, a plan participant's incentive opportunity increases to a maximum of 200% of the Performance Component at 130% of the 2013 DCF objective, and is determined on a quantitative basis solely based on our actual DCF for 2013.

    The Discretionary Component (50% of the incentive target value)—The Compensation Committee has discretion in determining the 2013 Discretionary Component for any plan participant under the 2013 STIP, within a range of 0% to 200% of the 2013 Discretionary Component, and based upon (i) the Compensation Committee's consideration of management's performance over the course of the 2013 plan year; (ii) the CEO's assessment of other members of our management; (iii) our overall financial results for the year in relation to our business plan; and (iv) any significant mitigating factor(s) that may have influenced a plan participant's performance, positively or negatively. The objective of considering these factors is to arrive at a decision that best reflects the Compensation Committee's overall assessment of management's performance. The Compensation Committee believes that when combined with the Performance Component, the results will more accurately reflect a plan participant's performance in light of the relevant factors.

Annual Bonuses—Discretionary

        Our compensation program for named executive officers contains a provision for the Compensation Committee to award a discretionary bonus to recognize significant contributions made by an executive in the course of the year. Typically, these are one-time awards and not associated with any of our incentive plans. The Compensation Committee may make discretionary bonus awards to our CEO. Our CEO may also recommend discretionary bonus awards for all other named executive officers for consideration and approval by the Compensation Committee for similar purposes.

        In recognition of their extraordinary performance during 2012, the Compensation Committee awarded discretionary bonus payments to our CEO in the amount of $200,000 and to our Executive Vice President and General Counsel in the amount of $59,375.

        The Compensation Committee awarded the named executive officers special discretionary bonuses in the amounts of $270,000, $25,500, $97,500 and $32,500, respectively, for Messrs. Eric Slifka, Hollister, Faneuil and Rudinsky in respect of 2011. The Compensation Committee elected to not award any discretionary bonus payments in respect of 2010.

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Long-Term Incentive Plans

        2011 CEO Performance-Based Cash Incentive Plan.    On December 31, 2011, pursuant to a contractual commitment in Eric Slifka's 2012-2014 employment agreement with our general partner, the Compensation Committee included provisions for a new long-term performance-based cash incentive plan. The new plan replaced a three-year grant of phantom units to Mr. Slifka pursuant to his 2009-2011 employment agreement with our general partner, which vested in six approximately equal installments each June 30 and December 31 during the term of Mr. Slifka's 2009-2011 employment agreement. The new long-term performance-based cash incentive plan is based solely on the achievement of distribution growth to our unitholders over the term of Mr. Slifka's employment agreement, using the 3-year period from January 1, 2012 through December 31, 2014 and an annualized $2.00 per unit distribution to unitholders (subject to adjustment by the Compensation Committee as set forth in Mr. Slifka's employment agreement) as the baseline against which Mr. Slifka's performance will be measured over the 2012-2014 period.

        2009 Awards.    On February 5, 2009, the Compensation Committee granted 88,183, 61,728, 48,501 and 17,637 phantom units (without Distribution Equivalent Rights ("DERs")) under the LTIP, respectively, to Messrs. Eric Slifka, Hollister, Faneuil and Rudinsky. Grant levels were established by the Compensation Committee to achieve the overall objectives of the compensation program.

        The phantom units granted in 2009 will vest and become payable on a one-for-one basis in common units (and/or cash in lieu thereof) on December 31, 2013 (or potentially sooner as described below). A portion (25%) of the February 5, 2009 phantom units vested on August 21, 2009 when the Compensation Committee determined that the first Average Unit Price condition ($21.00 for 10 consecutive trading days) was satisfied. A second portion (25%) of the February 5, 2009 phantom units vested on February 18, 2011 when the Compensation Committee determined that the second Average Unit Price condition ($27.00 for 10 consecutive trading days) was satisfied. In each instance, our general partner delivered common units that it purchased in the open market to the named executive officers in payment for these vested phantom units. The remaining 50% of the phantom units granted to our named executive officers may vest earlier than December 31, 2013 if the Average Unit Price (as defined below) equals or exceeds specified $34.00 at any time during the period from June 5, 2012 through December 31, 2013. "Average Unit Price" means the closing market price per common unit for any 10-consecutive trading day period.

        The phantom units granted to Mr. Slifka on February 5, 2009 that do not otherwise vest early as described above will be subject to a performance goal. Specifically, any unvested phantom units held by Mr. Slifka on December 31, 2013 will vest only if the Partnership makes cumulative distributions on all units of the Partnership outstanding during the 20 consecutive quarters ending December 31, 2013 in an amount equal to or exceeding the minimum quarterly distribution (as defined in the Partnership's Agreement of Limited Partnership) on all such units.

        Any phantom units granted on February 5, 2009 that have not vested as of the end of the five-year cliff vesting period will be forfeited. Additionally, upon a change of control event (as defined in the grant agreement, as amended), all outstanding phantom units that were granted on February 5, 2009 to Messrs. Eric Slifka, Hollister and Faneuil only and that have not otherwise vested automatically will become fully vested (in the case of the phantom units awarded to Mr. Eric Slifka, without regard to the achievement of the performance goal.)

Retirement and Health Benefits; Perquisites

        Each of our named executive officers is eligible to participate in our general partner's health insurance plans, pension plan, 401(k) savings and profit sharing plan and other employee benefit plans in accordance with our general partner's policies and on the same general basis as other employees of our general partner. Under our general partner's pension plan, an employee becomes fully vested in his or her pension benefits after completing five years of service or, if earlier, upon termination due to

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death, disability or retirement after the first day of the month following the month in which the employee attains age 65. Certain employees are entitled to a supplemental benefit that vests over five years with 20% vesting on each December 31 beginning in 2010 and lasting through 2014. See "Other Benefits—Pension Benefits" for information with respect to eligibility standards and calculations of estimated annual pension benefits payable upon retirement under the pension plan. Our general partner's pension plan was frozen on December 31, 2009. Prior to 2013, our general partner's 401(k) savings and profit sharing plan provided for discretionary matching contributions by our general partner. Beginning in 2013, our general partner's 401(k) savings and profit sharing plan provides for employer matching contributions equal to 100% of elective deferrals up to the first 3% of eligible compensation plus 50% of elective deferrals up to the next 2% of eligible compensation. See "Other Benefits—401(k) Savings and Profit Sharing Plan" for additional information with respect to eligibility and contributions under this plan. Additional perquisites for our named executive officers may include payment of premiums for supplemental life and/or long-term disability insurance, automobile fringe benefits, club membership dues and payment of fees for professional financial planning, tax and/or legal advice.

        Prior to March 1, 2012, Andrew Slifka was employed by Alliance and eligible to participate in Alliance's pension plan and 401(k) savings and profit sharing plan. In connection with our acquisition of the membership interests in Alliance (the "Alliance Acquisition"), sponsorship of the Alliance plans was transferred to GMG and Mr. Andrew Slifka's employment was transferred to our general partner, at which point he became eligible for our general partner's 401(k) savings and profit sharing plan and pension plan. Final contributions to the former Alliance plans, which have been renamed to reflect GMG's sponsorship, on behalf of Mr. Andrew Slifka were made in January 2013. See "Other Benefits—Pension Benefits" and "Other Benefits—401(k) Savings and Profit Sharing Plan" for additional information with respect to eligibility and permitted contributions to these plans.

Relationship of Compensation Elements to Compensation Objectives

        We use base salaries to provide financial stability and to compensate our executive officers for fulfillment of their respective job duties.

        We use a short-term incentive plan with performance-based and discretionary components to align a significant portion of our executive officers' compensation with annual business performance and success, and to provide rewards and recognition for key annual business and financial results such as achieving increased quarterly distributions, enhancing our "virtual pipeline" from the mid-continent region of the United States and Canada to refiners and other customers on the East and West coasts, expanding our distribution, marketing and sales of petroleum products, expanding our gasoline station and convenience store assets and the geographic markets that we serve, and diversifying our product mix to enhance profitability and effectively managing our business. Short-term performance-based incentives also allow flexibility to reward performance and individual success consistent with such criteria as may be established from time to time by our CEO and the Compensation Committee.

        Our long-term incentive plans (performance-based cash incentive plan and LTIP) provide incentive and reward eligible participants for the achievement of long-term objectives, facilitate the retention of key employees by aligning their incentives with our long-term performance, continue to make our compensation mix more competitive, and align the interests of management with those of our unitholders.

        We offer a mix of traditional perquisites such as automobile fringe benefits and country/golf club memberships, and additional benefits, such as payment of professional financial planning and tax advice fees, that are tailored to address our executive officers' individual needs, to facilitate the performance of their job duties and to be competitive with the total compensation packages available to executive officers generally.

Tax Deductibility of Compensation

        With respect to the deduction limitations imposed under Section 162(m) of the Internal Revenue Code of 1986, as amended (the "Code"), we are a limited partnership and do not meet the definition of a "corporation" under Section 162(m). Accordingly, such limitations do not apply to compensation paid to the named executive officers.

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    Compensation of Named Executive Officers

        The following table sets forth certain information with respect to compensation of our CEO, our CFO and the three other most highly compensated executive officers during 2012, 2011 and 2010.


Summary Compensation Table

Name and Principal Position
  Year   Salary
($)
  Bonus
($) (2)
  Non-Equity
Incentive Plan
Compensation
($) (3)
  Change in
Pension Value
and
Nonqualified
Deferred
Compensation
Earnings
($)(4)
  All Other
Compensation
($) (5)
  Total
($)
 

Eric Slifka

    2012     800,000     200,000     1,400,000     240,443     102,547     2,742,990  

President and

    2011     800,000     270,000     480,000         95,414     1,645,414  

CEO (1)(4)(6)

    2010     800,000         480,000     13,725     93,798     1,387,523  

Andrew Slifka

   
2012
   
425,000
   
   
300,000
   
64,511
   
28,031
   
817,542
 

EVP and President of Alliance Gasoline Division (7)

                                           

Thomas J. Hollister

   
2012
   
578,000
   
   
400,000
   
24,715
   
36,995
   
1,039,710
 

COO and

    2011     578,000     25,500     202,500     1,939     29,951     837,890  

CFO (8)

    2010     578,000         202,500     9,559     34,739     824,798  

Edward J. Faneuil

   
2012
   
376,000
   
59,375
   
240,625
   
99,675
   
56,211
   
831,886
 

EVP, General

    2011     376,000     97,500     82,500     26,542     47,774     630,316  

Counsel and Secretary (9)

    2010     376,000         82,500     49,790     52,799     561,089  

Charles A. Rudinsky

   
2012
   
273,000
   
   
141,500
   
93,725
   
46,612
   
554,837
 

EVP and Chief

    2011     273,000     32,500     67,500     38,553     35,719     447,272  

Accounting Officer (10)

    2010     273,000         67,500     88,074     34,891     463,465  

(1)
The above table reflects the base salary paid to Mr. Eric Slifka in 2010 and 2011 pursuant to his employment agreement with our general partner that expired December 31, 2011. Effective January 1, 2012, Mr. Slifka entered into a new employment agreement with our general partner, pursuant to which his base salary remained $800,000.

(2)
In 2013, Messrs. Eric Slifka and Faneuil were paid discretionary bonuses of $200,000 and $59,375, respectively, for services performed during 2012, which discretionary bonuses were in addition to the payments they received in 2013 for services performed during 2012 under the 2012 Short-Term Incentive Plan. In 2012, Messrs. Slifka, Hollister, Faneuil and Rudinsky were paid discretionary bonuses of $270,000, $25,500, $97,500 and $32,500, respectively, for services performed during 2011, which discretionary bonuses were in addition to the payments they received in 2012 for services performed during 2011 under the 2011 Short-Term Incentive Plan. No discretionary bonuses were paid for services performed during 2010.

(3)
The bonuses paid to each of the named executive officers for services performed during 2012, 2011 and 2010 were determined in accordance with our general partner's Short-Term Incentive Plans described above under Elements of CompensationShort-Term Incentive Plans.

(4)
Mr. Eric Slifka's pension decreased in value by $11,068 in 2011 and therefore is shown as a $0 positive change in actuarial value under the column labeled "Change in Pension Value and Nonqualified Deferred Compensation Earnings".

(5)
All of our named executive officers are eligible to participate in our general partner's health insurance, pension, 401(k) and other employee benefit plans in accordance with our general partner's policies and on the same general basis as other employees of our general partner. See "Other Benefits—Pension Benefits" for information with respect to eligibility standards and calculations of estimated annual pension benefits payable upon retirement. Our general partner's 401(k) Savings and Profit Sharing Plan provides for matching and nonmatching contributions to the plan by our general partner. See "Other Benefits—401(k) Savings and Profit Sharing Plan" for additional information with respect to eligibility and permitted contributions to this plan.

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(6)
With respect to Mr. Eric Slifka, "All Other Compensation" for the years ended December 31, 2012, 2011 and 2010 includes the following perquisites in connection with his employment by our general partner: employer contributions paid by us under our general partner's 401(k) plan in the amounts of $12,667, $14,700 and $14,700, respectively for 2012, 2011 and 2010; a one-time cash payment to Mr. Slifka in the amount of $15,000 paid in 2012 in connection with the inability to make non-elective contributions to highly compensated employees under our general partner's 401(k) plan; the estimated incremental cost of an automobile provided by us for Mr. Slifka's use; medical and dental premiums paid by us; life insurance and long-term disability insurance premiums paid by us; club membership dues; legal fees; and professional financial planning and tax advice fees paid by us in the aggregate amounts of $36,386, $26,450 and $34,750, respectively, for 2012, 2011 and 2010.

(7)
Mr. Andrew Slifka was employed by Alliance prior to March 1, 2012. With respect to Mr. Slifka, "All Other Compensation" for the year ended December 31, 2012 includes the following perquisites in connection with his employment by our general partner: employer contributions paid by us under our general partner's 401(k) plan in the amount of $11,800 in 2012; the estimated incremental cost of an automobile provided by us for Mr. Slifka's use; medical and dental premiums paid by us; and life insurance and long-term disability insurance premiums paid by us. Mr. Slifka's employment agreement with our general partner also provides for payment by us of club membership dues and professional financial planning and tax advice fees in an aggregate amount not to exceed $15,000 on behalf of Mr. Slifka. Mr. Slifka did not receive any amount of this perquisite in 2012.

(8)
With respect to Mr. Hollister, "All Other Compensation" for the years ended December 31, 2012, 2011 and 2010 includes the following perquisites in connection with his employment by our general partner: employer contributions paid by us under our general partner's 401(k) plan in the amounts of $10,963, $12,250 and $7,350, respectively for 2012, 2011 and 2010; a one-time cash payment to Mr. Hollister in the amount of $7,500 paid in 2012 in connection with the inability to make non-elective contributions to highly compensated employees under our general partner's 401(k) plan; medical and dental premiums paid by us; and long-term disability insurance premiums paid by us.

(9)
With respect to Mr. Faneuil, "All Other Compensation" for the years ended December 31, 2012, 2011 and 2010 includes the following perquisites in connection with his employment by our general partner: employer contributions paid by us under our general partner's 401(k) plan in the amounts of $11,253, $14,700 and $12,250, respectively for 2012, 2011 and 2010; a one-time cash payment to Mr. Faneuil in the amount of $15,000 paid in 2012 in connection with the inability to make non-elective contributions to highly compensated employees under our general partner's 401(k) plan; the estimated incremental cost of an automobile provided by us for Mr. Faneuil's use; medical and dental premiums paid by us; long-term disability insurance premiums paid by us; and club membership dues paid by us.

(10)
With respect to Mr. Rudinsky, "All Other Compensation" for the years ended December 31, 2012, 2011 and 2010 includes the following perquisites in connection with his employment by our general partner: employer contributions paid by us under our general partner's 401(k) plan in the amounts of $10,910, $14,700 and $14,700, respectively for 2012, 2011 and 2010; a one-time cash payment to Mr. Rudinsky in the amount of $15,000 paid in 2012 in connection with the inability to make non-elective contributions to highly compensated employees under our general partner's 401(k) plan; the estimated incremental cost of an automobile provided by us for Mr. Rudinsky's use; medical and dental premiums paid by us; and life insurance and long-term disability insurance premiums paid by us.

Grants of Plan-Based Awards

        On March 12, 2013, the Compensation Committee awarded cash awards under our general partner's 2012 Short-Term Incentive Plan to our named executive officers in consideration of their respective services during the year ended December 31, 2012 in the following amounts: $1,400,000 for Mr. Eric Slifka, $400,000 for Mr. Hollister, $300,000 for Mr. Andrew Slifka, $240,625 for Mr. Faneuil and $141,500 for Mr. Rudinsky. These awards were paid promptly without restrictions. See "Elements of CompensationShort-Term Incentive Plan" for a discussion of the parameters on which the 2012 awards were determined.

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        The table below presents the minimum threshold, target and maximum possible payout amounts under our general partner's 2012 Short-Term Incentive Plan, depending upon our financial performance in 2012:

 
  Estimated Possible Payouts Under Non-Equity Incentive Plan Awards (1)  
Name
  Minimum
Threshold ($)
  Target ($)   Maximum ($)  

Eric Slifka

    40,000     800,000     1,600,000  

Thomas J. Hollister

    16,875     337,500     675,000  

Andrew Slifka

    10,000     200,000     400,000  

Edward J. Faneuil

    6,875     137,500     275,000  

Charles A. Rudinsky

    5,625     112,500     225,000  

(1)
No equity-based awards were granted during 2012.

Outstanding Equity Awards at Fiscal Year End

        The following table presents equity awards in the form of the unvested portion of phantom units granted under the LTIP to the named executive officers on February 5, 2009. The awards shown on the table below were the only equity awards held by the named executive officers at the end of the last fiscal year:

 
  Equity Incentive Plan Awards  
 
  Number of
Phantom Units
That Have Not
Vested
(#)
  Market or Payout
Value of Phantom
Units That Have
Not Vested
($) (1)
 

Eric Slifka

    44,091     1,117,707  

Thomas J. Hollister

    30,864     782,402  

Andrew Slifka

         

Edward J. Faneuil

    24,251     614,763  

Charles A. Rudinsky

    8,819     223,562  

(1)
These units will vest should the average closing price per unit for any 10-consecutive trading day period (the "Unit Price") during the period from June 5, 2012 through December 31, 2013 reach $34.00. These units also will vest on December 31, 2013 if the Unit Price does not reach $34.00 but the recipient remains continuously employed by our general partner through such date.

(2)
The market values of the equity awards shown in the table above were calculated based on the closing price of $25.35 per common unit on December 31, 2012.

        See "Elements of Compensation—Long-Term Incentive Plan" for a discussion of these phantom unit awards.

    Units Vested in the 2012 Fiscal Year

        No restricted unit awards and no phantom unit awards to named executive officers vested during the year ended December 31, 2012.

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    Employment and Related Agreements

        Eric Slifka is employed as President and Chief Executive Officer pursuant to an employment agreement with our general partner. The term of his initial employment agreement commenced on October 4, 2005 and continued through December 31, 2008. Effective December 31, 2008, Mr. Slifka entered into a subsequent employment agreement with our general partner which commenced January 1, 2009 and continued through December 31, 2011 (the "2008 Agreement"). Effective January 1, 2012, Mr. Slifka entered into a new employment agreement with our general partner which supersedes each of his prior two agreements (the "2012 Agreement").

        Like the 2008 Agreement, the 2012 Agreement provides for a base salary of $800,000 per year, subject to increase as of each January 1 during the term, as may be determined by the Compensation Committee. In addition, both agreements provide that Mr. Slifka: is (a) eligible to receive a cash bonus, from time to time, in an amount to be determined at the discretion of the Compensation Committee and (b) entitled to participate in our general partner's short-term incentive compensation plan, pursuant to which he shall be entitled to receive cash incentive amounts to be determined based upon the achievement of financial metrics to be established by the Compensation Committee in the first quarter of each fiscal year during the term of the agreement, with the annual "award target" amount being 100% of his base salary and the annual maximum cash incentive amount being 200% of his base salary; any such awards to be paid within two and one-half months after the applicable fiscal year end. Similarly, both agreements provide that Mr. Slifka also may be eligible to participate in any other incentive plans in which management employees may participate, as determined by the Compensation Committee. He is entitled to participate in such other benefit plans and programs as our general partner may provide for its executives in general.

        Mr. Slifka was entitled under the 2008 Agreement to participate in our general partner's LTIP, including without limitation (i) the December 31, 2008 grant to Mr. Slifka of 99,700 phantom units (with a contingent right to receive cash in amounts equal to the number of awarded phantom units outstanding multiplied by the cash distributions per common unit made by us from time to time), which became fully vested as of December 31, 2011, and (ii) the February 5, 2009 grant to Mr. Slifka of 88,183 performance-restricted phantom units under the LTIP. See "Elements of Compensation—Long-Term Incentive Plan." Under the 2012 Agreement, Mr. Slifka is entitled to receive awards under our general partner's Long-Term Performance-Based Cash Incentive Plan, which is determined based upon the achievement of distribution growth to the Partnership's unitholders over the term of his employment agreement, using the 3-year period from January 1, 2012 through December 31, 2014 and an annualized $2.00 per unit distribution to unitholders as the baseline against which Mr. Slifka's performance will be measured. Mr. Slifka also participates in our general partner's LTIP, in such forms and amounts as may be determined by the Compensation Committee, including, without limitation, the aforementioned February 5, 2009 grant to Mr. Slifka.

        Mr. Slifka's current employment agreement includes a confidentiality provision which, subject to typical exceptions for requirements of law and public knowledge (other than as a result of unauthorized disclosure by Mr. Slifka), will continue for two years following Mr. Slifka's termination of employment. The agreement also includes nonsolicitation and non-competition provisions which will continue for one year following Mr. Slifka's termination of employment. See "Potential Payments Upon Termination or Change of Control" for a discussion of the provisions in Mr. Slifka's employment agreement, as amended, relating to termination, change in control and related payment obligations.

        Thomas J. Hollister is employed as Chief Operating Officer and Chief Financial Officer of our general partner. Mr. Hollister's employment commenced effective July 1, 2006 and is on an "at will" basis, meaning that Mr. Hollister's employment has no specific duration and that, subject to the provisions of his employment agreement, either Mr. Hollister or our general partner may terminate his employment at any time for any reason. The agreement provides for a base salary of $550,000 for the initial 12-month period commencing July 1, 2006, and subsequent review by the Compensation

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Committee no less frequently than annually, at which time Mr. Hollister's base salary may be increased at the discretion of the Compensation Committee. In 2011, Mr. Hollister's base salary was $578,000. Mr. Hollister also is eligible to receive an annual cash bonus amount of $130,000 for each 12-month period that he is employed by our general partner, provided that we achieve a distributable cash flow target set by the Compensation Committee. Prior to the Compensation Committee's determination of Mr. Hollister's awards for each of 2010, 2011 and 2012 under our general partner's then applicable Short-Term Incentive Plan, Mr. Hollister waived his annual contractual bonuses for those years. Under our general partner's short-term incentive plan, Mr. Hollister's 2010, 2011 and 2012 target awards were set at amounts that exceed his contractual bonus amount. The employment agreement provides that Mr. Hollister also is entitled to participate in the LTIP and in such other benefit plans and programs as our general partner may provide for its employees in general. The agreement includes a confidentiality provision which, subject to typical exceptions for requirement of law and public knowledge (other than as a result of unauthorized disclosure by Mr. Hollister), will continue for two years following Mr. Hollister's termination of employment. The agreement also includes non-competition provisions which continue during the term of the agreement and for a period of two years thereafter. Also see "Potential Payments Upon Termination or Change of Control" for a discussion of the provisions in Mr. Hollister's employment agreement, as amended, relating to termination, change of control and related payment obligations.

        Andrew P. Slifka is employed as Executive Vice President of our general partner and President of the Alliance Gasoline Division of our partnership, pursuant to an employment agreement with our general partner. Mr. Slifka's initial employment agreement became effective as of March 1, 2012 and continues for a thirty-six (36) month term.

        Mr. Slifka's employment agreement provides for a base salary of $425,000 per year, subject to increase as of each January 1 during the term, as may be determined by the Compensation Committee. In addition, the agreement also provides that Mr. Slifka: is (a) eligible to receive a cash bonus, from time to time, in an amount to be determined at the discretion of the Compensation Committee and (b) entitled to participate in our general partner's short-term incentive compensation plan, pursuant to which he shall be entitled to receive cash incentive amounts, 50% of which shall be determined based upon the achievement of financial metrics to be established by the Compensation Committee in the first quarter of each fiscal year during the term of the agreement, and 50% of which shall be determined at the discretion of the Compensation Committee in the first quarter of each fiscal year during the term of the agreement, with the annual "award target" amount being $200,000 and the annual maximum cash incentive amount that may be awarded being $400,000; any such awards to be paid within two and one-half months after the applicable fiscal year end. Pursuant to his employment agreement, Mr. Slifka also may participate in our general partner's LTIP, in such forms and amounts as may be determined by the Compensation Committee. Similarly, his employment agreement provides that Mr. Slifka also may be eligible to participate in any other incentive plans in which management employees may participate, as determined by the Compensation Committee. He is entitled to participate in such other benefit plans and programs as our general partner may provide for its executives in general.

        Mr. Slifka's current employment agreement includes a confidentiality provision which, subject to typical exceptions for requirements of law and public knowledge (other than as a result of unauthorized disclosure by Mr. Slifka), will continue for two years following Mr. Slifka's termination of employment. The agreement also includes nonsolicitation and noncompetition provisions which will continue for one year following Mr. Slifka's termination of employment. See "Potential Payments Upon Termination or Change of Control" for a discussion of the provisions in Mr. Slifka's employment agreement, as amended, relating to termination, change in control and related payment obligations.

        Edward J. Faneuil is employed as Executive Vice President, General Counsel and Secretary pursuant to an employment agreement with our general partner. Mr. Faneuil's employment agreement became effective as of July 1, 2006 and pursuant to an amendment dated December 31, 2011, has been

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extended through December 31, 2014. In 2011, Mr. Faneuil's base salary was $376,000. Pursuant to the terms of his agreement, Mr. Faneuil's base salary is reviewed by the Compensation Committee at least annually. Mr. Faneuil also is entitled to receive bonuses in accordance with the then applicable short-term incentive plan as authorized by the Compensation Committee to be paid no later than March 15 of the calendar year immediately following the calendar year in which such bonuses are earned. Mr. Faneuil is eligible to participate in our general partner's health insurance, pension, 401(k) and other employee benefit plans and will also receive additional fringe benefits consistent with benefits previously provided to him under prior arrangements. Mr. Faneuil is eligible to participate in the LTIP on the same general basis as the other executive officers of our general partner. The agreement includes a confidentiality provision which, subject to typical exceptions for requirement of law and public knowledge (other than as a result of unauthorized disclosure by Mr. Faneuil), will continue for two years following Mr. Faneuil's termination of employment. The agreement also includes non-competition and non-solicitation provisions which continue during the term of the agreement and for a period of two years thereafter. Mr. Faneuil also has entered into deferred compensation agreements with each of our general partner and Alliance. See "—Deferred Compensation Agreements" below for a description of these non-qualified deferred compensation plans. Mr. Faneuil also has entered into a supplemental executive retirement plan ("SERP") agreement with our general partner to provide him with supplemental retirement benefits in consideration of past and future services provided by him and in recognition of his ineligibility to participate in our increased benefits program in connection with the freezing of benefits under the pension plan. See "—Supplemental Executive Retirement Plan Agreements" for a discussion of the provisions in Mr. Faneuil's SERP agreement. See "Potential Payments Upon Termination or Change of Control" for a discussion of the provisions in Mr. Faneuil's employment agreement, as amended, and in his amended and restated deferred compensation agreements relating to termination, change of control and related payment obligations.

        Charles A. Rudinsky, Executive Vice President and Chief Accounting Officer, is an at will employee and does not have an employment agreement with our general partner. In 2012, Mr. Rudinsky's base salary was $273,000. Mr. Rudinsky also has entered into a SERP agreement with our general partner to provide him with supplemental retirement benefits in consideration of past and future services provided by him and in recognition of his ineligibility to participate in our increased benefits program in connection with the freezing of benefits under the pension plan. Upon reaching normal retirement age, Mr. Rudinsky acquired a fully vested and nonforfeitable interest in his SERP benefit, which was paid out to him in 2012. See "—Supplemental Executive Retirement Plan Agreements" for a discussion of the provisions in Mr. Rudinsky's SERP agreement.

    Deferred Compensation Agreements

        On December 31, 2008, our general partner and Edward J. Faneuil entered into a deferred compensation agreement pursuant to which Mr. Faneuil will be subject to terms and conditions relating to confidential information, non-solicitation and non-competition, as provided therein (the "Global Deferred Compensation Agreement"). See "Potential Payments Upon Termination or Change of Control" for a discussion of the provisions in Mr. Faneuil's deferred compensation agreement relating to termination, change of control and related payment obligations.

        On September 23, 2009, Alliance and Mr. Faneuil entered into a deferred compensation agreement pursuant to which Mr. Faneuil will be subject to terms and conditions relating to confidential information, non-solicitation and non-competition, as provided therein (the "Alliance Deferred Compensation Agreement"). See "Potential Payments Upon Termination or Change of Control" for a discussion of the provisions in Mr. Faneuil's deferred compensation agreement relating to termination, change of control and related payment obligations.

    Supplemental Executive Retirement Agreements

        On December 31, 2009, our general partner entered into SERP agreements with each of Edward J. Faneuil and Charles A. Rudinsky. The value of the SERP benefits to be provided under the agreements, expressed as single lump sum payments, will be $159,355 for Mr. Faneuil and was $277,318 for Mr. Rudinsky. Mr. Faneuil will acquire a fully vested and nonforfeitable interest in his SERP benefit only to the extent he is continuously employed with our general partner from December 31, 2009 through the vesting dates set forth in his agreement, or if he dies or becomes Disabled (as such term is defined in the agreements) or if there is a Change in Control (as such term is defined in the agreements). Mr. Rudinsky became fully vested in his SERP benefit in 2012. See "Potential Payments Upon Termination or Change of Control" for a discussion of the provisions in Mr. Faneuil's and Mr. Rudinsky's SERP agreements relating to termination, change of control and related payment obligations.

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    Supplemental Payments in lieu of Discretionary Non-Matching Contributions under the Partnership's 401(k) and Profit Sharing Plan

        As a result of the Partnership's acquisition of the membership interests in Alliance (the "Alliance Acquisition"), effective as of March 1, 2012, our general partner determined that it was unable to continue making certain non-elective contributions to our general partner's 401(k) and Profit Sharing Plan on behalf of highly compensated employees (as such term is defined in Code section 414(q)), including each of the named executive officers of our general partner. In connection with the termination of these non-elective contributions, our general partner made one-time cash bonus payments in the amounts of $15,000, $7,500, $15,000 and $15,000 respectively, to each of Messrs. Eric Slifka, Hollister, Faneuil and Rudinsky.

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Potential Payments upon a Change of Control or Termination

        The following table shows potential payments to our named executive officers under existing contracts, agreements, plans or arrangements, whether written or unwritten, for various scenarios involving a change of control or termination of employment of each such named executive officer assuming a December 31, 2012 termination date. Amounts reflected in the table below with respect to LTIP awards were calculated based on the closing price of our common units of $25.35 per unit on December 31, 2012.

 
   
   
   
  Termination by general partner without Cause / Constructive Termination / Breach by general partner    
 
Name
  Change in
Control
($)
  Death
($)
  Disability
($)
  No Change
in Control
($)
  With a Change
in Control
($)
  Nonrenewal
($)
 

Eric Slifka (1)

                                     

Severance Amount

        3,200,000     3,200,000     3,200,000     4,800,000     800,000  

LTIP awards (6)

        1,117,707     1,117,707     894,165     1,117,707     894,165  

Fringe benefits

        102,547     102,547     102,547     102,547      

Life insurance benefits

        210,000                  
                           

Total

        4,630,254     4,420,254     4,196,712     6,020,254     1,694,165  

Thomas J. Hollister (2)

                                     

Severance Amount

                1,156,000     1,831,000      

LTIP awards (6)

    782,402     782,402     782,402     782,402     782,402      

Fringe benefits

                73,990     73,990      

Life insurance benefits

        210,000                  
                           

Total

    782,402     992,402     782,402     2,012,392     2,687,392      

Andrew Slifka (3)

                                     

Severance Amount

        956,250     1,500,000     1,500,000     1,500,000     543,750  

Fringe benefits

        63,070     63,070     63,070     63,070      

Life insurance benefits

        210,000                  
                           

Total

        1,229,320     1,563,070     1,563,070     1,563,070     543,750  

Edward J. Faneuil (4)

                                     

Severance Amount

                752,000     1,027,000      

Deferred Compensation

    2,041,122     2,041,122     1,830,203              

SERP benefit

    159,355     159,355     159,355     95,613     95,613      

LTIP awards (6)

    614,763             491,810     614,763      

Fringe benefits

                56,211     56,211      

Life insurance benefits

        210,000                  
                           

Total

    2,815,240     2,410,477     1,989,558     1,295,634     1,793,587      

Charles A. Rudinsky (5)

                                     

LTIP awards (6)

                         

Life insurance benefits

        350,000                  
                           

Total

        350,000                  

(1)   Eric Slifka

        Assuming that Mr. Slifka's employment was terminated on December 31, 2012, the employment agreement between our general partner and Mr. Slifka provides that, upon termination of his employment for any reason, he would have been entitled to receive (i) all amounts of his base salary due and owing up through the date of termination, (ii) any earned but unpaid bonus, (iii) all reimbursements of expenses appropriately and timely submitted, and (iv) any and all other amounts that may be due to him as of the date of termination (the "Accrued Obligations").

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        If Mr. Slifka's employment had been terminated by death or "Disability" (defined below) on December 31, 2012, within 10 days following such termination he (or his estate) would have been entitled to receive in addition to any Accrued Obligations:

    (i)
    a lump sum payment of $1,600,000 (equal to his then base salary multiplied by 200%); plus

    (ii)
    a lump sum payment of $1,600,000 (equal to his target incentive amount under the short-term incentive plan multiplied by 200%); plus

    (iii)
    his interests in our general partner's long-term incentive plans, as described below.

        Additionally, our general partner would have continued the monthly payment of all group health and similar insurance premiums on behalf of his spouse and dependents for 24 months following the date of termination. For purposes of Mr. Slifka's employment agreement, "Disability" is defined as a physical or mental condition which (a) renders Mr. Slifka, with or without reasonable accommodation, unable to engage in any substantial gainful activity by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than 12 months, or (b) by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than 12 months, results in Mr. Slifka receiving income replacement benefits for a period of not less than 3 months under an accident and health plan covering employees of our general partner.

        Assuming Mr. Slifka's employment had been terminated by our general partner without cause or by Mr. Slifka for reasons constituting "Constructive Termination" (defined below) on December 31, 2012, within 10 days following such termination he would have been entitled to receive in addition to any Accrued Obligations:

    (i)
    a lump sum payment of $1,600,000 (an amount equal to his then base salary multiplied by 200%); provided, however, that the lump sum payment would be increased to $2,400,000 (an amount equal to his then base salary multiplied by 300%) if such termination were for reasons constituting Constructive Termination and such termination occurred within 12 months following a "Change in Control" (defined below); plus

    (ii)
    a lump sum payment of $1,600,000 (an amount equal to his target incentive amount under the then applicable Short-Term Incentive Plan multiplied by 200%); provided, however, that the lump sum payment would be increased to $2,400,000 (an amount equal to his target incentive amount under the then applicable Short-Term Incentive Plan multiplied by 300%) if such termination were for reasons constituting Constructive Termination and such termination occurred within 12 months following a "Change in Control" (defined below); plus

    (iii)
    his interests in our general partner's long-term incentive plans, as described below.

        Also, our general partner would have continued the monthly payment of all group health and similar insurance premiums on behalf of Mr. Slifka's spouse and dependents for 24 months following the date of termination. For purposes of Mr. Slifka's employment agreement, "Constructive Termination" means termination of employment as a result of (a) any substantial diminution, without Mr. Slifka's written consent, in his working conditions consisting of (i) a material reduction in his duties and responsibilities, (ii) any change in the reporting structure so that he no longer reports solely to our Board of Directors, or (iii) a relocation of his place of work further than 40 miles from Waltham, Massachusetts, or (b) an uncured breach by the general partner of a material provision of the employment agreement, as amended. Pursuant to Mr. Slifka's employment agreement, a "Change in Control" would be deemed to have occurred upon (1) the date that any one person, entity or group (other than Alfred Slifka, Richard Slifka or Eric Slifka, or their respective family members or entities they control, individually or in the aggregate, directly or indirectly) acquires ownership of the membership interests of our general partner that, together with the membership interests of our general partner already held by such person, entity or group, constitutes more than 50% of the total fair market value or total voting power of the membership interests of our general partner; provided,

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however, if any one person, entity or group is considered to own more than 50% of the total fair market value or total voting power of the membership interests of our general partner, the acquisition of additional membership interests by the same person, entity or group shall not be deemed to be a Change in Control; (2) a consolidation or merger (in one transaction or a series of related transactions) of our general partner pursuant to which the holders of our general partner's equity securities immediately prior to such transaction or series of related transactions would not be the holders immediately after such transaction or series of related transactions of at least 50% of the voting power of the entity surviving such transaction or series of related transactions; or (3) the sale, lease, exchange or other transfer (in one transaction or a series of related transactions) of all or substantially all of our business and/or assets to a person other than Alfred Slifka, Richard Slifka or Eric Slifka, or their respective family members or entities they control, individually or in the aggregate, directly or indirectly.

        With respect to Mr. Slifka's interests in our general partner's long-term incentive plans:

    (i)
    Assuming, at December 31, 2012, that Mr. Slifka's employment had been terminated for death or Disability, or by our general partner without Cause or by Mr. Slifka for Constructive Termination, in either case within twelve months following a Change in Control, then all outstanding and unvested phantom units that were granted to Mr. Slifka under our LTIP on February 5, 2009 automatically would become fully vested without regard to the achievement of the performance goal provided in the grant. Using the closing market price of $25.35 per unit at December 31, 2012, the fair value of these phantom units would have been $1,117,707. There were no DERs associated with the February 5, 2009 grant.

    (ii)
    Assuming, at December 31, 2012, that Mr. Slifka's employment had been terminated by our general partner without Cause or by Mr. Slifka for Constructive Termination, but such termination did not occur within twelve months following a Change in Control, then because Mr. Slifka was employed by our general partner for four years of the five year vesting period for his February 5, 2009 LTIP award, he would become fully vested in 4/5 of the then outstanding and unvested phantom units granted to him, or 35,273 phantom units, automatically without regard to the achievement of the performance goal provided in the grant. Using the closing market price of $25.35 per unit at December 31, 2012, the fair value of these phantom units would have been $894,171. There were no DERs associated with the February 5, 2009 grant.

        In the event of termination for "Cause" (defined below), assuming a termination date of December 31, 2012, Mr. Slifka would have been entitled to receive the Accrued Obligations only. For purposes of Mr. Slifka's employment agreement, "Cause" is defined as (a) engaging in gross negligence or willful misconduct in the performance of duties, (b) committing an act of fraud, embezzlement or willful breach of a fiduciary duty to us including our general partner and any of our subsidiaries (including the unauthorized disclosure of any of our material secret, confidential and/or proprietary information, knowledge or data), (c) being convicted of a crime involving fraud, dishonesty or moral turpitude or any felony, or (d) breaching any material provision of the employment agreement.

        If Mr. Slifka's employment agreement had not been renewed by our general partner effective January 1, 2012 and he did not continue to serve as our general partner's President and Chief Executive Officer following the expiration of the then current term of his employment agreement, he would have been entitled to be paid a lump sum payment equal to 100% of his then base salary plus a proportionate amount of the then outstanding and unvested phantom units awarded to him under our LTIP on February 5, 2009 plus any Accrued Obligations. For purposes of the above table we have assumed that Mr. Slifka's employment agreement was due to be renewed as of December 31, 2012 and we used Mr. Slifka's current base salary.

(2)   Thomas J. Hollister

        The employment agreement between our general partner and Mr. Hollister provides, upon termination of his employment for any reason, that Mr. Hollister will receive payment through the date of termination of his employment of (i) any earned, but unpaid, base salary as then in effect, (ii) all earned, but unpaid, bonuses, and (iii) all accrued vacation, expense reimbursements and other benefits (other than severance benefits, except as provided below) due Mr. Hollister in accordance with the established plans and policies of our general partner or applicable law (the "Accrued Obligations").

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        In the event of a change in control (defined below), Mr. Hollister's employment agreement provides for accelerated vesting on any and all outstanding Partnership options, restricted units, phantom units, unit appreciation rights and other similar rights (under the LTIP or otherwise) held by him as in effect on the date of termination. The Compensation Committee granted to Mr. Hollister 61,728 phantom units (without DERs) on February 5, 2009, 15,432 of which vested and were paid to Mr. Hollister in August 2009 and another 15,432 of which vested and were paid to Mr. Hollister in February 2011. No other such options, restricted units, phantom units, unit appreciation rights and other similar rights had been granted to Mr. Hollister as of December 31, 2012. Assuming a change of control event (as defined in the grant) had occurred on December 31, 2012, all outstanding and unvested phantom units that were granted to Mr. Hollister on February 5, 2009 automatically would become fully vested. Using the closing market price of $25.35 per unit at December 31, 2012, the fair value of the February 5, 2009 awarded phantom units would have been $782,402. Pursuant to Mr. Hollister's employment agreement, a "change in control" is deemed to occur on the date that any one person, entity or group (other than Alfred Slifka, Richard Slifka or Eric Slifka, or their respective family members or entities they control, individually or in the aggregate, directly or indirectly) acquires ownership of the membership interests of our general partner that, together with the membership interests of our general partner already held by such person, entity or group, constitutes more than 50% of the total voting power of the membership interests of our general partner.

        Assuming Mr. Hollister's employment had been terminated on December 31, 2012 by our general partner for "Cause" (defined below) or by Mr. Hollister voluntarily (for reasons other than Constructive Termination), then following such termination Mr. Hollister (or his estate, if applicable) would have been entitled to the Accrued Obligations. For purposes of Mr. Hollister's employment agreement, "Cause" is defined as (1) engaging in gross negligence or willful misconduct in the performance of duties, (2) committing an act of fraud, embezzlement or willful breach of a fiduciary duty to us including our general partner and any of our subsidiaries (including the unauthorized disclosure of any material secret, confidential and/or proprietary information, knowledge or data of the Company or any of its subsidiaries), (3) being convicted of (or pleading no contest to) a crime involving fraud, dishonesty or moral turpitude or any felony, or (4) an uncured breach of any material provision of the agreement.

        Assuming Mr. Hollister's employment had been terminated on December 31, 2012 by reason of Mr. Hollister's death or "Disability" (defined below), then following such termination Mr. Hollister (or his estate, if applicable) would have been entitled to the Accrued Obligations plus accelerated vesting of all outstanding and unvested phantom units that were granted to Mr. Hollister on February 5, 2009. Using the closing market price of $25.35 per unit at December 31, 2012, the fair value of the February 5, 2009 awarded phantom units would have been $782,402. Pursuant to Mr. Hollister's employment agreement, "Disability" means a physical or mental disability or impairment which renders Mr. Hollister unable, with or without reasonable accommodation, to perform the essential functions of his duties for a period of at least 90 consecutive days and, following the expiration of the initial 90-day period, a medical doctor or other appropriate health care provider, in either case selected solely by our general partner, has delivered an opinion to our general partner that such physical or mental disability or impairment is expected to continue for at least an additional 90 consecutive days.

        Assuming Mr. Hollister's employment had been terminated on December 31, 2012 by our general partner without Cause, or by Mr. Hollister for reasons constituting "Constructive Termination" (defined below), Mr. Hollister would have been entitled to receive a severance payment in an amount equal to the sum of (i) twice his then base salary ($1,156,000), plus (ii) if such termination had occurred within 12 months following a Change in Control, an additional amount equal to twice his target incentive amount under the applicable short-term incentive for the fiscal year 2011 ($675,000), for a total severance amount of $1,831,000. Such severance payment would be payable monthly in 24 equal installments. During such severance payment payout period, Mr. Hollister would remain eligible to participate in our general partner's health insurance, pension, 401(k) and other employee benefit plans

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in accordance with our general partner's policies and on the same general basis as other employees. Additionally, in the absence of any Change in Control, all of the outstanding and unvested phantom units that were granted to Mr. Hollister on February 5, 2009 would automatically vest. Using the closing market price of $25.35 per unit at December 31, 2012, the fair value of the February 5, 2009 awarded phantom units would have been $782,402. Mr. Hollister's employment agreement defines "Constructive Termination" as the termination of employment by Mr. Hollister as a result of (i) an uncured breach by the general partner of a material provision of the employment agreement, as amended, (ii) the failure of any successor (whether direct or indirect, by purchase, merger or otherwise) to all or substantially all of our business and/or assets to expressly assume and agree to perform the employment agreement, as amended or (iii) any material diminution, without Mr. Hollister's written consent, in his working conditions consisting of (a) a material reduction in his duties and responsibilities as the Chief Operating Officer or Chief Financial Officer, (b) any change in the reporting structure so that he no longer reports to the President or Chief Executive Officer of our general partner, or (c) a relocation of his place of work further than 40 miles from Waltham, Massachusetts. Assuming a December 31, 2012 termination date, in the event Mr. Hollister elected to terminate his employment for constructive termination at any time within three months before a change in control and 12 months after a change in control, then in addition to the foregoing severance and benefits Mr. Hollister also would have been entitled to the accelerated vesting provisions described above.

        Our general partner is obligated to reimburse Mr. Hollister for any and all federal excise taxes and penalties (other than penalties imposed as a result of Mr. Hollister's actions), and any taxes imposed upon such reimbursement amounts, including, but not limited to, any federal, state and local income taxes, employment taxes, and other taxes, if any, which may become due pursuant to the application of Sections 4999 and/or 409A of the Code on any payments to Mr. Hollister in connection with the employment agreement, as amended.

(3)   Andrew Slifka

        The employment agreement between our general partner and Mr. Slifka provides, upon termination of his employment for any reason, that Mr. Slifka will receive payment through the date of termination of his employment of (i) any earned, but unpaid, base salary as then in effect, (ii) all earned, but unpaid, bonuses, and (iii) all accrued vacation, expense reimbursements and other benefits (other than severance benefits, except as provided below) due Mr. Slifka in accordance with the established plans and policies of our general partner or applicable law (the "Accrued Obligations").

        Assuming Mr. Slifka's employment had been terminated on December 31, 2012 by our general partner for "Cause" (defined below) or by Mr. Slifka voluntarily (for reasons other than Constructive Termination), then following such termination Mr. Slifka (or his estate, if applicable) would have been entitled to the Accrued Obligations. For purposes of Mr. Slifka's employment agreement, "Cause" is defined as (i) engaging in gross negligence or willful misconduct in the performance of duties, (ii) committing an act of fraud, embezzlement or willful breach of a fiduciary duty to us including our general partner and any of our subsidiaries (including the unauthorized disclosure of any material secret, confidential and/or proprietary information, knowledge or data of the Partnership or any of its subsidiaries), (iii) being convicted of a crime involving fraud or moral turpitude or any felony, or (iv) an uncured breach of any material provision of the agreement.

        Assuming Mr. Slifka's employment had been terminated on December 31, 2012 by reason of Mr. Slifka's death or "Disability" (defined below), then following such termination Mr. Slifka (or his estate, if applicable) would have been entitled to (i) the Accrued Obligations, and (ii) the base salary then in effect ($425,000) as well as all the fringe benefits that Mr. Slifka was receiving as of December 31, 2012 through February 28, 2015. Furthermore, if Mr. Slifka's employment is terminated due to his Disability, our general partner shall pay an amount equal to the product of 75% and the sum of (i) the base salary in effect as of December 31, 2012 ($425,000); and (ii) the average of the aggregate bonuses and short-term cash incentive amounts awarded to Mr. Slifka pursuant to the agreement, if any, since March 1, 2012.

        Pursuant to Mr. Slifka's employment agreement, "Disability" is defined as a physical or mental condition which (a) renders Mr. Slifka, with or without reasonable accommodation, unable to engage in any substantial gainful activity by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than 12 months, or (b) by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than 12 months, results in Mr. Slifka receiving income replacement benefits for a period of not less than three months under an accident and health plan covering employees of our general partner.

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        Assuming Mr. Slifka's employment had been terminated on December 31, 2012 by our general partner without Cause, or by Mr. Slifka for reasons constituting "Constructive Termination" (defined below), Mr. Slifka would have been entitled to receive a lump sum payment in an amount equal to the (i) base salary and fringe benefits that would have been payable to Mr. Slifka during the balance of the agreement, (ii) the aggregate bonus and short-term cash incentive amounts awarded to Mr. Slifka, if any, since March 1, 2012, and (iii) an additional lump sum amount equal to the product of 75% and the sum of (a) the base salary as in effect on December 31, 2012 ($425,000) and (b) the average of any bonuses and short-term cash incentive amounts awarded pursuant to the agreement, if any, since March 1, 2012. In addition, Mr. Slifka would be entitled to continue to receive any fringe benefits in effect on the date of such termination through the end of the term of his employment agreement.

        Mr. Slifka's employment agreement defines "Constructive Termination" as the termination of the agreement by Mr. Slifka as a result of any (i) substantial diminution, without his written consent, in Mr. Slifka's working conditions consisting of (a) a material reduction in his duties and responsibilities, (b) any change in the reporting structure so that he no longer reports solely to the President and Chief Executive Officer of our general partner, or (c) a relocation of his place of work further than 40 miles from Waltham, Massachusetts, or (ii) an uncured material breach of the agreement by our general partner. Assuming a December 31, 2012 termination date, in the event that Mr. Slifka elected to terminate his employment for constructive termination, he must provide notice to our general partner of the existence of any of the conditions set forth in the immediately preceding sentence within 90 days of the initial existence of such condition(s), and our general partner must fail to remedy such condition(s) within 30 days of such notice. In no event shall the date of termination in connection with a constructive termination occur any later than one year following the initial existence of the condition(s) constituting a constructive termination under the employment agreement.

        If Mr. Slifka's employment agreement is not renewed by our general partner at the end of the applicable term, and Mr. Slifka does not continue to serve as an Executive Vice President of our general partner or President of the Alliance Gasoline Division of the Partnership following the expiration of the employment agreement pursuant to a different employment agreement with our general partner, our general partner shall pay Mr. Slifka in 12 equal monthly installments an amount equal to the greater of (a) the product of 75% and the sum of (i) the base salary in effect as of the end of the agreement; and (ii) the average of the aggregate bonuses and short-term cash incentive amounts awarded to Mr. Slifka pursuant to the agreement, if any, for the two calendar years immediately preceding the expiration of the agreement; and (b) the base salary in effect as of the end of the agreement.

(4)   Edward J. Faneuil

        The employment agreement between our general partner and Mr. Faneuil, as amended, provides that, upon termination of his employment for any reason, Mr. Faneuil will receive payment through the date of termination of his employment of (i) any earned, but unpaid, base salary as then in effect, (ii) all earned, but unpaid, bonuses, and (iii) all accrued vacation, expense reimbursements and other benefits (other than severance benefits, except as provided below) due Mr. Faneuil in accordance with the established plans and policies of our general partner or applicable law (the "Accrued Obligations").

        In the event of a change in control (defined below), Mr. Faneuil's employment agreement provides for accelerated vesting on any and all outstanding Partnership options, restricted units, phantom units, unit appreciation rights and other similar rights (under the LTIP or otherwise) held by him as in effect on the date of termination. The Compensation Committee granted to Mr. Faneuil 48,501 phantom units (without DERs) on February 5, 2009, 12,125 of which vested and were paid to Mr. Faneuil in August 2009 and another 12,125 of which vested and were paid to Mr. Faneuil in February 2011. No other such options, restricted units, phantom units, unit appreciation rights and other similar rights had been granted to Mr. Faneuil as of December 31, 2012. Assuming a change of control event (as defined in the grant) had occurred on December 31, 2012, all outstanding and unvested phantom units and associated DERs that were granted to Mr. Faneuil on February 5, 2009 automatically would become fully vested. Using the closing market price of $25.35 per unit at December 31, 2011, the fair value of the February 5, 2009 awarded phantom units would have been $614,763. Pursuant to Mr. Faneuil's employment agreement, a "change in control" is deemed to occur on the date that any one person, entity or group (other than Alfred Slifka, Richard Slifka or Eric Slifka, or their respective family members or entities they control, individually or in the aggregate, directly or indirectly) acquires ownership of the membership interests of our general partner that, together with the membership interests of our general partner already held by such person, entity or group, constitutes more than 50% of the total voting power of the membership interests of our general partner.

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        Assuming Mr. Faneuil's employment had been terminated on December 31, 2012 (i) by our general partner for "Cause" (defined below), (ii) by Mr. Faneuil voluntarily (for reasons other than Constructive Termination), or (iii) by reason of Mr. Faneuil's death, then following such termination Mr. Faneuil (or his estate, if applicable) would have been entitled to the Accrued Obligations. For purposes of Mr. Faneuil's employment agreement, "Cause" is defined as (1) engaging in gross negligence or willful misconduct in the performance of duties, (2) committing an act of fraud, embezzlement or willful breach of a fiduciary duty to us including our general partner and any of our subsidiaries (including the unauthorized disclosure of any material secret, confidential and/or proprietary information, knowledge or data of the Company or any of its subsidiaries), (3) being convicted of (or pleading no contest to) a crime involving fraud, dishonesty or moral turpitude or any felony, or (4) an uncured breach of any material provision of the agreement.

        Assuming Mr. Faneuil's employment had been terminated on December 31, 2012 by our general partner without Cause, or by Mr. Faneuil for reasons constituting "Constructive Termination" (defined below), Mr. Faneuil would have been entitled to receive a severance payment in an amount equal to the sum of (i) twice his then base salary ($752,000), plus (ii) if such termination had occurred within 12 months following a Change in Control, an additional amount equal to twice his target incentive amount under the then applicable short-term incentive for the fiscal year ($275,000), for a total severance amount of $1,027,000. Such severance payment would be payable monthly in 24 equal installments. In addition, the general partner would provide health care continuation coverage benefits to Mr. Faneuil pursuant to the Consolidated Omnibus Budget Reconciliation Act of 1985 ("COBRA") and would continue to pay the applicable percentage of the medical insurance premium that it pays for active employees during the applicable COBRA coverage period. Mr. Faneuil's employment agreement defines "Constructive Termination" as the termination of employment by Mr. Faneuil as a result of (i) an uncured breach by the general partner of a material provision of the employment agreement, as amended, (ii) the failure of any successor (whether direct or indirect, by purchase, merger or otherwise) to all or substantially all of our business and/or assets to expressly assume and agree to perform the employment agreement, as amended or (iii) any material diminution, without Mr. Faneuil's written consent, in his working conditions consisting of (a) a material reduction in his duties and responsibilities as the Executive Vice-President and General Counsel, (b) any change in the reporting structure so that he no longer reports to the President or Chief Executive Officer of our general partner, or (c) a relocation of his place of work further than 40 miles from Waltham, Massachusetts. For purposes of Mr. Faneuil's employment agreement, however, Constructive Termination does not include a change in reporting structure as a result of our general partner becoming a subsidiary of an unrelated entity, including, without limitation, a change whereby Mr. Faneuil is not the chief legal officer or general counsel of the acquiring or parent entity or must report to the chief legal officer or general counsel of a currently unaffiliated parent corporation or entity. Assuming a December 31, 2012 termination date, in the event Mr. Faneuil elected to terminate his employment for constructive termination at any time within three months before a change in control and 12 months after a change in control, then in addition to the foregoing severance Mr. Faneuil also would have been entitled to the accelerated vesting provisions described above.

        Our general partner and Mr. Faneuil also entered into the Global Deferred Compensation Plan, pursuant to which Mr. Faneuil will be paid the sum of $70,000 per year (the "Global Deferred Compensation") in equal monthly installments of $5,833.33 on the first business day of each month for 15 years (180 months) commencing on the earlier of: (i) August 1, 2014, and (ii) the first business day of the month following Mr. Faneuil's "separation from service" (as defined in the Code) with our general partner for reasons other than "Cause" (as defined in the deferred compensation agreement), subject to earlier termination as provided in the agreement. In the event of an unforeseeable emergency as referenced in the deferred compensation agreement, our general partner will pay Mr. Faneuil within 15 days of the occurrence of the unforeseeable emergency the maximum amount allowable in a lump sum promptly following the occurrence of such unforeseeable emergency. The Global Deferred Compensation will be forfeited in its entirety in the event that our general partner terminates Mr. Faneuil's employment prior to August 1, 2014 for Cause or Mr. Faneuil terminates his employment for any reason other than death,

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disability or a Change in Control (as defined below). On and after the date on which Global Deferred Compensation payments commence, our general partner may terminate its obligations under the deferred compensation agreement for Cause or if our general partner subsequently determines within 18 months of Mr. Faneuil's termination that circumstances which would give rise to a for Cause termination of Mr. Faneuil otherwise existed at the time of his earlier termination. In the event of Mr. Faneuil's death prior to his receiving any or all of the aggregate amount of the Global Deferred Compensation (including the event of Mr. Faneuil's death before August 1, 2014), our general partner will pay Mr. Faneuil's beneficiary within 60 days of the date of his death a single lump sum payment in an amount equal to the present value of the remaining payments that would have been paid to Mr. Faneuil. If there is a Change in Control or Mr. Faneuil is determined to have become disabled prior to his receiving any or all of the aggregate amount of the Global Deferred Compensation (including if the Change of Control occurred or the determination that Mr. Faneuil became disabled were made before August 1, 2014), our general partner will pay to Mr. Faneuil within 60 days of the effective date of the Change in Control or the determination that Mr. Faneuil became disabled a single lump sum payment in an amount equal to the present value of the remaining payments that would have been paid to him had the Change in Control not occurred or had Mr. Faneuil not become disabled. For purposes of the Global Deferred Compensation Agreement, "Cause", as defined in the deferred compensation agreement, means (a) any uncured material breach by Mr. Faneuil of his obligations under the Global Deferred Compensation Agreement, (b) any breach by Mr. Faneuil of his confidentiality, non-competition and non-solicitation obligations set forth on Exhibit "A" to the Global Deferred Compensation Agreement or included in his employment agreement with our general partner, (c) engagement in gross negligence or willful misconduct in the performance of his duties, (d) a conviction or plea of no contest to a crime involving fraud, dishonesty or moral turpitude or any felony, or (e) the commission of an act of embezzlement or willful breach of a fiduciary duty to our general partner, the Partnership or any of its Affiliates.

        Alliance and Mr. Faneuil also entered into the Alliance Deferred Compensation Agreement, the terms of which, including, without limitation, the payment terms thereunder, are on the same terms as those of the Global Deferred Compensation Agreement. Accordingly, the various scenarios involving a change of control or termination of employment under the Alliance Deferred Compensation Agreement are identical to those described above with respect to the Global Deferred Compensation Agreement.

        Mr. Faneuil entered into a SERP agreement with our general partner on December 31, 2009. The value of the benefit to be provided under the SERP agreement, expressed as a single lump sum payment, is $159,355. Mr. Faneuil will acquire a fully vested and nonforfeitable interest in his SERP benefit only to the extent he is continuously employed with our general partner from December 31, 2009 through the vesting dates set forth in his SERP agreement, or if he dies or becomes Disabled (as such term is defined in the SERP agreement) after December 31, 2009 while employed with our general partner or if there is a Change in Control (as such term is defined in the SERP agreement).

        Our general partner is obligated to reimburse Mr. Faneuil for any and all federal excise taxes and penalties (other than penalties imposed as a result of Mr. Faneuil's actions), and any taxes imposed upon such reimbursement amounts, including, but not limited to, any federal, state and local income taxes, employment taxes, and other taxes, if any, which may become due pursuant to the application of Sections 4999 and/or 409A of the Code on any payments to Mr. Faneuil in connection with the employment agreement, as amended. Mr. Faneuil and our general partner have agreed to reform any provision of the deferred compensation agreement, as amended, between them in a manner mutually agreeable to avoid imposition of any additional tax under the provisions of Section 409A of the Code and related regulations and Treasury pronouncements.

(5)   Charles A. Rudinsky

        Upon reaching normal retirement age, Mr. Rudinsky acquired a fully vested and nonforfeitable interest in his SERP benefit, which was paid out to him in 2012.

(6)   LTIP Awards

        On February 5, 2009, the Compensation Committee made grants of 88,183, 61,728, 48,501 and 17,637 phantom units under the LTIP, respectively, to Messrs. Eric Slifka, Hollister, Faneuil and Rudinsky. Upon a change of control event (as defined in the grant, as amended), all outstanding phantom units that were granted on February 5, 2009 to Messrs. Slifka, Hollister and Faneuil only and that have not otherwise vested automatically will become fully vested (in the case of the phantom units awarded to Mr. Slifka, without regard to the achievement of the performance goal.). See "Elements of Compensation—Long-Term Incentive Plan" for information regarding performance restrictions and additional vesting terms.

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Other Benefits

Pension Benefits

        The table below sets forth information regarding the present value as of December 31, 2012 of the accumulated benefits of our named executive officers under the Global Partners LP Pension Plan, Supplemental Executive Retirement Agreements and, with respect to Mr. Faneuil, the Global and Alliance Deferred Compensation Agreements. Amounts with respect to the Global and Alliance Deferred Compensation Plans are reflected in the table below because they represent a fixed entitlement.


Pension Benefits at December 31, 2012

Name
  Plan Name   Number of Years
Credited Service
  Present Value of
Accumulated Benefit
  Payments During
Last Fiscal Year
 
 
   
  (#)
  ($)
  ($)
 

Eric Slifka (2)

    (1 )   24     473,377      

Thomas J. Hollister

    (1 )   5     111,970      

Andrew P. Slifka

    (1 )   7     23,011      

Andrew P. Slifka

    (3 )   12     201,603      

Edward J. Faneuil

    (1 )   20     566,252      

Edward J. Faneuil

    (4 )   n/a     158,883      

Edward J. Faneuil

    (5 )   n/a     1,020,561      

Edward J. Faneuil

    (6 )   n/a     1,020,561      

Charles A. Rudinsky (7)

    (1 )   27     963,923      

Charles A. Rudinsky (8)

    (4 )   n/a         377,318  

(1)
Global Partners LP Pension Plan

(2)
Includes a supplemental benefit in connection with the freezing of benefits under the Global Partners LP Pension Plan

(3)
Global Montello Group Corp. Pension Plan

(4)
Supplemental Executive Retirement Agreement

(5)
Global Deferred Compensation Agreement

(6)
Alliance Deferred Compensation Agreement

(7)
From 1984 through 1988, Mr. Rudinsky was employed by National Petroleum Corporation, Inc. In 1988, a predecessor of ours acquired all of the outstanding capital stock of National Petroleum Corporation, Inc. and Mr. Rudinsky became an employee of said predecessor of ours. In connection with this acquisition, and for purposes of the Global Partners LP Pension Plan, Mr. Rudinsky was credited with four additional years of service for the period from 1984 through 1988.

(8)
Mr. Rudinsky received his Supplemental Executive Retirement Agreement benefit of $277,318 in 2012.

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Global Partners LP Pension Plan

        Effective December 31, 2009, the Global Partners LP Pension Plan (the "Pension Plan") was amended to freeze participation in and benefit accruals under the Pension Plan. Prior to the freeze, all employees who (1) were 21 years of age or older, (2) were not covered by a collective bargaining agreement providing for union pension benefits, and (3) had been employed by our predecessor, our general partner or one of our operating subsidiaries for one year prior to enrollment in the Pension Plan were eligible to participate in the Pension Plan. An employee is fully vested in benefits under the Pension Plan after completing five years of service or upon termination due to death, disability or retirement after the first day of the month following the month in which the employee attains age 65. Certain employees are entitled to a supplemental benefit that vests over five years with 20% vesting on each December 31 beginning in 2010 and lasting through 2014. When an employee retires at age 65, the employee can elect to receive either a lump sum distribution or monthly benefit payments under the Pension Plan, in either case equal to (1) 23% of the employee's average monthly compensation for the five consecutive calendar years during which the employee received the highest amount of pay ("Average Compensation") plus (2) 19.5% of the employee's Average Compensation in excess of his monthly "covered compensation" for Social Security purposes, as provided in the Pension Plan. However, if an employee has completed less than 30 years of service on his termination at or after reaching age 65, the monthly benefit will be reduced by 1/30th for each year less than 30 years completed by the employee. When an employee retires at an age other than 65, the employee retirement benefit will be the actuarial equivalent of the benefit he or she would have received if he or she had retired at age 65. An employee who terminates employment after completing at least five years of service will be eligible for an early retirement benefit determined as described in the preceding sentence at any time after attaining age 60.

        The following table sets forth the estimated annual pension benefits payable upon retirement under the Global Partners LP Pension Plan formula to persons in the specified compensation and years of service classifications:

 
  Estimated Annual Pension
for Representative Years of Credited Service
 
Highest Consecutive 5-Year
Average Compensation $
  5 Years   10 Years   15 Years   20 Years   25 Years   30 Years &
Over
 
 
  $
  $
  $
  $
  $
  $
 

125,000

    6,676     13,353     20,029     26,706     33,382     40,058  

150,000

    8,447     16,894     25,342     33,789     42,236     50,683  

175,000

    10,218     20,436     30,654     40,872     51,090     61,308  

200,000

    11,989     23,978     35,967     47,956     59,945     71,933  

225,000

    13,760     27,519     41,279     55,039     68,799     82,558  

245,000 and above

    15,176     30,353     45,529     60,706     75,882     91,058  

        Benefits under the formula are based upon the employee's highest consecutive five-year average compensation and are not subject to offset for social security benefits. Compensation for such purposes means compensation including overtime, but excluding bonuses, 50% of commissions, taxable fringe benefits, relocation allowances, transportation allowances, housing allowances, cash and distribution rights pursuant to any long-term incentive plan and any cash payable in lieu of group healthcare coverage. These estimated annual pension benefits do not include supplemental benefits, if any, to which the employee may be entitled.

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GMG Pension Plan

        As a result of the Alliance Acquisition, effective as of March 1, 2012, sponsorship of Alliance Energy LLC Pension Plan was transferred to GMG, which is a part of our controlled group, and the name of the plan was changed to the Global Montello Group Corp. Pension Plan (the "GMG Pension Plan"). Effective May 15, 2012, the GMG Pension Plan was amended to freeze participation in and benefit accruals. Prior to the freeze, all employees who (1) were 21 years of age or older, (2) were not covered by a collective bargaining agreement providing for union pension benefits, (3) had been employed by GMG or a predecessor employer for one year prior to enrollment in the Pension Plan, (4) were not nonresident aliens, (5) had not become employees as a result of Code Section 410(b)(6)(C) transaction and (6) were not non-exempt gas station/c-store employees hired on or after January 1, 2007 or employees hired after September 30, 2009 were eligible to participate in the GMG Pension Plan. An employee is fully vested in benefits under the GMG Pension Plan after completing five years of service or, if earlier, upon termination due to death, disability or retirement. When an employee retires at age 65, the employee can elect to receive a monthly annuity or an equivalent lump sum payment. The employee's benefit payable at retirement is equal to (1) 23% of the employee's average monthly compensation for the five consecutive calendar years during which the employee received the highest amount of pay ("Average Compensation") plus (2) 19.5% of the employee's Average Compensation in excess of his monthly "covered compensation" for Social Security purposes, as provided in the GMG Pension Plan. When an employee retires at an age other than 65, the employee retirement benefit will be the actuarial equivalent of the benefit he or she would have received if he or she had retired at age 65. An employee who terminates employment after completing at least five years of service will be eligible for an early retirement benefit determined as described in the preceding sentence at any time after attaining age 60.

        The following table sets forth the estimated annual pension benefits payable upon retirement under the GMG Pension Plan formula to persons in the specified compensation and years of service classifications:

 
  Estimated Annual Pension
for Representative Years of Credited Service
 
Highest Consecutive 5-Year
Average Compensation $
  5 Years   10 Years   15 Years   20 Years   25 Years   30 Years &
Over
 
 
  $
  $
  $
  $
  $
  $
 

125,000

    6,676     13,353     20,029     26,706     33,382     40,058  

150,000

    8,447     16,894     25,342     33,789     42,236     50,683  

175,000

    10,218     20,436     30,654     40,872     51,090     61,308  

200,000

    11,989     23,978     35,967     47,956     59,945     71,933  

225,000

    13,760     27,519     41,279     55,039     68,799     82,558  

245,000 and above

    15,176     30,353     45,529     60,706     75,882     91,058  

        Benefits under the GMG Pension Plan formula are based upon the employee's highest consecutive five-year average compensation and are not subject to offset for social security benefits. Compensation for such purposes means compensation including overtime, but excluding bonuses, 50% of commissions, deferred compensation, employee benefits, moving expenses, transportation allowance, salary continuation and non-cash remuneration.

Supplemental Executive Retirement Agreements

        For a description of the benefits provided to Messrs. Faneuil and Rudinsky pursuant to their SERP Agreements, please see "Employment and Related Agreements—Supplemental Executive Retirement Agreements."

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Global and Alliance Deferred Compensation Agreements

        For a description of the deferred compensation arrangements provided to Mr. Faneuil pursuant to the Global Deferred Compensation Plan and the Alliance Deferred Compensation Plan, please see "Employment and Related Agreements—Deferred Compensation Agreements."

Global Partners 401(k) Savings and Profit Sharing

        The 401(k) Savings and Profit Sharing Plan (the "401(k) Plan") permits all eligible employees to make voluntary pre-tax contributions to the plan, subject to applicable tax limitations. During calendar years 2010, 2011 and 2012, our general partner was permitted to make a discretionary matching contribution to the 401(k) plan for each eligible employee. Effective January 1, 2013, our general partner amended the 401(k) Plan to remove the discretionary matching contributions and provide instead for employer matching contributions equal to 100% of elective deferrals up to the first 3% of eligible compensation plus 50% of elective deferrals up to the next 2% of eligible compensation. All employees are eligible to participate in the 401(k) Plan other than employees who (1) are not yet 21 years of age, (2) are covered by a collective bargaining agreement that does not provide for employees to be covered by the 401 (k) Plan, (3) have not been employed by our predecessor, our general partner or one of our operating subsidiaries for at least six months or (4) are nonresident aliens. Eligible employees may elect to contribute up to 100% of their compensation to the plan for each plan year. Employee contributions are subject to annual dollar limitations, which are periodically adjusted for changes in the cost of living. Participants in the plan are always fully vested in any matching contributions under the plan; however, discretionary profit sharing contributions are subject to a six year vesting schedule. The plan is intended to be tax-qualified under Section 401(a) of the Code so that contributions to the plan, and income earned on plan contributions, are not taxable to employees until withdrawn from the plan, and so that contributions, if any, will be deductible when made.

GMG 401(k) Savings and Profit Sharing

        As a result of the Alliance Acquisition, effective as of March 1, 2012, sponsorship of Alliance Energy LLC 401(k) Savings and Profit Sharing Plan was transferred to GMG, which is a part of our controlled group, and the name of the Plan was changed to the Global Montello Group Corp 401(k) Savings and Profit Sharing Plan (the "GMG 401(k) Plan"). The GMG 401(k) Plan permits all eligible employees to make voluntary pre-tax contributions to the plan, subject to applicable limitations under the Code. The GMG 401(k) Plan provides for employer matching contributions equal to 100% of elective deferrals up to the first 3% of eligible compensation plus 50% of elective deferrals up to the next 2% of eligbile compensa