EDGAR 10-K Filing

Company CIK: 1323468
Filing Year: 2024
Filename: 1323468_10-K_2024_0001558370-24-002047.json

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ITEM 1. BUSINESS
Items 1. and 2. Business and Properties.
Overview
We are a master limited partnership formed in March 2005. We own, control or have access to a large terminal network of refined petroleum products and renewable fuels-with strategic rail and/or marine assets-spanning from Maine to Florida and into the U.S. Gulf states. We are one of the largest independent owners, suppliers and operators of gasoline stations and convenience stores, primarily in Massachusetts, Maine, Connecticut, Vermont, New Hampshire, Rhode Island, New York, New Jersey and Pennsylvania (collectively, the “Northeast”) and Maryland and Virginia. As of December 31, 2023, we had a portfolio of 1,627 owned, leased and/or supplied gasoline stations, including 341 directly operated convenience stores, primarily in the Northeast, as well as 64 gasoline stations located in Texas that are operated by our unconsolidated affiliate, Spring Partners Retail LLC (“SPR”). We are also one of the largest distributors of gasoline, distillates, residual oil and renewable fuels to wholesalers, retailers and commercial customers in the New England states and New York. We engage in the purchasing, selling, gathering, blending, storing and logistics of transporting petroleum and related products, including gasoline and gasoline blendstocks (such as ethanol), distillates (such as home heating oil, diesel and kerosene), residual oil, renewable fuels, crude oil and propane and in the transportation of petroleum products and renewable fuels by rail from the mid-continent region of the United States and Canada.
We purchase refined petroleum products, gasoline blendstocks, 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. We operate our businesses under three segments: (i) Wholesale, (ii) Gasoline Distribution and Station Operations (“GDSO”) and (iii) Commercial.
Global GP LLC, our general partner, manages our operations and activities and employs our officers and substantially all of our personnel, except for most of our gasoline station and convenience store employees who are employed by our wholly owned subsidiary, Global Montello Group Corp. (“GMG”) and for substantially all of the employees who primarily or exclusively provide services to SPR, who are employed by SPR Operator LLC, a wholly owned subsidiary of ours.
2024 Events
Credit Agreement Facility Reallocation and Accordion Reduction-On February 5, 2024, we and the lenders under our credit agreement agreed, pursuant to the terms of our credit agreement, to (i) a reallocation of $300.0 million of the revolving credit facility to the working capital revolving credit facility and (ii) reduce the accordion feature from $200.0 million to $0. After giving effect to the reallocation and the accordion reduction, the working capital revolving credit facility is $950.0 million and the revolving credit facility is $600.0 million, for a total commitment of $1.55 billion, effective February 8, 2024. This reallocation and accordion reduction return our credit facilities to the terms in place prior to the reallocation and accordion exercise previously agreed to by us and the lenders on December 7, 2023. Please read Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations-Liquidity and Capital Resources-Credit Agreement.”
2032 Notes Offering-On January 18, 2024, we and GLP Finance Corp. (the “Issuers”) issued $450.0 million aggregate principal amount of 8.250% senior notes due 2032 (the “2032 Notes”) that are guaranteed by certain of our subsidiaries in a private placement exempt from the registration requirements under the Securities Act of 1933, as amended (the “Securities Act”). We used the net proceeds from the offering to repay a portion of the borrowings outstanding under our credit agreement and for general corporate purposes. Please read Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations-Liquidity and Capital Resources-Senior
Notes.”
Pending Acquisition of Terminals from Gulf Oil-On December 15, 2022, we entered into a purchase agreement with Gulf Oil Limited Partnership (“Gulf”) pursuant to which we were to acquire five refined-products terminals located in New Haven, CT, Thorofare, NJ, Portland, ME, Linden, NJ and Chelsea, MA for approximately $273.0 million in cash. On February 23, 2024, we entered into an amended and restated purchase agreement with Gulf in response to concerns raised by the Federal Trade Commission and the State Attorney General of Maine, pursuant to which (a) the refined-products terminal located in Portland, ME was removed from the transaction and (b) the purchase price was reduced to $212.3 million, subject to certain customary adjustments. We expect to finance the transaction with borrowings under our revolving credit facility. We continue to work through the process of obtaining regulatory approvals and other customary closing conditions.
2023 Events
Acquisition of Terminals from Motiva Enterprises LLC-On December 21, 2023, we acquired 25 refined product terminals and related assets from Motiva Enterprises LLC (“Motiva”) which are located along the Atlantic Coast, in the Southeast and in Texas (the “Terminal Facilities”), pursuant to an Asset Purchase Agreement dated November 8, 2023. The Terminal Facilities have an aggregate shell capacity of approximately 8.4 million barrels. The transaction is underpinned by a 25-year take-or-pay throughput agreement with Motiva that includes minimum annual revenue commitments. The purchase price was approximately $313.2 million, including inventory. We financed the transaction with borrowings under our revolving credit facility. See Note 3 of Notes to Consolidated Financial Statements.
Investment in Real Estate-On October 23, 2023, we, through our wholly owned subsidiary, Global Everett Landco, LLC, entered into a Limited Liability Agreement (the “Everett LLC Agreement”) of Everett Landco GP, LLC (“Everett”), a Delaware limited liability company formed as a joint venture with Everett Investor LLC (the “Everett Investor”), an entity controlled by an affiliate of The Davis Companies, a company primarily involved in the acquisition, development, management and sale of commercial real estate. In accordance with the Everett LLC Agreement, we agreed to invest up to $30.0 million for an initial 30% ownership interest in the joint venture. See Note 17 of Notes to Consolidated Financial Statements.
Expansion of Retail Operations into Texas-In June 2023, SPR, a joint venture between us and ExxonMobil Corporation (“ExxonMobil”), acquired a portfolio of 64 Houston-area convenience and fueling facilities from Landmark Industries, LLC and its related entities. SPR was formed for the purpose of engaging in the business of operating retail locations in Texas and such other states as may be approved by SPR’s board of directors. We hold a 49.99% ownership interest in SPR and ExxonMobil holds the remaining 50.01% ownership interest. SPR is managed by a two-person board of directors, one of whom is designated by us. The day-to-day activities of SPR are operated by SPR Operator LLC, one of our wholly owned subsidiaries. See Note 17 of Notes to Consolidated Financial Statements.
Amendments to the Credit Agreement and Accordion Exercise and Facility Reallocation-On February 2, 2023, we entered into the eighth amendment to the third amended and restated credit agreement which, among other things, permits us to request up to two reallocations per calendar year of the lending commitments among the facilities under our credit agreement. On May 2, 2023, we entered into the ninth amendment to third amended and restated credit agreement and joinder which, among other things, increased the applicable revolver rate by 25 basis points on borrowings under the revolving credit facility and extended the maturity date from May 6, 2024 to May 2, 2026. On December 7, 2023, pursuant to the terms of our credit agreement, we exercised a portion of the accordion feature and increased the aggregate working capital revolving commitments by $200.0 million for a period not to exceed 364 days. Also on December 7, 2023, pursuant to the terms of our credit agreement, we reallocated $300.0 million of the working capital revolving credit facility to the revolving credit facility. After giving effect to such reallocation, the working capital revolving credit facility was $850.0 million and the revolving credit facility was $900.0 million. Please read Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations-Liquidity and Capital Resources-Credit Agreement.”
Operating Segments
We operate our businesses under three segments: (i) Wholesale, (ii) GDSO and (iii) Commercial. In 2023, our Wholesale, GDSO and Commercial sales accounted for approximately 58%, 35% and 7% of our total sales, respectively.
Wholesale
In our Wholesale segment, we engage in the logistics of selling, gathering, blending, storing and transporting refined petroleum products, gasoline blendstocks, renewable fuels, crude oil and propane. We transport these products by railcars, barges, trucks and/or pipelines pursuant to spot or long-term contracts. We sell home heating oil, branded and unbranded gasoline and gasoline blendstocks, diesel, kerosene and residual oil to home heating oil and propane retailers and wholesale distributors. Generally, customers use their own vehicles or contract carriers to take delivery of the gasoline, distillates and propane at bulk terminals and inland storage facilities that we own or control or at which we have throughput or exchange arrangements. Ethanol is shipped primarily by rail and by barge.
Gasoline Distribution and Station Operations
In our GDSO segment, gasoline distribution includes sales of branded and unbranded gasoline to gasoline station operators and sub-jobbers. Station operations include (i) convenience store and prepared food sales, (ii) rental income from gasoline stations leased to dealers, from commissioned agents and from cobranding arrangements and (iii) sundries (such as car wash sales and lottery and ATM commissions).
As of December 31, 2023, we had a portfolio of owned, leased and/or supplied gasoline stations, primarily in the Northeast, that consisted of the following:
Company operated (1)
Commissioned agents
Lessee dealers
Contract dealers
Total
1,627
(1) Excludes 64 sites operated by our SPR joint venture (see Note 17 of Notes to Consolidated Financial Statements).
Commercial
In our Commercial segment, we include 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 and bunker fuel. In the case of public sector commercial and industrial end user customers, we sell products primarily either through a competitive bidding process or through contracts of various terms. We respond to publicly issued requests for product proposals and quotes. We generally arrange for the delivery of the product to the customer’s designated location. Our Commercial segment also includes sales of custom blended fuels delivered by barges or from a terminal dock to ships through bunkering activity.
Products
General
The following table presents our product sales and other revenues as a percentage of our consolidated sales for the years ended December 31:
Gasoline sales: gasoline and gasoline blendstocks (such as ethanol)
%
%
%
Distillates (home heating oil, diesel and kerosene), residual oil and crude oil sales
%
%
%
Convenience store and prepared food sales, rental income and sundries
%
%
%
Total
%
%
%
The above table excludes the 64 sites operated by our unconsolidated affiliate, SPR.
Gasoline. We sell substantially all grades of branded and unbranded gasoline and we sell gasoline blendstocks, such as ethanol, that comply with seasonal and geographical requirements in the areas in which we market.
Distillates. Distillates are primarily divided into home heating oil, diesel and kerosene. In 2023, sales of diesel, home heating oil and kerosene accounted for approximately 69%, 30% and 1%, respectively, of our total volume of distillates sold. 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 sell generic home heating oil and Heating Oil Plus™, our proprietary premium branded heating oil that is electronically blended at the delivery facility, to wholesale distributors and retailers. In addition, we sell the additive used to create Heating Oil Plus™ to some wholesale distributors, 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 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 2023, 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 volume was sold on either a posted price or a price based on various indices which, in both instances, reflect current market conditions.
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 sell residual oil to industrial, commercial and marine customers. We specially blend product for users in accordance with their individual power specifications and for marine transport.
Crude Oil. We engage in the purchasing, selling, storing and logistics of transporting domestic and Canadian crude oil and other products via pipeline, rail and barge from the mid-continent region of the United States and Canada for distribution to refiners and other customers.
Convenience Store Items and Sundries. We sell a broad selection of food, beverages, snacks, grocery and non-food merchandise at our convenience store locations and generate sundry sales, such as car wash sales and lottery and ATM commissions, at our convenience store locations.
Significant Customers
None of our customers accounted for greater than 10% of total sales for years ended December 31, 2023, 2022 and 2021.
Assets
Terminals
As of December 31, 2023, we owned, leased or maintained dedicated storage facilities at 49 bulk terminals throughout the United States, each with the capacity to receive petroleum products via marine vessel, pipeline and/or rail, with a collective storage capacity of approximately 18.3 million barrels. Some of our storage tankage is versatile, allowing us to switch tankage from one product to another. We also maintain commingled storage at numerous smaller inland terminals owned and operated by third parties.
Our bulk terminals located in New York, Vermont, Oregon, Georgia and Florida include rail facilities capable of handling refined and renewable products. In North Dakota, we own two bulk terminals with rail facilities permitted to receive, store or distribute crude oil. In Albany, New York, we also have an additional rail-fed storage terminal capable of handling propane.
The bulk terminals from which we distribute product are supplied by ship, barge, truck, pipeline and/or rail. The inland storage facilities, which we use primarily to store and distribute distillates, are mostly supplied with product delivered by truck from bulk terminals. Our customers receive product from our network of bulk terminals and inland storage facilities primarily via truck, pipeline and/or rail.
In connection with our businesses, we may lease or otherwise secure the right to use certain third-party assets (such as railcars and barges). As of December 31, 2023, we supported our rail activity with a fleet of approximately 50 leased general-purpose railcars. We lease railcars from a third party under a lease arrangement that expires in 2027, and we also lease barges from third parties through various time charter lease arrangements with various expiration dates.
Many of our bulk terminals operate 24 hours a day and consist of multiple storage tanks and a truck rack with an automated truck loading system. 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 from which we market are equipped with truck loading racks capable of providing automated blending and additive packages which meet our customers’ specific requirements.
We use throughput arrangements for storage of product at terminals owned by others, including terminals where we do not maintain dedicated storage. We or 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. Our throughput agreements may require us to throughput a minimum volume over an agreed-upon period and may include make-up rights if the minimum volume is not met.
We have exchange agreements with customers and suppliers. An exchange agreement is a contractual arrangement 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.
We sometimes purchase or sell products at terminals owned by us and/or owned by others under rack purchase agreements. Rack purchase agreements enable us to receive (when we are the customer) or deliver (when we are the
supplier) product at a terminal’s truck rack. Ownership of the product typically transfers when product passes through the flange connecting the terminal’s truck rack infrastructure and a hauler’s tanker truck. Rack purchase agreements have terms of varying length, with pricing often tied to an index plus a pricing differential and sometimes have minimum and maximum quantity requirements.
Gasoline Stations
As of December 31, 2023, we had a portfolio of 1,627 owned, leased and/or supplied gasoline stations, including 341 directly operated convenience stores, primarily in the Northeast, as well as 64 gasoline stations located in Texas that are operated by our unconsolidated joint venture, SPR.
At our company-operated stores, we operate the gasoline stations and convenience stores with our employees, and we set the retail price of gasoline at the station. At commissioned agent locations, we own the gasoline inventory, and we set the retail price of gasoline at the station and pay the commissioned agent a fee related to the gallons sold. We receive rental income from commissioned agent leased gasoline stations for the leasing of the convenience store premises, repair bays and/or other businesses that may be conducted by the commissioned agent. At dealer-leased locations, the dealer purchases gasoline from us, and the dealer sets the retail price of gasoline at the dealer’s station. We also receive rental income from (i) dealer-leased gasoline stations and (ii) cobranding arrangements. We also supply gasoline to locations owned and/or leased by independent contract dealers. Additionally, we have contractual relationships with distributors in certain New England states pursuant to which we source and supply these distributors’ gasoline stations with Exxon- or Mobil-branded gasoline.
Supply
Our products, including refined petroleum products, gasoline blendstocks and renewable fuels, 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 and occasionally from Asia. Most of our products are delivered by water, pipeline, rail or truck. 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 two days) to net 30 days. Please read “-Commodity Risk Management.” We obtain our convenience store inventory from traditional suppliers.
Seasonality
Due to the nature of our businesses and our reliance, in part, on consumer travel and spending patterns, we may experience more demand for gasoline during the late spring and summer months than during the fall and winter months. Travel and recreational activities are typically higher in these months in the geographic areas in which we operate, increasing the demand for gasoline. Therefore, our volumes in gasoline 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 volumes are generally higher during the first and fourth quarters of the calendar year. These factors may result in fluctuations in our quarterly operating results.
Commodity Risk Management
When we take title to the products 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, gasoline blendstocks, renewable fuels and crude oil. We endeavor to minimize commodity risk in connection with our daily operations through hedging by the use of exchange-traded futures contracts on regulated exchanges or using other over-the-counter 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, with certain adjustments based on quality and freight due to location differences and prevailing supply and demand conditions, as well as other factors. While we use these transactions to seek to maintain a position that is substantially balanced within our commodity product purchase and sales activities, we may experience net unbalanced positions for short periods of time as a result of variances in daily
purchases and sales and transportation and delivery schedules as well as other logistical issues inherent in our businesses, such as weather conditions. In connection with managing these positions, we are aided by maintaining a constant presence in the marketplace. We also engage in a controlled trading program for up to an aggregate of 250,000 barrels of commodity products at any one 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.
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. Basis risk is the inherent market price risk created when a commodity of a certain grade or location is purchased, sold or exchanged as compared to a purchase, sale or exchange of a commodity at a different time or place, including 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 exchange-traded 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, the Chicago Mercantile Exchange (“CME”) and the Intercontinental-Exchange (“ICE”), which are exchanges for the respective 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.
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.
In our Wholesale segment, we obtain Renewable Identification Numbers (“RINs”) in connection with our purchase of ethanol which is used for bulk trading purposes or for blending with gasoline through our terminal system. A RIN is a renewable identification number associated with government-mandated renewable fuel standards. To evidence that the required volume of renewable fuel is blended with gasoline, obligated parties must retire sufficient RINs to cover their Renewable Volume Obligation (“RVO”). Our U.S. Environmental Protection Agency (“EPA”) obligations relative to renewable fuel reporting are comprised of foreign gasoline and diesel that we may import and blending operations at certain facilities. As a wholesaler of transportation fuels through our terminals, we separate RINs from renewable fuel through blending with gasoline and can use those separated RINs to settle our RVO. While the annual compliance period for the RVO is a calendar year and the settlement of the RVO typically occurs by March 31 of the following year, the settlement of the RVO can occur, under certain EPA deferral actions, more than one year after the close of the compliance period. Our Wholesale segment operating results may be sensitive to the timing associated with our RIN position relative to our RVO at a point in time, and we may recognize a mark-to-market liability for a shortfall in RINs at the end of each reporting period. To the extent that we do not have a sufficient number of RINs to satisfy our RVO as of the balance sheet date, we charge cost of sales for such deficiency based on the market price of the RINs as of the balance sheet date and record a liability representing our obligation to purchase RINs.
For more information about our policies and procedures to minimize our exposure to market risk, including commodity market risk, please read Part II, Item 7A, “Quantitative and Qualitative Disclosures About Market Risk.”
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 markets, we compete in various product lines and for all customers of those various product lines. 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 supply oil to industrial, commercial and marine customers. 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 with respect to 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 gasoline stations as well as supermarket and warehouse stores that sell gasoline, and our convenience stores compete with other convenience store chains, independent convenience stores, supermarkets, drugstores, discount warehouse clubs, motor fuel stations, mass merchants, quick service restaurants and other similar retail outlets.
Employees and Human Capital
To carry out our operations, our general partner and certain of our operating subsidiaries employed a total of approximately 5,060 employees, including approximately 3,485 full-time employees as of December 31, 2023, of which approximately 100 employees were represented by labor unions under collective bargaining agreements with various expiration dates. We strive to maintain positive relations with our employees.
Our values and culture are key to our ability to attract, hire and retain skilled and talented employees for our businesses and are critical to our success. Striving to offer competitive compensation and benefit programs is a cornerstone to fostering an engaged and motivated workforce and rewarding performance.
Diversity is one of our core strengths and is key to building an inclusive and equitable workplace. We encourage all employees to exhibit integrity, quality, commitment and innovation and, in doing so, contribute to our long-standing character and reputation.
Our continued growth depends on our ability to attract and retain the best people. Our ability to lead employees through growth depends on our continued investment in the training and development of our leaders and continued focus on cultivating the leaders of tomorrow. Our approach to securing top talent is tailored to each workplace environment. In our retail locations, we have an expedited application and onboarding process, including text to apply, and a referral bonus scheme for existing employees. In our corporate offices, we continue to offer a flexible working policy for everyone and the ability to work completely remotely for approved employees.
It is essential to hear from our employees. We maintain an environment of open communications where the contributions of all employees are valued. We encourage many forms of company-wide communications, including town hall meetings. Our culture is founded upon core principles of respect, fair treatment and providing equal opportunities for our workforce.
Safeguarding the health and safety of our employees is our first and foremost priority. We are committed to providing a safe working environment for all our employees and operating in a safe and environmentally sound manner. This commitment extends to supporting the communities where we operate and continuing to foster sustainability throughout the company. We continue to focus and expand on sustainability. We added customizable biofuels systems at four of our terminals; developed an electric vehicle strategy and installed a number of charging units; and deployed per- and polyfluroroalkyl substances (“PFAS”)-free foam for fire suppression to all of our owned legacy terminals and are planning to do the same at our recently-acquired terminals in 2024. We continue to research, explore and develop other sustainable energy opportunities while supporting policy that advances clean fuel adoption.
We operate in an evolving regulatory environment and our operations are subject to numerous and varying regulatory requirements. We proactively manage compliance and work collaboratively with stakeholders, including government agencies, in this endeavor.
Title to Properties, Permits and Licenses
We believe we have all of the assets needed, including leases, permits and licenses, to operate our businesses 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 GDSO 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 businesses.
The name GLOBAL®, our Global logos and the name Global Petroleum Corp.® are our trademarks. In addition, we have trademarks for our premium fuels and additives: Heating Oil Plus™ and the Heating Oil Plus® logo, SubZero® and the SubZero® logo, Diesel One® and the Diesel One® logo, Diesel 1®, the Diesel 1™ logo, the tagline Legacy.Technology.Performance.®, GlobalGlo™ and GlobalGlo Low Carbon Solutions™. Our Global online customer portal for buying, bidding and contract management is operated under the name GlobalCONNECT™.
We also own registrations and use the following trademarks, among others, for our convenience store business: A Fresh Take on Everything®, Alltown®, Alltown Fresh & logo®, Fresh with Benefits®, Alltown Insiders®, Alltown Market®, Alltown Neighborhood Perks®, Centre St. Kitchen®, Fast Freddie’s®, Mr. Mike’s®, Deli Joe’s®, Diamond Fuels®, Xtra Mart & logo®, XtraCafe®, HF Honey Farms & logo®, Wheels & logo®. We also own the trademark Jiffy Mart & logo SM. We also have rights to use O’Connell’s Convenience PlusSM, T-BirdSM, Miller’s Mart® and related marks.
Facilities
We lease office space for our principal executive office in Waltham, Massachusetts. This lease expires on July 31, 2026 with extension options through July 31, 2036. In addition, we have leases for various small office spaces in other states for which we utilize to support our operations.
Regulation
General
Our businesses of supplying primarily refined petroleum products, gasoline blendstocks, renewable fuels and crude oil involve a number of activities that are subject to extensive and stringent environmental laws. In addition, these laws are frequently modified or revised to impose new obligations.
Our operations use a number of petroleum and other products storage and distribution facilities. These facilities include rail transloading facilities and gasoline stations that we do not own or operate, but at which refined petroleum products, gasoline blendstocks, renewable fuels and crude oil are stored. We use 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 or their operations could be compromised, requiring us to incur costs to use alternative facilities.
State, federal, and municipal laws and regulations, including, without limitation, those governing environmental matters 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 our operations to obtain, maintain and renew permits which can obligate us to incur capital expenditures to comply with environmental control requirements and which may restrict our operations;
● enjoining the operations of facilities found to be noncompliant with applicable laws and regulations;
● inability to renew, modify or obtain permits on terms and conditions that are satisfactory to maintain existing operations, to modify and/or expand existing operations and to conduct new operations; and
● limiting or restricting the products we may sell at our company-operated convenience stores.
Any such failures to comply may also trigger administrative, civil and possibly criminal enforcement measures, including monetary penalties and remedial requirements. Certain 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.
Our operating permits are subject to modification, renewal and revocation. We regularly monitor and review our operations, procedures and policies for compliance with permits, laws and regulations. Risk of noncompliance, permit interpretation, permit modification, renewal of permits on less favorable terms, judicial or administrative challenges of permits or permit revocation are inherent in the operation of our businesses, as it is with other companies engaged in similar businesses.
The trend in environmental regulation has been 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 municipal laws, including 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 or will not have a material adverse effect on our financial position, results of operations or cash available for distribution to our unitholders.
For additional information concerning certain environmental proceedings, please read Notes 15 and 25 of Notes to Consolidated Financial Statements.
Hazardous Substance Releases and Waste Handling
Our businesses are subject to laws that relate to the release of hazardous substances into the water, air or soils and require, among other things, 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 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. 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. 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. 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. 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 our operations are in substantial compliance with the existing requirements of RCRA, the Solid Waste Disposal Act and similar state and municipal laws, and the cost involved in complying with these requirements is not material. We also incur ongoing costs for monitoring groundwater and/or remediation of contamination at several facilities that we operate.
We believe we are in substantial compliance with applicable hazardous substance releases and waste handling requirements related to our operations. We do not believe that compliance with federal, state or municipal hazardous substance releases and waste handling regulations will have a material adverse effect on our financial position, results of operations or cash available for distribution to our unitholders. However, these and future statutes, regulatory changes or initiatives regarding hazardous substance releases and waste handling could directly and indirectly increase our operating and compliance costs. For example, the EPA has proposed to designate two widely used chemicals that break down slowly over time (per- and poly-fluoroalkyl substances, also known as “PFAS”) as hazardous substances under CERCLA (namely, perfluorooctanoic acid (PFOA) and perfluorooctanesulfonic acid (PFOS)). Should any PFAS contamination be detected at sites that we currently own or operate, or formerly owned or operated, we may be obligated to remediate any such materials. We cannot assure that costs incurred to comply with standards and regulations emerging from these and future rulemakings will not be material to our businesses, financial condition or results of operations.
Above Ground Storage Tanks
Above ground tanks that contain petroleum and other hazardous substances are subject to comprehensive regulation under environmental and other laws. Generally, these laws require secondary containment systems for tanks or that the operators take alternative precautions to ensure that no contamination results from tank leaks or spills and impose liability for releases from the tanks. We believe we are in substantial compliance with environmental laws and regulations applicable to above ground storage tanks.
Under the Oil Pollution Act of 1990 (“OPA”) and comparable state laws, responsible parties for a regulated facility from which products are spilled may be subject to strict, joint and several liability for removal costs and certain other consequences of any spill such as natural resource damages, where the spill is into navigable waters, groundwater or along shorelines and other resource areas, and damages to private properties.
Under the authority of the federal Clean Water Act, the EPA imposes specific requirements for Spill Prevention, Control and Countermeasure Plans and Facility Response Plans that are designed to prevent, and minimize the impacts of, releases of oil and other products from above ground storage tanks. We believe we are in substantial compliance with regulations pursuant to OPA, the Clean Water Act and similar state laws. We follow the American Petroleum Institute’s inspection, maintenance and repair standard applicable to our above ground storage tanks.
Underground Storage Tanks
We are required to make financial expenditures to comply with regulations governing underground storage tanks (“USTs”) which store gasoline or other regulated substances adopted by federal, state and municipal regulatory agencies. Pursuant to RCRA, the EPA has established a comprehensive regulatory program for the detection, prevention, investigation and cleanup of leaking USTs. State or local agencies may be 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. We believe we are in substantial compliance with applicable environmental requirements, including those applicable to our USTs. Compliance with existing and future environmental laws regulating UST systems of the kind we use may require significant capital expenditures in the future. These expenditures may include upgrades, modifications, and the replacement of USTs 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, gasoline blendstocks, renewable fuels and crude oil, into waters of the United States. This law and comparable state laws may require permits for discharging pollutants into state and federal waters, including certain underground sources, and impose substantial liabilities and remedial obligations for noncompliance. We hold these discharge permits for our facilities, as applicable. These state and federal laws are subject to uncertainty due to ongoing proposed regulatory revisions, ongoing litigation and the recent change in federal administration. This uncertainty extends to, among other regulatory provisions, the definition of waters of the United States, which continues to be the subject of regulatory redefinitions (as well as ongoing litigation). Most recently, the EPA and U.S. Army Corps of Engineers released a final revised definition of waters of the United States founded upon the pre-2015 definition and including updates incorporating existing Supreme Court decisions and regulatory guidance. However, the revised definition has already been challenged and is currently enjoined in 27 states. In May 2023, the Supreme Court released its opinion in Sackett v. EPA, which involved issues relating to the legal tests used to determine whether wetlands qualify as waters of the United States. The Sackett decision invalidated certain parts of the final revised definition and significantly narrowed its scope, resulting in a revised rule being issued in September 2023. However, due to the injunction of the revised definition, the implementation of the September 2023 rule currently varies by state. Therefore, some uncertainty remains as to how broadly the September 2023 rule and the Sackett decision will be interpreted by the agencies. Uncertainty also extends to potential changes in regulated pollutants and applicable standards and the regulation of discharges to groundwater. All of these actions could expand jurisdiction or restrict discharges due to revised standards. This regulatory uncertainty may result in a need for additional or amended permits in areas that were not formerly subject to the Clean Water Act, which may impact operations in the future and result in increased costs.
EPA regulations also may 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 periodic 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 (the “CAA”) and comparable state and local laws, permits are typically required to emit regulated air pollutants into the atmosphere above certain thresholds. 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 municipal agencies have the authority to prescribe product quality specifications for the petroleum products and renewable fuels 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, such as sulfur content for transportation fuels and home heating fuels, could require the construction of additional storage.
In addition, the CAA 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.
In December 2020, the EPA under President Trump maintained the November 2015 National Ambient Air Quality Standards (“NAAQS”) for ground-level ozone. A designation of nonattainment can lead the governing state to issue more stringent limits on existing sources of those precursor pollutants within the designated nonattainment area. However, in October 2021, the EPA announced that it would reconsider the December 2020 determination to maintain the November 2015 NAAQS with a target date of year end of 2023. A draft assessment released in April 2022 indicated EPA staff had reached a preliminary conclusion that the December 2020 decision would stand, but in August 2023, the EPA announced a new review of the NAAQS for ground-level ozone. Until a final review is released, the full extent of the impacts of any new standards are not clear. However, any revisions have the potential to change the nonattainment designations and could have a material impact on our operations and cost-structure, which would be determined on an individual permit by permit basis.
Climate Change
The threat of climate change continues to attract considerable attention in the United States and in foreign countries. In the United States, no comprehensive climate change legislation has been implemented at the federal level; however, President Biden has made action on climate change a focus of his administration, and several states have implemented their own efforts to curb greenhouse gas (“GHG”) emissions. To the extent that our operations are subject to restrictions on GHG emissions, we may face increased capital and operating costs associated with new or expanded facilities. Significant expansions of our existing facilities or construction of new facilities may be subject to the CAA’s requirements for review of pollutants regulated under the Prevention of Significant Deterioration and Title V programs. Some of our facilities and operations are also subject to the EPA’s Mandatory Reporting of Greenhouse Gases rule, and any further regulation may increase our operational costs. Some states in which we do business, including New York, have enacted measures requiring regulatory agencies to consider potential sea level rise in the performance of their regulatory duties.
The EPA has proposed or finalized New Source Performance Standards (“NSPS”) for a number of emissions categories, including methane and volatile organic compound emissions from certain activities in the oil and gas production sector. Although the Trump administration reduced certain of these requirements, President Biden issued an executive order calling for the EPA to revisit federal regulations regarding methane and, in December 2023, the EPA finalized more stringent methane rules for new, modified, and reconstructed facilities, known as OOOOb, as well as standards for existing sources for the first time ever, known as OOOOc. Under the final rules, states have two years to prepare and submit their plans to impose methane emissions controls on existing sources. The presumptive standards established under the final rule are generally the same for both new and existing sources and include enhanced leak detection survey requirements using optical gas imaging and other advanced monitoring to encourage the deployment of innovative techniques to reduce methane emissions, reduction of emissions by 95% through capture and control systems, zero-emission requirements for certain devices, and the establishment of a “super-emitter” response program that would allow third parties to make reports to the EPA of large methane emission events, triggering certain investigation and repair requirements. It is likely, however, that the final rule and its requirements will be subject to legal challenge. Moreover, compliance with the new rules may affect the amount we owe under the Inflation Reduction Act of 2022 (“IRA”), signed into law by President Biden on August 16, 2022. The IRA imposes a fee on methane from certain sources in the oil and natural gas sector. Starting in 2024, the methane emissions charge would begin at $900 per metric ton of leaked methane, rising to $1,200 in 2025 and $1,500 in 2026 and thereafter. Calculation of the fee is based on certain thresholds established in the IRA. However, compliance with the EPA’s methane rules would exempt an otherwise covered facility from the requirement to pay the fee. The imposition of the EPA’s final methane rules and, as applicable, the IRA’s fee, alongside other provisions of the IRA, could accelerate a transition away from fossil fuels, restricting production of liquid and fossil fuels which could lower fuel consumption and adversely affect our business. Moreover, failure to comply with these requirements could result in the imposition of substantial fines and penalties, as well as costly injunctive relief.
Under Subpart MM of the Mandatory Greenhouse Gas Reporting Rule (“MRR”), importers and exporters of petroleum products, including distillates and natural gas liquids, must report the GHG emissions that would result from the complete combustion of all imported and exported products if such combustion would result in the emission of at least 25,000 metric tons of carbon dioxide equivalent 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.
The EPA has also issued Corporate Average Fuel Economy (“CAFE”) standards to regulate emissions of GHGs from the use of fossil fuels for mobile sources. Generally, the CAFE standards have incremental annual increases; however, in recent years, significant regulatory changes and related litigation have cast uncertainty on the pace of state and federal efforts to further accelerate fuel economy objectives, which are tied to regulatory strategies to reduce vehicle emissions. In August 2021, the National Highway Traffic Safety Administration (“NHTSA”) proposed new CAFE standards for light duty vehicles manufactured in models years 2024 through 2026, so that standards would increase in stringency at a rate of 8% per year rather than the previous incremental change of 1.5% per year. The final rule establishing these standards was released in March 2022, implementing a rate of 8% annually for model years 2024 and 2025 and 10% for model year 2026. Additionally, in December 2021, the EPA and the NHTSA withdrew the Safer Affordable Fuel-Efficient Vehicles Rule Part I (“SAFE I Rule”), which would have preempted state authority and prevented states like California from setting their own fuel economy standards. Accordingly, various state and regional programs have been proposed which would curtail or prevent the sale of new gasoline-powered personal vehicles in their jurisdictions within identified time periods. Such programs to achieve reductions in emissions of GHGs from the operation of motor vehicles may be required, which may reduce demand for our products and services.
Overall, there has been a trend towards increased regulation of GHGs and initiatives, both domestically and internationally, to limit GHG emissions. Future efforts to limit emissions associated with transportation fuels and heating fuels could reduce the market for, or effect pricing of, our products, and thus adversely impact our businesses. For example, at the 2015 United Nations Framework Convention on Climate Change in Paris, the United States and nearly 200 other nations entered into an international climate agreement. Although this agreement does not create any binding obligations for nations to limit their GHG emissions, it does include pledges to voluntarily limit or reduce future emissions. Although the United States had withdrawn from the Paris Agreement, President Biden signed an executive order recommitting the United States to the Paris Agreement, and the country formally rejoined on February 19, 2021. In April 2021, President Biden announced a new, more rigorous nationally determined emissions reduction level of 50-52% reduction from 2005 levels in economy-wide net GHG emissions. The impacts of resultant actions and of any legislation or regulation that may be passed to implement the United States’ commitment under the Paris Agreement, are unclear at this time.
Separately, it should be noted that many scientists have concluded that increasing concentrations of GHG in the earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, droughts, and floods and other climatic events. If any of those effects were to occur, they could have an adverse effect on our assets and operations. In addition, various suits have been filed, alleging that certain companies created public nuisances by producing fuels that contributed to climate change, or alleging that such companies have been aware of the adverse impacts of climate change for some time but failed to adequately disclose such impacts to their investors or customers. Any such litigation could have an adverse effect on operations in the future.
There are increasing financial risks associated with our operations. Activists concerned about the potential effects of climate change have, in certain instances, directed their attention at sources of funding for energy companies whose businesses are related to the use of fossil fuels. In the future, financial institutions may be required to adopt policies that could have the effect of reducing funding available to the fossil fuel industry. This could make it more difficult to secure funding. For example, in October 2023, the Federal Reserve, Office of the Comptroller of the Currency and the Federal Deposit Insurance Corp. released a finalized set of principles guiding financial institutions with $100.0 billion or more in assets on the management of physical and transition risks associated with climate change. Additionally, in March 2022, the SEC released a proposed rule that would establish a framework for the reporting of climate risks, targets and metrics. We cannot predict the final form and substance of the rule or its requirements. Relatedly, California has enacted new laws requiring additional disclosure with respect to certain climate-related risks and GHG emissions reduction claims, and other states are considering similar laws. The ultimate impact of the SEC rule and new laws or regulations imposing more stringent requirements on our business related to the disclosure of climate-related risks may result in reputation harms among certain stakeholders if they disagree with our approach to mitigating climate-related risks, additional costs to comply with any such disclosure requirements and increased costs of restrictions and on access to capital.
Convenience Store Regulations
Our convenience store operations are subject to extensive governmental laws and regulations that include legal restrictions on the sale of alcohol, tobacco and lottery products, food labelling, safety and health requirements and public accessibility, as well as sanitation, environmental, 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 passed the Family Smoking Prevention and Tobacco Control Act (“FSPTCA”) which gave the Food and Drug Administration (“FDA”) broad authority to regulate tobacco and nicotine products. Under the FSPTCA, the FDA has enacted numerous regulations restricting the sale of such products 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. These governmental actions, as well as national, state and municipal campaigns to discourage smoking, tax increases, and imposition of regulations restricting the sale of flavored tobacco products, e-cigarettes and vapor products, have and could result in reduced consumption levels, higher costs which we may not be able to pass on to our customers, and reduced overall customer traffic. Also, increasing regulations related to and restricting the sale of flavored tobacco products, e-cigarettes and vapor products may offset some of the gains we have experienced from selling these types of products. These factors could materially affect the sale of this product mix which in turn could have an adverse effect on our results of operations.
Ethanol Market
The market for ethanol is dependent on several economic incentives and regulatory mandates for blending ethanol into gasoline, including the availability of 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, such as ethanol, be utilized in transportation fuels, including gasoline, in the United States each year. Additionally, the EPA imposes oxygenate blending requirements for reformulated gasoline that are best met with ethanol blending. Gasoline marketers may also choose to discretionally blend ethanol into conventional gasoline for economic reasons. A change or waiver of the RFS mandate or the reformulated gasoline oxygenate blending requirements could adversely affect the availability and pricing of ethanol. Any change in the RFS mandate could also result in reduced discretionary blending of ethanol into conventional gasoline.
In June 2023, the EPA released its final “Set” rule establishing biofuel targets for 2023, 2024 and 2025 under the RFS program, increasing the amount of the renewable volume obligation imposed on importers and producers of transportation fuels. Generally, the final volumes under the Set rule represent an aggregate downward adjustment for certain categories of renewable fuel. The changes under the Set rule are likely to result in increases in the cost of such fuels and could lower fuel consumption and thereby reduce our revenues.
Environmental Insurance
We maintain insurance which may cover, in whole or in part, certain costs relating to environmental matters associated with releases of products we store, sell and/or ship. We maintain insurance policies with insurers in amounts and with coverage and deductibles 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 businesses. Where required by federal or municipal 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”). Pursuant to the Terrorism Risk Insurance Program Reauthorization Act of 2019, TRIA has been extended through December 31, 2027. We elect to purchase terrorism coverage through a stand-alone insurance program for both liability and property. 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.
Hazardous Materials Transportation
Our operations include the preparation and shipment of some hazardous materials by truck, rail, marine vessel and/or pipeline. We are subject to regulations promulgated under the Hazardous Materials Transportation Act (and subsequent amendments) and administered by the U.S. Department of Transportation (“DOT”) under the Federal Highway Administration, the Federal Railroad Administration, the United States Coast Guard and the Pipeline and Hazardous Materials Safety Administration (“PHMSA”).
We conduct loading and unloading of primarily refined petroleum products, gasoline blendstocks, renewable fuels and crude oil to and from cargo transports, including tanker trucks, railcars, marine vessels and pipelines. In large part, the cargo transports are owned and operated by third parties. In addition, we lease a fleet of railcars and charter barges associated with the shipment of refined petroleum products, gasoline blendstocks, renewable fuels and crude oil. We conduct ongoing training programs to help ensure that our operations are in compliance with applicable regulations.
The trend in hazardous material transportation is to increase oversight and regulation of these operations. These regulations address: the testing and ensuing designations of crude oil; the safety of tank cars that are used in transporting crude oil and other flammable or petroleum type liquids by rail, including the phase out of DOT-111 tank cars that have not been retro-fitted; braking standards for certain trains; new operational protocols for trains transporting large volumes of flammable liquids, such as routing requirements, speed restrictions and the provision of information to local government agencies; and comprehensive oil spill response plans for any railroad that transports Class 3 flammable liquid petroleum oil in a single train carrying either a continuous block of 20 or more loaded tank cars or 35 or more loaded tank cars in total. In May 2020, PHMSA withdrew an Advance Notice of Proposed Rulemaking announcing potential revisions of the Hazardous Materials Regulations to establish vapor pressure limits for the transportation of crude oil and potentially all Class 3 flammable liquid hazardous materials. This or other regulations regarding the movement of hazardous liquids by rail may be pursued by the Biden Administration, although at this time, no such actions have occurred. In addition to any action taken or proposed by federal agencies, a number of states have proposed or enacted laws in recent years that encourage safer rail operations or urge the federal government to enhance requirements for these operations.
Regulations for rail transport are similar in Canada, though specific requirements may vary. Transport Canada has implemented regulations imposing speed limit restrictions on certain trains carrying hazardous materials in highly populated areas, requiring railways to give municipalities and first responders more information about the hazardous materials they carry, requiring that approved Emergency Response Assistance Plans be in place prior to transporting certain quantities of dangerous goods, and requiring railways to carry minimum levels of insurance depending on the quantity of crude oil or dangerous goods that they transport.
We believe we are in substantial compliance with applicable hazardous materials transportation requirements related to our operations. We do not believe that compliance with federal, state or municipal hazardous materials transportation regulations will have a material adverse effect on our financial position, results of operations or cash available for distribution to our unitholders. However, these and future statutes, regulatory changes or initiatives
regarding hazardous material transportation, could directly and indirectly increase our operation, compliance and transportation costs and lead to shortages in availability of tank cars. We cannot assure that costs incurred to comply with standards and regulations emerging from these and future rulemakings will not be material to our businesses, financial condition or results of operations. Furthermore, we can provide no assurance that future events, such as changes in existing laws (including changes in the interpretation of existing laws), the promulgation of new laws and regulations, including any voluntary measures by the rail industry, that result in new requirements for the design, construction or operation of tank cars used to transport crude oil or other products, or, or the development or discovery of new facts or conditions will not cause us to incur significant costs. Any such requirements would apply to the industry as a whole.
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 standard requires 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.

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ITEM 1A. RISK FACTORS
Item 1A. Risk Factors.
Summary of Risk Factors
We are subject to a variety of risks and uncertainties, including, without limitation risks related to (i) our businesses and our operations, (ii) our structure and (iii) tax matters, each of which could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders. The following summarizes certain of these risks:
● We may not have sufficient cash from operations to enable us to pay distributions on our Series A preferred units or our Series B preferred units (collectively, our “preferred units”) or maintain distributions on our common units at current levels.
● A significant decrease in price or demand for the products we sell or a significant increase in the cost of our logistics activities could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.
● Certain of our financial results are subject to seasonality.
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The condition of credit markets may adversely affect our liquidity.
● Covenants and borrowing base limitations included in our debt instruments and our debt levels may limit our flexibility in obtaining additional financing and in pursuing other business opportunities.
● Our risk management policies cannot eliminate all commodity risk, basis risk or the impact of unfavorable market conditions. In addition, any noncompliance with our risk management policies could result in significant financial losses.
● We are exposed to trade credit risk and risk associated with our trade credit support in the ordinary course of our businesses.
● Higher prices, new technology and alternative fuels, such as electric, hybrid, battery powered, hydrogen or other alternative fuel-powered motor vehicles, energy efficiency and changing consumer preferences or driving habits could reduce demand for our products.
● We depend upon marine, pipeline, rail and truck transportation services for the petroleum products we purchase and sell. Regulations and directives related to these transportation services as well as disruption in any of these transportation services could adversely affect our logistics activities.
● Changes in government usage mandates and tax credits could adversely affect the availability and pricing of ethanol and renewable fuels, which could negatively impact our sales.
● We may not be able to obtain state fund or insurance reimbursement of our environmental remediation costs.
● Our results can be adversely affected by unforeseen events, such as adverse weather, natural disasters, terrorism, cyberattacks, pandemics or other catastrophic events.
● Our businesses, including our gasoline station and convenience store business, expose us to litigation which could result in an unfavorable outcome or settlement of one or more lawsuits where insurance proceeds are insufficient or otherwise unavailable.
● Our businesses are subject to federal, state and municipal environmental and non-environmental regulations which could significantly impact our operations, increase our costs and have a material adverse effect on such businesses.
● Our assets and operations are subject to a series of risks arising from climate change.
● A disruption to our information technology systems, including cybersecurity, could significantly limit our ability to manage and operate our businesses.
● Our general partner and its affiliates have conflicts of interest and limited fiduciary duties, which could permit them to favor their own interests to the detriment of our unitholders.
● 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.
Risks Related to Our Business
We may not have sufficient cash from operations to enable us to pay distributions on our preferred units or maintain distributions on our common units 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 distributions on our preferred units and maintain distributions on our common units 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, gasoline blendstocks, renewable fuels and crude oil and convenience store items and sundries;
● demand for refined petroleum products, gasoline blendstocks, renewable fuels and crude oil in the markets we serve;
● absolute price levels, as well as the volatility of prices, of refined petroleum products, gasoline blendstocks, renewable fuels, RINs and crude oil in both the spot and futures markets;
● supply, extreme weather and logistics 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 indentures governing our senior notes, including financial covenants, borrowing base limitations and advance rates;
● distributions paid on our preferred units;
● redemptions of some or all of our preferred units;
● 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 does not depend solely on profitability.
The amount of cash we have available for distribution depends primarily on our cash flow, including borrowings, and does not depend solely on profitability. Our cash flow 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 commit substantial resources to pursuing acquisitions and expending capital for growth projects, although there is no certainty that we will successfully complete any acquisitions or growth projects or receive the economic results we anticipate from completed acquisitions or growth projects.
We are continuously engaged in discussions with potential sellers and lessors of existing (or suitable for development) terminalling, storage, logistics and/or marketing assets, including gasoline stations, convenience stores and related businesses, and also consider organic growth projects. Our growth largely depends on our ability to make accretive acquisitions and/or accretive development projects. We may be unable to execute such accretive transactions for a number of reasons, including the following: (1) we are unable to identify attractive transaction candidates or negotiate acceptable terms; (2) we are unable to obtain financing for such transactions on economically acceptable terms; or (3) we are outbid by competitors. Many of these transactions involve numerous regulatory, environmental, commercial and legal uncertainties beyond our control, which may materially alter the expected return associated with the underlying transaction. We may consummate transactions that we believe will be accretive but that ultimately may not be accretive and may even result in a decrease in cash. Any such transactions involves potential risks, including:
● performance from the acquired assets and businesses or completed growth projects that is below the forecasts we used in evaluating the transaction;
● mistaken assumptions about price, demand, market growth, volumes, revenues and costs, including synergies;
● a project that is behind schedule or in excess of budgeted costs;
● a significant increase in our indebtedness and working capital requirements;
● an inability to hire, train or retain qualified personnel to manage and operate the businesses or 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 of the acquired assets and businesses;
● customer or key employee loss from the acquired businesses;
● unforeseen difficulties operating in new and existing product areas or new and existing geographic areas; and
● diversion of our management’s and employees’ attention from other business concerns.
If any acquisitions we consummate or projects we pursue and complete do not generate the expected level of cash available for distribution to our unitholders, our ability to increase or maintain distributions on our common units may be reduced.
We may not be able to realize expected returns or other anticipated benefits associated with our joint ventures.
We are currently involved in two joint ventures. We may not always be in complete alignment with our unaffiliated joint venture counterparties due to, for example, conflicting strategic objectives, change in control, change in market conditions or applicable laws, or other events. We may disagree on governance matters with respect to the respective joint venture or the jointly-owned assets and may be outvoted by our respective joint venture counterparty. Our joint venture arrangements may also require us to expend additional resources that could otherwise be directed to other areas of our business. As a result of such challenges, the anticipated benefits associated with our joint ventures may not be achieved and could negatively impact our results of operations.
Our gasoline financial results in our GDSO segment can be lower in the first and fourth quarters of the calendar year due to seasonal fluctuations in demand.
Due to the nature of our businesses and our reliance, in part, on consumer travel and spending patterns, we may experience more demand for gasoline during the late spring and summer months than during the fall and winter months. Travel and recreational activities are typically higher in these months in the geographic areas in which we operate, increasing the demand for gasoline. Therefore, our results of operations in gasoline can be lower in the first and fourth quarters of the calendar year.
Our heating oil and residual oil financial results can be 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.
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 can decrease the total volume we sell and the gross profit realized on those sales.
A significant decrease in price or demand for the products we sell or a significant increase in the cost of our logistics activities could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.
A significant decrease in price or demand for the products we sell or a significant increase in the cost of our logistics activities could reduce our revenues and, therefore, reduce our ability to make distributions to our unitholders or increase distributions to our common unitholders. Factors that could lead to a decrease in market demand for products we sell, including refined petroleum products, gasoline blendstocks, renewable fuels and crude oil, include:
● a recession or other adverse economic conditions or an increase in the market price or of an oversupply of refined petroleum products, gasoline blendstocks, renewable fuels and crude oil or higher taxes or other governmental or regulatory actions that increase, directly or indirectly, the cost of gasoline or other refined petroleum products, gasoline blendstocks, renewable fuels and crude oil;
● a shift by consumers to more fuel-efficient or alternative fuel vehicles, including hybrids, 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 and/or electric heat pumps and utilization of propane and/or natural gas (instead of heating oil) as primary fuel sources.
Certain of our operating costs and expenses are fixed and do not vary with the volumes we store and distribute. Should we experience a reduction in our volumes stored, distributed and sold and in our logistics activities, such costs and expenses may not decrease ratably or at all. As a result, we may experience declines in our margin if volumes decrease.
Our businesses are influenced by the overall markets for refined petroleum products, gasoline blendstocks, renewable fuels, crude oil and propane 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 blending operations are influenced by prices for refined petroleum products, gasoline blendstocks, renewable fuels, crude oil and propane, price volatility and the market for such products. Prices in the overall markets 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 future 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 future prices are lower than current prices, referred to as backwardation, inventories can depreciate in value and hedging costs are more expensive. For this reason, in these backward markets, we attempt to reduce our inventories in order to minimize these effects.
Our inventory management is dependent on the use of hedging instruments which are managed based on the structure of the forward pricing curve. Daily market changes may impact periodic results due to the point-in-time valuation of these positions. Volatility in petroleum markets may impact our results. 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 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 market price from a competitor.
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 have been volatile. General political conditions, acts of war such as the conflicts in Ukraine and the Middle East, terrorism and instability in oil producing regions, particularly in the United States, Canada, Middle East, Russia, Africa and South America, could significantly impact crude oil supplies and crude oil and refined petroleum product 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 these increased costs can be passed along 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 customers’ needs, 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.
We have contractual obligations for certain transportation assets such as barges and railcars.
A decline in demand for the products we sell could result in a decrease in the utilization of our transportation assets. Certain costs associated with our contractual obligations for certain transportation assets are fixed and do not vary with volumes transported. Should we experience a reduction in our logistics activities, costs associated with our contractual obligations for related transportation assets may not decrease ratably or at all. As a result, our financial condition, results of operations and cash available for distribution to our unitholders may be negatively impacted.
The condition of credit markets may adversely affect our liquidity.
In the 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 could require us to provide collateral. In addition, we could experience a tightening of trade credit from our suppliers.
Our debt levels may limit our flexibility in obtaining additional financing and in pursuing other business opportunities.
As of December 31, 2023, adjusted to give effect to the issuance of the 2032 Notes and the use of proceeds therefrom in January 2024, our total debt, including amounts outstanding under our credit agreement and senior notes, was approximately $1.59 billion. Effective February 8, 2024, we have the ability to incur additional debt, including the capacity to borrow up to $1.55 billion under our credit agreement, 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 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 businesses, 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, 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 businesses;
● our debt level may limit our flexibility in responding to changing businesses and economic conditions; and
● our debt may increase our cost of borrowing.
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 at all, which could have a material adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.
Disruptions, volatility or otherwise distress in financial markets and overall economic conditions have in the past made and could in the future make it difficult to obtain funding. Activists concerned about the potential effects of climate change have, in certain instances, directed their attention at sources of funding for energy companies whose businesses are related to the use of fossil fuels. This could also make it more difficult to secure 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 certain types of 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.
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 businesses as currently conducted, enhance our existing businesses, 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.
Operating and financial restrictions and covenants in our credit agreement and the indentures governing our senior notes and borrowing base requirements in our credit agreement may restrict our business and financing activities.
The operating and financial restrictions and covenants in our credit agreement and the indentures governing our senior notes and any future financing agreements and borrowing base requirements in our credit agreement could restrict our ability to finance 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 businesses or undergo a fundamental change;
● make any material dispositions;
● acquire another company;
● enter into a merger, consolidation, sale-leaseback transaction, joint venture transaction or purchase of assets;
● make distributions if any potential default or event of default occurs; or
● modify borrowing base components and advance rates.
In addition, the indentures governing our senior notes 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;
● sell assets; or
● merge with other entities.
In addition, our credit agreement requires us to comply with specified financial ratios and covenants and borrowing base limitations.
Our ability to comply with the covenants and restrictions and limitations contained in our credit agreement and indentures 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 and restrictions may be impaired. If we violate any of the restrictions, covenants, ratios or tests in our credit agreement or indentures, 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.
Restrictions in our credit agreement and indentures limit our ability to pay distributions upon the occurrence of certain events.
Our credit agreement and indentures limit our ability to pay distributions upon the occurrence of certain events. For example, our credit agreement and the indentures 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 indentures 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 indentures, please read Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations-Liquidity and Capital Resources-Credit Agreement” and Note 9 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 businesses.
Our partnership agreement allows us to borrow under our credit agreement to pay distributions. Accordingly, we can make distributions on our units even though cash generated by our operations may not be sufficient to pay such distributions. For more information, please read Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations-Liquidity and Capital Resources” and Note 9 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 businesses.
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 Commodity Futures Trading Commission (“CFTC”), the SEC and other regulators to promulgate rules and regulations implementing the new legislation.
The CFTC has designated certain interest rate swaps and credit default swaps for mandatory clearing and exchange trading. To the extent we engage in such transactions or transactions that become subject to such rules in the future, we will be required to comply or take steps to qualify for an exemption to such requirements. Although we expect to qualify for the end-user exception to the mandatory clearing requirements for swaps entered to hedge our commercial risks, the application of the mandatory clearing and trade execution requirements to other market participants, such as swap dealers, may change the cost and availability of the swaps that we use for hedging. If our swaps do not qualify for the commercial end-user exception, or the cost of entering into uncleared swaps becomes prohibitive, we may be required to clear such transactions. The ultimate effect of the rules and any additional regulations on our businesses is uncertain at this time.
In addition, the Act requires that regulators establish margin rules for uncleared swaps. Banking regulators and the CFTC have adopted final rules establishing minimum margin requirements for uncleared swaps. Although we expect to qualify for the end-user exception from such margin requirements for swaps entered into to hedge our commercial
risks, the application of such requirements to other market participants, such as swap dealers, may change the cost and availability of the swaps that we use for hedging. If any of our swaps do not qualify for the commercial end-user exception, posting of initial or variation margin could impact our liquidity and reduce cash available for capital expenditures, therefore reducing our ability to execute hedges to reduce risk and protect cash flows.
The CFTC has finalized rules that place limits on positions in certain core futures and equivalent swaps contracts for, or linked to, certain physical commodities, subject to exceptions for certain bona fide hedging transactions. We currently do not expect such rules will have a material impact on us. The CFTC has also adopted a final rule regarding aggregation of positions, under which a party that controls the trading of, or owns 10% or more of the equity interests in, another party will have to aggregate the positions of the controlled or owned party with its own positions for purposes of determining compliance with position limits unless an exemption applies. The CFTC’s aggregation rules are now in effect, though CFTC staff have granted relief-until August 12, 2025 or the effective date of any codifying rulemaking-from various conditions and requirements in the final aggregation rules. With the implementation of the final aggregation rules and upon the effectiveness of the final CFTC position limits rule, our ability to execute our hedging strategies described above could be limited.
The full impact of the Act and related regulatory requirements upon our businesses will not be known until all of the related regulations are implemented. 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 and reduce our ability to monetize or restructure our existing derivative contracts. 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. Any of these consequences could have material adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.
In addition, the European Union and other non-U.S. jurisdictions are implementing regulations with respect to the derivatives market. To the extent we transact with counterparties in foreign jurisdictions, we may become subject to such regulations.
Our risk management policies cannot eliminate all commodity risk, basis risk or the impact of unfavorable market conditions, each of 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 to the amounts we can borrow to carry inventory.
Basis risk is 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, 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 prices of petroleum products, renewable fuels and other products we sell 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.
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, gasoline blendstocks, 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, gasoline blendstocks, 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, natural disaster, logistical issues associated with delivery schedules or otherwise. In the event such supply becomes scarce, 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.
Our gasoline, convenience store and prepared food sales could be significantly reduced by a reduction in demand due to higher prices and inflation in general and new technologies and alternative fuel sources, such as electric, hybrid, battery powered, hydrogen or other alternative fuel-powered motor vehicles and changing consumer preferences and driving habits.
Technological advances and alternative fuel sources, such as electric, hybrid, battery powered, hydrogen or other alternative fuel-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 number of new legal incentives and regulatory requirements, and executive initiatives, including various government subsidies including the extension of certain tax credits for renewable energy, have made these alternative forms of energy more competitive. Changing consumer preferences or driving habits could lead to new forms of fueling destinations or potentially fewer customer visits to our sites, resulting in a decrease in gasoline sales and/or sales of food, sundries and other on-site services. In addition, higher prices and inflation in general could reduce the demand for gasoline and the products and services we offer at our convenience stores and adversely impact our sales. A reduction in our 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 heating oil and residual oil.
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 several decades. We could face additional competition from alternative energy sources as a result of future government-mandated controls or regulations 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, electric heat pumps or other alternative fuels. 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, electric heat pumps or other alternative fuels. As described above, such switching or conversion could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.
Erosion of the value of major gasoline brands could adversely affect our gasoline sales and customer traffic.
As a significant number of our retail gasoline stations and convenience stores are branded utilizing major gasoline brands, they may be dependent, in part, upon the continuing favorable reputation of such brands. Erosion of the value of major gasoline brands could have a negative impact on our gasoline sales, which in turn may cause our operations to be less profitable.
We depend upon marine, pipeline, rail and truck transportation services for a substantial portion of our logistics activities in transporting the petroleum products we purchase and sell. Disruption in any of these 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 the transportation services we depend upon and could affect the flow of service. In addition, accidents, labor disputes between providers and their employees and labor renegotiations, including strikes, lockouts or a work stoppage, shortage of railcars, trucks and barges, mechanical difficulties or bottlenecks and disruptions in transportation logistics could also disrupt our business operations. These events could result in service disruptions and increased costs 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 businesses.
Changes in government usage mandates and tax credits could adversely affect the availability and pricing of ethanol and renewable fuels, which could negatively impact our sales.
The EPA has implemented a RFS pursuant to the Energy Policy Act of 2005 and the Energy Independence and Security Act of 2007. The RFS program seeks to promote the incorporation of renewable fuels in the nation’s fuel supply and, to that end, sets annual quotas for the quantity of renewable fuels (such as ethanol) that must be blended into transportation fuels consumed in the United States. A RIN is assigned to each gallon of renewable fuel produced in or imported into the United States.
We are exposed to volatility in the market price of RINs. We cannot predict the future prices of RINs. RIN prices are dependent upon a variety of factors, including EPA regulations related to the amount of RINs required and the total amounts that can be generated, the availability of RINs for purchase, the price at which RINs can be purchased, and levels of transportation fuels produced, all of which can vary significantly from quarter to quarter. For more information, please read Part I, Items 1. and 2. “Business and Properties-Regulation-Ethanol Market.” If sufficient RINs are unavailable for purchase or if we have to pay a significantly higher price for RINs, or if we are otherwise unable to meet the EPA’s RFS mandates, our results of operations and cash flows could be adversely affected.
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. In addition, changes in blending requirements or broadening the definition of what constitutes a renewable fuel could affect the price of RINs which could impact the magnitude of the mark-to-market liability recorded for the deficiency, if any, in our RIN position relative to our RVO at a point in time. Future changes proposed by EPA for the renewable volume obligations may increase the cost to consumers for transportation fuel, which could result in a decline in demand for fuels and lower revenues for our business.
We may not be able to obtain state fund or insurance reimbursement of our environmental remediation costs.
Where releases of products, including, without limitation, refined petroleum products, gasoline blendstocks, 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 for certain products may be recoverable from the reimbursement fund of the applicable state and/or from third party insurance after any deductible or self-insured retention has been met, but there are no assurances that such reimbursement funds or insurance proceeds will be available to us.
Potential exposure to products we handle at our facilities could subject us to product liability claims and complaints which could increase our litigation, operating and compliance costs and adversely affect our financial condition and results of operations.
We may be subject to complaints or litigation arising out of alleged contamination and/or exposure to chemicals or other regulated materials, such as various perfluorinated compounds, including perfluorooctanoate, perfluorooctane sulfonate, perfluorohexane sulfonate, or other per- and polyfluoroalkyl substances, benzene and/or petroleum hydrocarbons, at or from our facilities. Such complaints or litigation could have a negative impact on our businesses.
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 distribution to our unitholders.
We may incur costs or liabilities as a result of litigation or adverse publicity resulting from concerns over food quality, health or other issues that could cause customers to avoid our convenience stores.
We may be the subject of complaints or litigation arising from food-related illness or injury in general which could have a negative impact on our businesses. Additionally, negative publicity, regardless of whether the allegations are valid, concerning food quality, food safety or other health concerns, employee relations or other matters related to our food preparation operations may materially adversely affect demand for our offerings and could result in a decrease in customer traffic to our convenience stores.
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.
Governmental action and campaigns to discourage smoking and use of other products may have a material adverse effect on our financial condition, results of operations, and cash available for distribution to our unitholders.
Congress has given the FDA broad authority to regulate tobacco and nicotine products, and the FDA, states and some municipalities have enacted and are pursuing enaction of numerous regulations restricting the sale of such products. These governmental actions, as well as national, state and municipal campaigns to discourage smoking, tax increases, and imposition of regulations restricting the sale of flavored tobacco products, e-cigarettes and vapor products, have and could result in reduced consumption levels, higher costs which we may not be able to pass on to our customers, and reduced overall customer traffic. Also, increasing regulations related to and restricting the sale of flavored tobacco products, e-cigarettes and vapor products may offset some of the gains we have experienced from selling these types of products. These factors could materially affect the sale of this product mix which in turn could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.
Our financial condition, results of operations, and cash available for distribution to our unitholders may be adversely affected by global and national health concerns.
Global and national health concerns, such as the outbreak of a pandemic or contagious disease like COVID-19, may adversely affect us by reducing demand for our products. Such a health concern could result in people traveling less and avoiding public spaces, such as convenience stores and other locales where food and sundries are sold, either due to self-imposed or government-mandated restrictions to halt the spread of disease, thereby resulting in a decrease in the demand for our products, including gasoline and other refined petroleum products, and a decrease in sales of food, sundries and other on-site services. Such an event may impair our suppliers’ ability to provide the volumes and types of product and goods we sell. A disease outbreak could affect the health of our workforce or result in travel restrictions, in either case rendering employees unable to work or travel. While these factors and the impact of these factors are difficult to predict, any one or more of them could disrupt our business as we may be unable to continue business operations in a continuous manner consistent with the level and extent of business activities prior to the occurrence of an unexpected event or events, lower our revenues, increase our costs, or reduce our cash available for distribution to our unitholders.
New entrants or increased competition in the convenience store industry could result in reduced gross profits.
We compete with numerous other convenience store chains, independent convenience stores, supermarkets, drugstores, discount warehouse clubs, motor fuel service stations, mass merchants, quick service restaurants, other locales providing food services and other similar retail outlets. Several non-traditional retailers, including supermarkets and club stores, compete directly with convenience stores.
We face intense competition in our purchasing, selling, gathering, blending, terminalling, transporting and storage. Competition from other providers of refined petroleum products, gasoline blendstocks, renewable fuels and crude oil that are able to supply our customers with those products and services at a lower price and have capital resources 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, gasoline blendstocks, renewable fuels and crude oil that may be able to supply our customers with the same or comparable products and gathering, blending, 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 markets, we compete in various product lines and for all customers of those various products lines. 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. 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, gasoline blendstocks, renewable fuels 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 price competition and the availability of alternative and less expensive fuels.
We may not be able to renew or replace our leases or 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. As of December 31, 2023, we owned, operated and maintained dedicated storage facilities at 42 bulk terminals, leased the entirety of one bulk terminal that we operated exclusively for our businesses, and maintained dedicated storage at six bulk terminals at which we have terminalling agreements. These lease and terminalling agreements are subject to expiration at various times through 2028. If these lease and terminalling agreements are not renewed or we are unable to renew them at rates and on terms and conditions satisfactory us or we are otherwise unable to replace such dedicated storage as may be needed, 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 lease and/or sub-lease sites we lease with respect to the sale of gasoline and/or related activities on favorable terms and any such failure could adversely affect our financial condition, results of operations and cash available for distribution to our unitholders.
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/or may not be adequate to cover costs associated with ownership of that site. We may lease certain sites where the rent expense we pay is more than the lease payments we collect. We cannot provide any assurance that our gross margin from the sale of transportation fuels and related convenience store items at 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.
Some of our sales are generated pursuant to 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 products, gasoline blendstocks, renewable fuels and crude oil prices, counterparty’s ability to pay for or accept contracted volumes and a competitive marketplace for the services and products offered by us. If we cannot successfully renegotiate or replace our contracts or if we 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 limited 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 terminals we own or control or to which we have access. Furthermore, a substantial portion of our assets and operations are located throughout the Northeast. Due to our limited diversification in asset type and location, an adverse development in these businesses or areas, including
adverse developments due to catastrophic events or weather and corresponding decreases in demand for refined petroleum products, gasoline blendstocks, renewable fuels, crude oil and propane, 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 businesses. Our operations are subject to operational hazards and unforeseen interruptions such as natural disasters, weather (including as the result of climate change), 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 primarily store gasoline and gasoline blendstocks, renewable fuels, crude oil and propane in underground and above ground storage tanks. Our operations are also subject to significant hazards and risks inherent in storing such products. These hazards and risks include 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.
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.
Environmental laws and other industry-related regulations or environmental litigation could significantly impact our operations and/or increase our costs, which could adversely affect our results of operations and financial condition.
Our operations are subject to federal, state and municipal laws and regulations regulating, among other matters, logistics activities, product quality specifications and other environmental matters. The trend in environmental regulation has been towards more restrictions and limitations on activities that may affect the environment over time. For example, President Biden signed an executive order calling for new or more stringent emissions standards for new, modified and existing oil and gas facilities, and the EPA has finalized rules to that effect. Our businesses 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. 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.
Risks related to our environmental permits, including the risk of noncompliance, permit interpretation, permit modification, renewal of permits on less favorable terms, judicial or administrative challenges to permits by citizens groups or federal, state or municipal entities or permit revocation are inherent in the operation of our businesses as it is with other companies engaged in similar businesses. We may not be able to renew the permits necessary for our operations, or we may be forced to accept terms in future permits that limit our operations or result in additional compliance costs.
Our terminalling operations are subject to federal, state and municipal 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 delivery of primarily refined petroleum products, gasoline blendstocks, renewable fuels and crude oil are subject to stringent federal,
state and municipal 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 municipal 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, gasoline blendstocks, renewable fuels and crude oil incur additional costs or liabilities associated with regulations, including environmental regulations. These shippers could increase their charges to us or discontinue service altogether. Similarly, many of our suppliers face a trend of increasing environmental regulations, which could likewise restrict their ability to produce crude oil or fuels, or increase their costs of production, and thus impact the price of, and/or their ability to deliver, these products.
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. In recent years environmental interest groups have filed suit against companies in the energy industry related to climate change. Should such suits succeed, we could face additional compliance costs or litigation risks.
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, or renewal of required operating or other regulatory permits. New environmental regulations, such as those related to the emissions of GHGs, might adversely affect the market for our products and activities, including the storage of refined petroleum products, gasoline blendstocks, renewable fuels and crude oil, as well as our waste management practices and our control of air emissions. Enactment of laws and passage of regulations regarding GHG emissions, or other actions to limit GHG emissions may reduce demand for fossil fuels and impact our businesses. Federal, state and municipal 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.
Additionally, the construction of new terminals or the expansion of an existing terminal involves numerous regulatory, environmental, political and legal uncertainties, most of which are not in our control. Delays, litigation, local concerns and difficulty in obtaining approvals for projects requiring federal, state or municipal permits could impact our ability to build, expand and operate strategic facilities and infrastructure, which could adversely impact growth and operational efficiency. Please read Part I, Items 1. and 2. “Business and Properties-Regulation.”
Our assets and operations are subject to a series of risks arising from climate change.
The threat of climate change continues to attract considerable attention. In the United States, no comprehensive climate change legislation has been implemented at the federal level. However, President Biden has made action on climate change a priority of his administration, which includes certain potential initiatives for climate change legislation to be proposed and passed into law. For example, on August 16, 2022, President Biden signed into law the IRA which contains hundreds of billions of dollars in incentives for the development of renewable energy, clean fuels, electric vehicles and supporting infrastructure, and carbon capture and sequestration, among other provisions. Moreover, federal regulators and state and local governments have taken (or announced that they plan to take) actions that have or may
have a significant influence on our operations. For example, following the finding that GHG emissions such as carbon dioxide and methane threaten the public health and welfare, the EPA has promulgated or adopted regulations to regulate GHG emissions from certain large stationary sources, require the monitoring and reporting of GHG emissions from certain sources, implement emissions standards for certain sources in the oil and gas sector, and (together with NHTSA), implement GHG emissions limits on vehicles manufactured for operation in the United States. Separately, President Biden issued a suite of executive orders that, among other things, recommitted the United States to the Paris Agreement, called for the revision of Trump Administration changes to the CAFE standards, and called for the issuance of methane-emission standards for new, modified, and existing oil and gas facilities, including in the transmission and storage segments. Over the past three years, the EPA has proposed and finalized several federal regulations to try to fulfill these directives. In addition, it is possible federal legislation could be adopted in the future to restrict GHGs, as Congress has considered various proposals to reduce GHG emissions from time to time. Many states and regions have also adopted GHG initiatives.
Future international, federal and state initiatives to control GHG emissions could result in increased costs associated with refined petroleum products consumption, such as costs to install additional controls to reduce GHG 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 distribution to our unitholders.
Climate change continues to attract considerable public and scientific attention. This attention has also resulted in increased political risks, including climate change related pledges made by certain candidates for public office. These have included promises to curtail oil and gas operations on federal land, such as through the cessation of leasing federal land for hydrocarbon development. During his time in office, President Biden has proposed several substantial actions on climate change including, among other things, proposing the increased use of zero-emission vehicles by the federal government, the elimination of subsidies provided to the fossil fuel industry, and increased emphasis on climate-related risk across governmental agencies and economic sectors. Other actions that could be pursued include more restrictive requirements for the development of midstream infrastructure. Additionally, litigation has been filed against companies in the energy industry related to climate change. Although the litigation is varied, many such suits allege that oil and gas companies have created public nuisances by producing fuels that contribute to climate change or allege that the companies have been aware of the adverse effects of climate change for some time but failed to adequately disclose those impacts to their investors and customers. Should such suits succeed, we could face additional costs or litigation risks.
Additionally, in response to concerns related to climate change, companies in the fossil fuel sector may be exposed to increasing financial risks. Certain financial institutions, including investment advisors and certain sovereign wealth, pension, and endowment funds, may elect in the future to shift some or all of their investment into non-fossil fuel related sectors. There is also a risk that financial institutions may be required to adopt policies that have the effect of reducing the funding provided to the fossil fuel sector. For example, in October 2023, the Federal Reserve, Office of the Comptroller of the Currency and the Federal Deposit Insurance Corp. released a finalized set of principles guiding financial institutions with $100 billion or more in assets on the management of physical and transition risks associated with climate change. Actions like this could make it more difficult to secure funding.
Separately, many scientists have concluded that increasing concentrations of GHG in the earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, droughts, and floods and other climatic events. If any of those effects were to occur in areas where our facilities are located, they could have an adverse effect on our assets and operations. For further information, please read Part I, Items 1. and 2. “Business and Properties-Regulation-Climate Change.”
1Increasing attention to environmental, social and governance (“ESG”) matters may impact our business.
Increasing attention to, and social expectations on, companies to address climate change and other environmental and social impacts, investor and societal explanations regarding voluntary ESG disclosures, and increased consumer demand for alternative forms of energy may result in increased costs, reduced demand for our
products, reduced profits, increased investigations and litigation, and negative impacts on our unit price and access to capital markets. Increasing attention to climate change and environmental conservation, for example, may result in demand shifts for our products and additional governmental investigations and private litigation against us. To the extent that societal pressures or political or other factors are involved, it is possible that such liability could be imposed without regard to our causation or contribution to the asserted damage, or other mitigating factors.
Additionally, we may receive pressure from investors, lenders, or other groups to adopt more aggressive climate or other ESG-related goals, but we cannot guarantee that we will be able to implement such goals because of potential costs or technical or operational obstacles. In March 2022, the SEC released a proposed rule that would establish a framework for the reporting of climate risks, targets, and metrics. As proposed, the SEC climate rule would impose burdensome and potentially costly emissions and other data gathering and reporting requirements on our operations, including, but not limited to, those related to risks to the physical impacts of climate change (i.e., flooding, water stress, extreme temperatures) on our assets and operations. To the extent the rule imposes additional reporting obligations, we could face increased costs. Separately, the SEC has announced that it is scrutinizing existing climate-change related disclosures in public filings, increasing the potential for enforcement if the SEC were to allege an issuer’s climate disclosures are misleading, deceptive or deficient. Such agency action could also increase the potential for private litigation. Relatedly, California has enacted new laws requiring additional disclosure with respect to certain climate-related risks and GHG emissions reduction claims. Non-compliance with these new laws may result in the imposition of substantial fines or penalties. Other states are considering similar laws. Any new laws or regulations imposing more stringent requirements on our business related to the disclosure of climate-related risks may result in reputation harms among certain stakeholders if they disagree with our approach to mitigating climate-related risks, increased compliance costs resulting from the development of any disclosures, and increased costs of and restrictions on access to capital to the extent we do not meet any climate-related expectations of requirements of financial institutions.
Relatedly, organizations that provide information to investors on corporate governance and related matters have developed ratings processes for evaluating companies on their approach to ESG matters. Such ratings are used by some investors to inform their investment and voting decisions. Unfavorable ESG ratings may lead to increased negative investor sentiment toward us or our customers and to the diversion of investment or other industries which could have a negative impact on our unit price and/ or our access to and costs of capital. Additionally, institutional lenders may decide not to provide funding for fossil fuel energy companies or the corresponding infrastructure projects based on climate change related concerns, which could affect our access to capital for potential growth projects. Moreover, to the extent ESG matters negatively impact our reputation, we may not be able to compete as effectively or recruit or retain employees, which may adversely affect our operations.
Finally, public statements with respect to ESG matters, such as emissions reduction goals, other environmental targets, or other commitments addressing certain social issues, are becoming increasingly subject to heightened scrutiny from public and governmental authorities related to the risk of potential “greenwashing,” i.e., misleading information or false claims overstating potential ESG benefits. For example, in March 2021, the SEC established the Climate and ESG Task Force in the Division of Enforcement to identify and address potential ESG-related misconduct, including greenwashing. Certain non-governmental organizations and other private actors have also filed lawsuits under various securities and consumer protection laws alleging that certain ESG-statements, goals, or standards were misleading, false, or otherwise deceptive. Moreover, the Federal Trade Commission in August 2022 indicated its intent to issue revised “Green Guides” which will likely address greenwashing risks arising from ESG-related matters. As a result, we may face increased litigation risks from private parties and governmental authorities related to our ESG efforts. In addition, any alleged claims of greenwashing against us or others in our industry may lead to further negative sentiment and diversion of investments. Additionally, we could face increasing costs as we attempt to comply with and navigate further regulatory focus and scrutiny.
Our businesses involve the buying, selling, gathering, blending and shipping of refined petroleum products, gasoline blendstocks, renewable fuels and crude oil by various modes of transportation, which involves risks of derailment, accidents and liabilities associated with cleanup and damages, as well as potential regulatory changes that may adversely impact our businesses, financial condition or results of operations.
Our operations involve the buying and selling, gathering and blending of refined petroleum products, gasoline blendstocks, renewable fuels and crude oil and shipping it to various markets including on railcars that we lease. The derailments of trains transporting such products in North America have caused various regulatory agencies and industry organizations, as well as federal, state and municipal governments, to focus attention on transportation by rail of flammable materials. Additional measures have been taken in both the United States and Canada to regulate the transportation of these products. Please read Part I, Items 1. and 2. “Business and Properties-Regulation-Hazardous Materials Transportation.”
Any changes to the existing laws and regulations, or promulgation of new laws and regulations, including any voluntary measures by the rail industry, that result in new requirements for the design, construction or operation of tank cars, including those used to transport crude oil or other products, may require us to make expenditures to comply with new standards that are material to our operations, and, to the extent that new regulations require design changes or other modifications of tank cars, we may incur significant constraints on transportation capacity during the period while tank cars are being retrofitted or newly constructed to comply with the new regulations. We cannot assure that the totality of costs incurred to comply with any new standards and regulations and any impacts on our operations will not be material to our businesses, financial condition or results of operations. In addition, any derailment of railcars or other events related to products that we have purchased or are shipping may result in claims being brought against us that may involve significant liabilities. Although we believe that we are adequately insured against such events, we cannot assure you that our policies will cover the entirety of any damages that may arise from such an event.
We are subject to federal, state and municipal laws and regulations that govern the product quality specifications of the refined petroleum products, gasoline blendstocks, renewable fuels, crude oil and propane we purchase, store, transport and sell.
Various federal, state and municipal government agencies have the authority to prescribe specific product quality specifications to the sale of commodities that we purchase, store, transport and sell. 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 adversely impact related 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 also result in substantial penalties.
We are subject to federal, state and municipal environmental regulations which could have a material adverse effect on our retail operations business and results of operations.
Our retail operations are subject to extensive federal, state and municipal 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 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.
We are subject to federal, state and municipal 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 legal restrictions on the sale of alcohol, tobacco and lottery products, food labelling, food preparation, 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.
Regulations related to wages also affect our businesses. Any increase in the statutory minimum wage would result in an increase in our labor costs and such cost increase could adversely affect our businesses, financial condition 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. In addition to the threat of terrorist attacks, we face various other security threats, including cybersecurity threats to gain unauthorized access to sensitive information or systems or to render data or systems unusable; threats to the safety of our employees; threats to the security of our facilities, such as terminals and pipelines, and infrastructure or third-party facilities and infrastructure.
Although we utilize various procedures and controls to monitor these threats and mitigate our exposure to security threats, there can be no assurance that these procedures and controls will be sufficient in preventing such threats from materializing. If any of these events were to materialize, they could lead to losses of sensitive information, critical infrastructure, personnel or capabilities, essential to our operations and could have a material adverse effect on our reputation, financial position, results of operations, or cash flows. Cybersecurity attacks in particular continue to evolve and include malicious software, attempts to gain unauthorized access to, or otherwise disrupt, pipeline control systems, attempts to gain unauthorized access to data, and other electronic security breaches that could lead to disruptions in critical systems, including pipeline control systems, unauthorized release of confidential or otherwise protected information and corruption of data. These events could damage our reputation and lead to financial losses from remedial actions, loss of business or potential liability.
We incur 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, gasoline blendstocks, renewable fuels, crude oil and propane. 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 purchase 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.
Cybersecurity breaches and other disruptions could compromise our information and operations, and expose us to liability, which would cause our business and reputation to suffer.
In the ordinary course of our business, in our data centers and on our networks, we collect and store sensitive data including, without limitation, our proprietary business information and that of our customers, suppliers and business partners, information with respect to potential ventures and transactions, and personally identifiable information of our employees, customers and business partners. The secure storage, processing, maintenance and transmission of this
information is critical to our operations and business strategy. Despite our security measures and those of our vendors and suppliers, our information technology and infrastructure may be vulnerable to ransomware, malware or other cyberattacks by hackers, employee error or malfeasance, natural disasters, power loss, telecommunication failures or other disruptions, or as a result of similar disruptions experienced by our business partners, suppliers and/or vendors. While there have been incidents of security breaches and unauthorized access to our information technologies, we have not experienced any material impact to our operations or business as a result of these attacks; however, other similar incidents could have a significant negative impact on our systems and operations. Any such cyberattack or breach or other disruption could compromise our networks and the information stored there could be accessed, publicly disclosed, lost or stolen. Any such access, disclosure or other loss of information or loss of access to information could result in legal claims or proceedings, liability under laws that protect the privacy of personal information, regulatory penalties, disruption of our operations, damage to our reputation, and loss of confidence in our ability to supply our products and services or maintain the security of information we collect and store, which could adversely affect our business. In addition, as technologies evolve, cyberattacks become increasingly sophisticated, and the regulatory framework for data privacy and security worldwide continues to evolve and develop, we may incur significant costs to modify, upgrade or enhance our security measures and we may face difficulties in fully anticipating or implementing adequate security measures or new or revised mandated processes or in generally mitigating potential harm. Further, any actual or perceived failure to comply with any new or existing laws, regulations and other obligations could result in fines, penalties or other liability.
We are subject to various federal and state laws related to cybersecurity, privacy and data protection which can impact our operations and increase our costs.
We are subject to various federal and state laws related to cybersecurity, privacy and data protection, including privacy laws in Virginia and Connecticut which took effect during 2023. We monitor pending and proposed legislation and regulatory initiatives to ascertain their relevance to and potential impact on our business and develop strategies to address them, including any required change to our privacy and cybersecurity compliance program and policies. We see a trend toward privacy laws increasing in complexity and number, and we anticipate that our obligations will expand commensurately. Further, any actual or perceived failure to comply with any new or existing laws, regulations and other obligations could result in fines, penalties or other liability.
We depend on key personnel for the success of our businesses.
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 one of our affiliates pursuant to a services agreement. Please read Part III, Item 13, “Certain Relationships and Related Transactions, and Director Independence-Services Agreement.”
We depend on unionized labor for the operation of certain of our terminals. Any work stoppages or labor disturbances at these terminals could disrupt our businesses.
Any work stoppages or labor disturbances by our unionized labor force at facilities with an organized workforce 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, including cybersecurity, to manage numerous aspects of our businesses, and a disruption of these systems could adversely affect our businesses.
We depend on our information technology (“IT”) systems to manage numerous aspects of our businesses and to provide analytical information to management. Our IT systems are an essential component of our businesses and growth
strategies, and a serious disruption to our IT systems could significantly limit our ability to manage and operate our businesses 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, cyber and other security breaches and computer viruses. While we believe we have adequate systems and controls in place, we are continuously working to install new, and upgrade existing, information technology systems and provide employee awareness around phishing, malware and other cyber risks in an effort to ensure that we are protected against cyber risks and security breaches. 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 or disruption. Any failure or interruption in our IT systems could have a negative impact on our operating results, cause our businesses and competitive position to suffer and damage our reputation.
In the normal course of our businesses, we may obtain personal data, including credit card information. While we believe we have adequate cyber and other security controls over individually identifiable customer, employee and vendor data provided to us, a breakdown or a breach in our systems that results in the unauthorized release of individually identifiable customer or other sensitive data could nonetheless occur and have a material adverse effect on our reputation, operating results and financial condition.
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 could harm our businesses and could adversely influence the trading price of our 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 could have a negative effect on the trading price of our units.
Risks Related to our Structure
Our general partner and its affiliates have conflicts of interest and limited fiduciary duties, which could permit them to favor their own interests to the detriment of our unitholders.
As of February 22, 2024, affiliates of our general partner, including directors and executive officers and their affiliates, owned 19.1% 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. Please read “-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, common unitholders consent to some actions and conflicts of interest that might otherwise constitute a breach of fiduciary or other duties under applicable state law. Additionally, our partnership agreement provides that we, and the officers and directors of our general partner, do not owe any duties, including fiduciary duties, or have any liabilities to holders of our preferred units.
● 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.
● 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 such 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 Part III, Item 13, “Certain Relationships and Related Transactions, and Director Independence-Noncompetition.”
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. Our partnership agreement provides that we, and the officers and directors
of our general partner, do not owe any duties, including fiduciary duties, or have any liabilities to holders of our preferred units. Additionally, 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 unit, a unitholder will become bound by the provisions of the partnership agreement, including the provisions described above.
Unitholders have limited voting rights and are not entitled to elect our general partner or its directors or remove our general partner without the consent of the holders of at least 66 2/3% of the outstanding common units (including common units held by our general partner and its affiliates), which could lower the trading price of our units.
Unlike the holders of common stock in a corporation, unitholders have only limited voting rights on matters affecting our businesses and, therefore, limited ability to influence management’s decisions regarding our businesses. 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. The vote of the holders of at least 66 2/3% of all outstanding common units (including common units held by our general partner and its affiliates) is required to remove our general partner.
Although the holders of our preferred units are entitled to limited protective voting rights with respect to certain matters, our preferred units generally vote separately as a class along with any other series of parity securities that we may issue upon which like voting rights have been conferred and are exercisable. As a result, the voting rights of holders of our preferred units may be significantly diluted, and the holders of such other series of parity securities that we may issue may be able to control or significantly influence the outcome of any vote.
As a result of these limitations, the prices at which our common units and our preferred units trade could diminish because of the absence or reduction of a takeover premium in the trading price.
We may issue additional units without unitholder approval, which would dilute unitholders’ ownership interests.
Except in the case of the issuance of units that rank equal to or senior to our preferred units, we may issue an unlimited number of limited partner interests of any type without the approval of our unitholders. We are allowed to
issue additional preferred units and parity securities without any vote of the holders of our preferred units, except where the cumulative distributions on our preferred units or any parity securities are in arrears.
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 units may decline.
We are prohibited from paying distributions on our common units if distributions on our preferred units are in arrears.
The holders of our preferred units are entitled to certain rights that are senior to the rights of holders of our common units, such as rights to distributions and rights upon liquidation of the Partnership. If we do not pay the required distributions on our preferred units, we will be unable to pay distributions on our common units. Additionally, because distributions to our preferred units are cumulative, we will have to pay all unpaid accumulated preferred distributions before we can pay any distributions to our common unitholders. Also, because distributions to our common unitholders are not cumulative, if we do not pay distributions on our common units with respect to any quarter, our common unitholders will not be entitled to receive distributions covering any prior periods if we later commence paying distributions on our common units. The preferences and privileges of our preferred units could adversely affect the market price for our common units, or could make it more difficult for us to sell our common units in the future.
Our preferred units are subordinated to our existing and future debt obligations and could be diluted by the issuance of additional units, including additional preferred units, and by other transactions.
Our preferred units are subordinated to all of our existing and future indebtedness. The payment of principal and interest on our debt reduces cash available for distribution to our limited partners, including the holders of our preferred units. The issuance of additional units on parity with or senior to our preferred units (including additional preferred units) would dilute the interests of the holders of our preferred units, and any issuance of equal or senior ranking securities or additional indebtedness could affect our ability to pay distributions on, redeem or pay the liquidation preference on our preferred units.
We cannot assure that we will be able to pay distributions on our preferred units regularly, and the agreements governing our indebtedness and redemptions of some or all of our preferred units may limit the cash available to make distributions on our preferred units.
Pursuant to our partnership agreement, we distribute all of our “available cash” each quarter to our limited partners. Our partnership agreement defines “Available Cash” to generally mean, for each fiscal quarter, all cash and cash equivalents on hand on the date of determination of available cash with respect to such quarter, less the amount of any cash reserves established by our general partner to:
● provide for the proper conduct of our businesses;
● comply with applicable law or the terms of any of our debt instruments or other agreements; or
● provide funds for distributions to holders of our common units and preferred units for any one or more of the next four quarters.
As a result, we do not expect to accumulate significant amounts of cash. Depending on the timing and amount of our cash distributions, these distributions could significantly reduce the cash available to us in subsequent periods to make distributions on our preferred units.
Further, our existing debt agreements and redemptions of some or all of our preferred units also may limit our ability to pay distributions on our preferred units.
Change of control conversion rights may make it more difficult for a party to acquire us or discourage a party from acquiring us.
The change of control conversion feature of our preferred units may have the effect of discouraging a third party from making an acquisition proposal for us or of delaying, deferring or preventing certain of our change of control transactions under circumstances that otherwise could provide the holders of our common units and preferred units with the opportunity to realize a premium over the then-current market price of such equity securities or that unitholders may otherwise believe is in their best interests.
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.
A substantial number of our securities may be sold in the future either pursuant to Rule 144 under 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.
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.
An increase in interest rates may cause the market price of our 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.
One of the factors that influences the price of our preferred units is the distribution yield on our preferred units (as a percentage of the price of our preferred units) relative to market interest rates. An increase in market interest rates, which are currently at low levels relative to historical rates, may lead prospective purchasers of our preferred units to expect a higher distribution yield, and higher interest rates would likely increase our borrowing costs and potentially decrease funds available for distribution to our limited partners, including the holders of our preferred units. Accordingly, higher market interest rates could cause the market price of our preferred units to decrease.
In addition, as of August 15, 2023, our Series A preferred units have a floating distribution rate set each quarterly distribution period at a percentage of the $25.00 liquidation preference equal to (i) an annual floating rate of a substitute or successor base rate that the calculation agent determines to be the most comparable to the three-month LIBOR (ii) plus a spread of 6.774% per annum. For the successor base rate comparable to the three-month LIBOR, the calculation agent has selected the industry-accepted substitute which is the 3-month CME Term SOFR plus the applicable tenor spread of 0.26161%.
The per annum distribution rate that is determined on the relevant determination date will apply to the entire quarterly distribution period following such determination date even if LIBOR (or an alternative rate, as applicable) increases during that period. As a result, the holders of our Series A preferred units will be subject to risks associated with fluctuation in interest rates and the possibility that holders will receive distributions that are lower than expected. We have no control over a number of factors, including economic, financial and political events, that impact market fluctuations in interest rates, which have in the past and may in the future experience volatility.
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 any class of our 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 Part III, 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.
Unitholders may not have limited liability if a court finds that unitholder action constitutes control of our businesses.
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 businesses.
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. Richard Slifka and his affiliates (other than us) are subject to noncompetition provisions in the omnibus agreement and business opportunity agreement. In addition, Mr. Eric Slifka’s employment agreement contains noncompetition provisions. These agreements do not prohibit Messrs. Richard Slifka and 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 Part III, Item 13, “Certain Relationships and Related Transactions, and Director Independence-Noncompetition.”
Tax Risks
Our tax treatment depends on our status as a partnership for U.S. federal income tax purposes and not being subject to a material amount of entity-level taxation. If the Internal Revenue Service, or IRS, were to treat us as a corporation for U.S. federal income tax purposes, or we become subject to entity level taxation for state tax purposes, our cash available for distribution to our unitholders would be substantially reduced.
The anticipated after-tax economic benefit of an investment in our common units depends largely on our being treated as a partnership for U.S. federal income tax purposes.
Despite the fact that we are organized as a limited partnership under Delaware law, we would be treated as a corporation for U.S. federal income tax purposes unless we satisfy a “qualifying income” requirement. Based upon our current operations and current Treasury Regulations, we believe we satisfy the qualifying income requirement. However, no ruling has been or will be requested regarding our treatment as a partnership for U.S. federal income tax purposes. Failing to meet the qualifying income requirement 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 income tax on our taxable income at the corporate tax rate. Distributions to our unitholders would generally be taxed again as corporate distributions, and no income, gains, losses or deductions would flow through to our unitholders. Because a tax
would be imposed upon us as a corporation, our cash available for distribution to our unitholders would be substantially reduced. Therefore, treatment of us as a corporation would result in a material reduction in the anticipated cash flow and after-tax return to our unitholders, likely causing a substantial reduction in the value of our common 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 taxation as a corporation or otherwise subjects us to additional amounts of entity level taxation for U.S. federal, state, municipal or foreign income tax purposes, the minimum quarterly distribution amount and the target distribution amounts may be adjusted to reflect the impact of that law or interpretation on us. At the state level, several states have been evaluating ways to subject partnerships to entity-level taxation through the imposition of state income, franchise or other forms of taxation. We currently own assets and conduct business in several states that impose a margin or franchise tax. In the future, we may expand our operations. Imposition of a similar tax on us in other jurisdictions that we may expand to could substantially reduce our cash available for distribution to our unitholders.
The tax treatment of publicly traded partnerships or an investment in our units could be subject to potential legislative, judicial or administrative changes or differing interpretations thereof, possibly applied on a retroactive basis.
The present U.S. federal income tax treatment of publicly traded partnerships, including us, or an investment in our units, may be modified by administrative, legislative or judicial changes or differing interpretations thereof at any time. From time to time, members of Congress have proposed and considered substantive changes to the existing U.S. federal income tax laws that would affect publicly traded partnerships, including proposals that would eliminate our ability to qualify for partnership tax treatment. Recent proposals have provided for the expansion of the qualifying income exception for publicly traded partnerships in certain circumstances and other proposals have provided for the total elimination of the qualifying income exception upon which we rely for our partnership tax treatment. Further, while unitholders of publicly traded partnerships are, subject to certain limitations, entitled to a deduction equal to 20% of their allocable share of a publicly traded partnership’s “qualified business income,” this deduction is scheduled to expire with respect to taxable years beginning after December 31, 2025.
In addition, the Treasury Department has issued, and in the future may issue, regulations interpreting those laws that affect publicly traded partnerships. There can be no assurance that there will not be further changes to U.S. federal income tax laws or the Treasury Department’s interpretation of the qualifying income rules in a manner that could impact our ability to qualify as a partnership in the future.
Any modification to the U.S. federal income tax laws or interpretations thereof may be applied retroactively and could make it more difficult or impossible for us to meet the exception for certain publicly traded partnerships to be treated as partnerships for U.S. federal income tax purposes. We are unable to predict whether any changes or other proposals will ultimately be enacted. In addition, there can be no assurance that there will not be any legislative, judicial or administrative changes in tax law generally that would negatively impact the value of an investment in our units. You are urged to consult with your own tax advisor with respect to the status of legislative, regulatory or administrative developments and proposals in tax law generally and their potential effect on your investment in our units.
We have subsidiaries that are treated as corporations for U.S. federal income tax purposes and subject to corporate-level income taxes.
As of December 31, 2023, we conducted substantially all of our operations of our end-user business through six subsidiaries that are treated as corporations for U.S. federal income tax purposes. These corporations primarily engage in the retail sale of gasoline and/or operate convenience stores and collect rents on personal property leased to dealers and commissioned agents at other stations. We may elect to conduct additional operations through these corporate subsidiaries in the future. These corporate subsidiaries are subject to corporate-level taxes, which reduce the cash available for distribution to us and, in turn, to our unitholders. If the IRS were to successfully assert that these corporations have more tax liability than we anticipate or legislation were enacted that increased the corporate tax rate, our cash available for distribution to our unitholders would be further reduced.
If the IRS were to contest the U.S. federal income tax positions we take, it may adversely impact the market for our
units, and the costs of any such contest would reduce our cash available for distribution to our unitholders.
We have not requested a ruling from the IRS with respect to our treatment as a partnership for U.S. federal income tax purposes. The IRS may adopt positions that differ from the 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 some or all of the positions we take. Any contest with the IRS may materially and adversely impact the market for our units and the price at which they trade. Moreover, the costs of any contest between us and the IRS will result in a reduction in our cash available for distribution to our unitholders and thus will be borne indirectly by our unitholders.
If the IRS makes audit adjustments to our income tax returns, it (and some states) may assess and collect any taxes (including any applicable penalties and interest) resulting from such audit adjustments directly from us, in which case our cash available for distribution to our unitholders might be substantially reduced and our current and former unitholders may be required to indemnify us for any taxes (including any applicable penalties and interest) resulting from such audit adjustments that were paid on such unitholders’ behalf.
Pursuant to the Bipartisan Budget Act of 2015, if the IRS makes an audit adjustment to our income tax return, it (and some states) may assess and collect any taxes (including any applicable penalties and interest) resulting from such audit adjustment directly from us. To the extent possible under these rules, our general partner may elect to either pay the taxes (including any applicable penalties and interest) directly to the IRS or, if we are eligible, issue a revised information statement to each unitholder and former unitholder with respect to an audited and adjusted return. Although our general partner may elect to have our unitholders and former unitholders take such audit adjustment into account and pay any resulting taxes (including applicable penalties or interest) in accordance with their interests in us during the tax year under audit, there can be no assurance that such election will be practical, permissible or effective in all circumstances. As a result, our current unitholders may bear some or all of the tax liability resulting from such audit adjustment, even if such unitholders did not own units in us during the tax year under audit. If, as a result of any such audit adjustment, we are required to make payments of taxes, penalties and interest, our cash available for distribution to our unitholders might be substantially reduced and our current and former unitholders may be required to indemnify us for any taxes (including any applicable penalties and interest) resulting from such audit adjustments that were paid on such unitholders’ behalf. These rules are not applicable for tax years beginning on or prior to December 31, 2017.
Even if our common unitholders do not receive any cash distributions from us, they will be required to pay taxes on their share of our taxable income.
Because common unitholders are treated as partners to whom we allocate taxable income, which could be different in amount than the cash we distribute, common unitholders are required to pay any U.S. 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. For example, if we sell assets and use the proceeds to repay existing debt or fund capital expenditures, you may be allocated taxable income and gain resulting from the sale and our cash available for distribution would not increase. Similarly, taking advantage of opportunities to reduce our existing debt, such as debt exchanges, debt repurchases, or modifications of our existing debt could result in “cancellation of indebtedness income” being allocated to our common unitholders as taxable income without any increase in our cash available for distribution. Our common unitholders may not receive cash distributions from us equal to their share of our taxable income or even equal to the tax liability that results from that income.
Tax gain or loss on the disposition of our common units could be more or less than expected.
If a unitholder sells common units, the unitholder will recognize a gain or loss equal to the difference between the amount realized and that unitholder’s tax basis in those common units. Because distributions in excess of a common unitholder’s allocable share of our net taxable income decrease such unitholder’s tax basis in its common units, the amount, if any, of such prior excess distributions with respect to the common units a unitholder sells will, in effect, become taxable income to a unitholder if it sells such units at a price greater than its tax basis in those units, even if the price such unitholder receives is less than its original cost. In addition, because the amount realized includes a unitholder’s share of our nonrecourse liabilities, if a unitholder sells its common units, the unitholder may incur a tax liability in excess of the amount of cash received from the sale.
A substantial portion of the amount realized from a unitholder’s sale of our common units, whether or not representing gain, may be taxed as ordinary income to such unitholder due to potential recapture items, including depreciation recapture. Thus, a common unitholder may recognize both ordinary income and capital loss from the sale of units if the amount realized on a sale of such units is less than such unitholder’s adjusted basis in the common units. Net capital loss may only offset capital gains and, in the case of individuals, up to $3,000 of ordinary income per year. In the taxable period in which a unitholder sells its common units, such unitholder may recognize ordinary income from our allocations of income and gain to such unitholder prior to the sale and from recapture items that generally cannot be offset by any capital loss recognized upon the sale of units.
Common unitholders may be subject to limitation on their ability to deduct interest expense incurred by us.
In general, we are entitled to a deduction for interest paid or accrued on indebtedness properly allocable to our trade or business during our taxable year. However, our deduction for “business interest” is limited to the sum of our business interest income and 30% of our “adjusted taxable income.” For the purposes of this limitation, our adjusted taxable income is computed without regard to any business interest expense or business interest income.
If our “business interest” is subject to limitation under these rules, our unitholders will be limited in their ability to deduct their share of any interest expense that has been allocated to them. As a result, common unitholders may be subject to limitation on their ability to deduct interest expense incurred by us which could negatively impact the value of an investment in our common units. You are urged to consult with your own tax advisor with respect to this potential limitation on the deductibility of interest expense and its impact on your investment in our common units.
Tax-exempt entities face unique tax issues from owning our common units that may result in adverse tax consequences to them.
Investment in our common units by tax-exempt entities, such as employee benefit plans and individual retirement accounts (known as IRAs) raises issues unique to them. For example, virtually all of our income allocated to organizations that are exempt from U.S. federal income tax, including IRAs and other retirement plans, will be unrelated business taxable income and will be taxable to them. Additionally, all or part of any gain recognized by such tax-exempt organization upon a sale or other disposition of our units may be unrelated business taxable income and may be taxable to them. Tax-exempt entities should consult a tax advisor before investing in our common units.
Non-U.S. Unitholders will be subject to U.S. taxes and withholding with respect to their income and gain from owning our units.
Non-U.S. unitholders are generally taxed and subject to income tax filing requirements by the United States on income effectively connected with a U.S. trade or business. Income allocated to our common unitholders and any gain from the sale of our units will generally be considered to be “effectively connected” with a U.S. trade or business. As a result, distributions to a non-U.S. common unitholder will be subject to withholding at the highest applicable effective tax rate and a non-U.S. unitholder who sells or otherwise disposes of a unit will also be subject to U.S. federal income tax on the gain realized from the sale or disposition of that unit. In addition to the withholding tax imposed on distributions of effectively connected income, distributions to a non-U.S. unitholder will also be subject to a 10% withholding tax on the amount of any distribution in excess of our cumulative net income. As we do not compute our cumulative net income for such purposes due to the complexity of the calculation and lack of clarity in how it would apply to us, we intend to treat all of our distributions as being in excess of our cumulative net income for such purposes and subject to such 10% withholding tax. Accordingly, distributions to a non-U.S. unitholder will be subject to a combined withholding tax rate equal to the sum of the highest applicable effective tax rate and 10%.
Moreover, the transferee of an interest in a partnership that is engaged in a U.S. trade or business is generally required to withhold 10% of the “amount realized” by the transferor unless the transferor certifies that it is not a foreign person. While the determination of a partner’s “amount realized” generally includes any decrease of a partner’s share of the partnership’s liabilities, the Treasury regulations provide that the “amount realized” on a transfer of an interest in a publicly traded partnership, such as our units, will generally be the amount of gross proceeds paid to the broker effecting the applicable transfer on behalf of the transferor, and thus will be determined without regard to any decrease in that
partner’s share of a publicly traded partnership’s liabilities. For a transfer of interests in a publicly traded partnership that is effected through a broker, the obligation to withhold is imposed on the transferor’s broker. Current and prospective non-U.S. unitholders should consult their tax advisors regarding the impact of these rules on an investment in our units.
We treat each purchaser of our common units as having the same tax benefits without regard to the common units actually purchased. The IRS may challenge this treatment, which could adversely affect the value of our common units.
Because we cannot match transferors and transferees of common units, we have adopted certain methods for allocating depreciation and amortization deductions that may not conform to all aspects of existing Treasury Regulations. A successful IRS challenge to the use of these methods could adversely affect the amount of tax benefits available to our unitholders. It also could affect the timing of these tax benefits or the amount of gain from any sale of common units and could have a negative impact on the value of our common units or result in audit adjustments to a unitholder’s tax returns.
We generally prorate our items of income, gain, loss and deduction between transferors and transferees of our common units each month based upon the ownership of our common units on the first day of each month, instead of on the basis of the date a particular common 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 generally prorate our items of income, gain, loss and deduction between transferors and transferees of our common units each month based upon the ownership of our common units on the first day of each month (the “Allocation Date”), instead of on the basis of the date a particular common unit is transferred. Similarly, we generally allocate (i) certain deductions for depreciation of capital additions, (ii) gain or loss realized on a sale or other disposition of our assets, and (iii) in the discretion of the general partner, any other extraordinary item of income, gain, loss or deduction based upon ownership on the Allocation Date. Treasury Regulations allow a similar monthly simplifying convention, but such regulations do not specifically authorize all aspects of our proration method. If the IRS were to challenge our proration method, we may be required to change the allocation of items of income, gain, loss and deduction among our unitholders.
A unitholder whose units are the subject of a securities loan (e.g., a loan to a “short seller” to cover a short sale of units) may be considered to have disposed of those units. If so, such 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 there are no specific rules governing the U.S. federal income tax consequences of loaning a partnership interest, a unitholder whose units are the subject of a securities loan may be considered to have disposed of the loaned units. In that case, the unitholder 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, 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 securities loan are urged to consult a tax advisor to determine whether it is advisable to modify any applicable brokerage account agreements to prohibit their brokers from borrowing their units.
We have adopted certain valuation methodologies in determining a unitholder’s allocations of income, gain, loss and deduction. The IRS may challenge these methodologies or the resulting allocations, which could adversely affect the value of our common units.
In determining the items of income, gain, loss and deduction allocable to our unitholders, we must routinely determine the fair market value of our assets. Although we may, from time to time, consult with professional appraisers regarding valuation matters, we make many fair market value estimates using a methodology based on the market value of our common units as a means to measure the fair market value of our assets. The IRS may challenge these valuation
methods and the resulting allocations of income, gain, loss and deduction.
A successful IRS challenge to these methods or allocations could adversely affect the timing or amount of taxable income or loss being allocated to our unitholders. It also could affect the amount of gain recognized from the sale of our common units, have a negative impact on the value of our common units or result in audit adjustments to our unitholders’ tax returns without the benefit of additional deductions.
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 units.
In addition to U.S. federal income taxes, our unitholders may be subject to other taxes, including foreign, state and local 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. Our unitholders will likely be required to file foreign, state and local income tax returns and pay state and local income taxes in some or all of these various jurisdictions. Further, our unitholders may be subject to penalties for failure to comply with those requirements.
We currently own assets and conduct business in several states, some of which impose a personal income tax on individuals, corporations and other entities. As we make acquisitions or expand our businesses, we may own assets or conduct business in additional states that impose a personal income tax. It is our unitholders’ responsibility to file all U.S. federal, state, municipal and non-U.S. tax returns and pay any taxes due in these jurisdictions. Unitholders should consult with their own tax advisors regarding the filing of such tax returns, the payment of such taxes, and the deductibility of any taxes paid.
The treatment of income attributable to distributions on our preferred units as guaranteed payments for the use of capital creates a different tax treatment for the holders of our preferred units than the holders of our common units and such distributions are not eligible for the 20% deduction for qualified business income.
The tax treatment of distributions on our preferred units is uncertain. We will treat each of the holders of our preferred units as partners for tax purposes and will treat income attributable to distributions on our preferred units as a guaranteed payment for the use of capital that will generally be taxable to each of the holders of our preferred units as ordinary income. Holders of our preferred units will recognize taxable income from the accrual of such income (even in the absence of a contemporaneous cash distribution). Otherwise, except in the case of our liquidation, the holders of our preferred units are generally not anticipated to share in our items of income, gain, loss or deduction, nor will we allocate any share of our nonrecourse liabilities to the holders of our preferred units. If distributions on our preferred units were treated as payments on indebtedness for tax purposes, rather than as guaranteed payments for the use of capital, the distributions likely would be treated as payments of interest by us to each of the holders of our preferred units.
Although we expect that much of the income we earn is generally eligible for the 20% deduction for qualified business income for taxable years beginning before December 31, 2025, the Treasury Regulations provide that income attributable to a guaranteed payment for the use of capital is not eligible for the 20% deduction for qualified publicly traded partnership income. As a result, income attributable to a guaranteed payment for use of capital recognized by holders of our preferred units is not eligible for the 20% deduction for qualified business income.
A holder of our preferred units will be required to recognize gain or loss on a sale of preferred units equal to the difference between the amount realized by such holder and such holder’s tax basis in the preferred units sold. The amount realized generally will equal the sum of the cash and the fair market value of other property such holder receives in exchange for such preferred units. Subject to general rules requiring a blended basis among multiple partnership interests, the tax basis of a preferred unit will generally equal the sum of the cash and the fair market value of other property paid by the holder of such preferred unit to acquire such preferred unit. Gain or loss recognized by a holder of preferred units on the sale or exchange of a preferred unit held for more than one year generally will be taxable as long-term capital gain or loss. Because holders of our preferred units will generally not be allocated a share of our items of depreciation, depletion or amortization, it is not anticipated that such holders will be required to recharacterize any
portion of their gain as ordinary income as a result of the recapture rules.
Investment in our preferred units by tax-exempt investors, such as employee benefit plans and individual retirement accounts, and non-United States persons raises issues unique to them. The treatment of guaranteed payments for the use of capital to tax-exempt investors is not certain and the income resulting from such payments may be treated as unrelated business taxable income for U.S. federal income tax purposes. Distributions to non-United States holders of our preferred units will be subject to withholding taxes. If the amount of withholding exceeds the amount of U.S. federal income tax actually due, non-United States holders of our preferred units may be required to file U.S. federal income tax returns in order to seek a refund of such excess.
All holders of our preferred units are urged to consult a tax advisor with respect to the consequences of owning our preferred units.

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ITEM 1B. UNRESOLVED STAFF COMMENTS
Item 1B. Unresolved Staff Comments.
None.

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ITEM 2. PROPERTIES

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ITEM 3. LEGAL PROCEEDINGS
Item 3. Legal Proceedings.
The information required by this item is included in Note 25 of Notes to Consolidated Financial Statements and is incorporated herein by reference.

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ITEM 4. MINE SAFETY DISCLOSURE
Item 4. Mine Safety Disclosures
Not applicable.
PART II

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ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities.
Market Information and Holders
Our common units trade on the New York Stock Exchange (“NYSE”) under the symbol “GLP.” At the close of business on February 22, 2024, based upon information received from our transfer agent, we had 32 holders of record of our common units. The number of record holders does not include common units held in street name.
Distributions of Available Cash
Common Units and General Partner Interest
We intend to make cash distributions to common 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. The indentures governing our outstanding senior notes and our partnership agreement also limit our ability to make distributions to our common unitholders in certain circumstances.
Within 45 days after the end of each quarter, we will distribute all of our Available Cash (as defined in our partnership agreement) to common 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 businesses, to comply with applicable law, any of our debt instruments or other agreements, or to provide funds for distributions to unitholders and 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: 99.33% to the common unitholders, pro rata, and 0.67% 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 common unitholders and the general partner based on the percentages as provided below.
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
Total Quarterly Distribution
Interest in Distributions
Target Amount
Unitholders
General Partner
First Target Distribution
up to $0.4625
99.33
%
0.67
%
Second Target Distribution
above $0.4625 up to $0.5375
86.33
%
13.67
%
Third Target Distribution
above $0.5375 up to $0.6625
76.33
%
23.67
%
Thereafter
above $0.6625
51.33
%
48.67
%
Series A Preferred Units
On August 7, 2018, we issued 2,760,000 Series A Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units representing limited partner interests (the “Series A Preferred Units”) at a price of $25.00 per Series A Preferred Unit.
Distributions on the Series A Preferred Units are cumulative from August 7, 2018, the original issue date of the Series A Preferred Units, and payable quarterly in arrears on February 15, May 15, August 15 and November 15 of each
year (each, a “Series A Distribution Payment Date”), commencing on November 15, 2018, to holders of record as of the opening of business on the February 1, May 1, August 1 or November 1 next preceding the Series A Distribution Payment Date, in each case, when, as, and if declared by the General Partner out of legally available funds for such purpose. Distributions on the Series A Preferred Units will be paid out of Available Cash with respect to the quarter immediately preceding the applicable Series A Distribution Payment Date.
No distribution may be declared or paid or set apart for payment on any junior securities (other than a distribution payable solely in junior securities) unless full cumulative distributions have been or contemporaneously are being paid or provided for on all outstanding Series A Preferred Units and any parity securities through the most recent respective distribution periods.
The initial distribution rate for the Series A Preferred Units from and including the original issue date, but excluding, August 15, 2023 was 9.75% per annum of the $25.00 liquidation preference per unit. On and after August 15, 2023, distributions on the Series A Preferred Units accumulate for each distribution period at a percentage of the $25.00 liquidation preference equal to (i) an annual floating rate of a substitute or successor base rate that a calculation agent determines to be the most comparable to the three-month LIBOR plus (ii) a spread of 6.774% per annum. For the successor base rate comparable to the three-month LIBOR, a calculation agent selected the industry-accepted substitute which is the 3-month CME Term SOFR plus the applicable tenor spread of 0.26161% per annum.
We may redeem, at our option and at any time, in whole or in part, the Series A Preferred Units at a redemption price in cash of $25.00 per Series A Preferred Unit plus an amount equal to all accumulated and unpaid distributions thereon to, but excluding, the date of redemption, whether or not declared. We must provide not less than 30 days’ and not more than 60 days’ advance written notice of any such redemption.
Series B Preferred Units
On March 24, 2021, we issued 3,000,000 9.50% Series B Fixed Rate Cumulative Redeemable Perpetual Preferred Units representing limited partner interests in us (the “Series B Preferred Units”) at a price of $25.00 per Series B Preferred Unit.
Distributions on the Series B Preferred Units are cumulative from March 24, 2021, the original issue date of the Series B Original Issue Date and payable quarterly in arrears on February 15, May 15, August 15 and November 15 of each year (each, a “Series B Distribution Payment Date”), commencing on May 15, 2021, to holders of record as of the opening of business on the February 1, May 1, August 1 or November 1 next preceding the Series B Distribution Payment Date, in each case, when, as, and if declared by the General Partner out of legally available funds for such purpose. Distributions on the Series B Preferred Units will be paid out of Available Cash with respect to the quarter immediately preceding the applicable Series B Distribution Payment Date.
No distribution may be declared or paid or set apart for payment on any junior securities (other than a distribution payable solely in junior securities) unless full cumulative distributions have been or contemporaneously are being paid or provided for on all outstanding Series B Preferred Units and any parity securities through the most recent respective distribution periods.
The distribution rate for the Series B Preferred Units is 9.50% per annum of the $25.00 liquidation preference per Series B Preferred Unit (equal to $2.375 per Series B Preferred Unit per annum).
At any time on or after May 15, 2026, we may redeem, in whole or in part, the Series B Preferred Units at a redemption price in cash of $25.00 per Series B Preferred Unit plus an amount equal to all accumulated and unpaid distributions thereon to, but excluding, the date of redemption, whether or not declared. We must provide not less than 30 days’ and not more than 60 days’ advance written notice of any such redemption.
Equity Compensation Plan
The equity compensation plan information required by Item 201(d) of Regulation S-K in response to this item is incorporated by reference from Part III, Item 12, “Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters-Equity Compensation Plan Table.”
Recent Sales of Unregistered Securities
None.
Issuer Purchases of Equity Securities
Maximum Number (or
Total Number of
Approximate Dollar
Units Purchased as
Value) of Units That May
Total Number
Average
Part of Publicly
Yet Be Purchased
Of Units
Price Paid
Announced Plans or
Under the Plans or
Period
Purchased
Per Unit($)
Programs (1)
Programs (1)
October 1-October 31, 2023
-
-
-
-
November 1-November 30, 2023
75,000
33.90
-
224,187
December 1-December 31, 2023
8,000
37.78
-
216,187
(1) In May 2009, the board of directors of our general partner authorized the repurchase of our common units for the purpose of meeting our general partner’s anticipated obligations to deliver common units under the Long-Term Incentive Plan (“LTIP”) and meeting the general partner’s obligations under existing employment agreements and other employment related obligations of the general partner. Since the repurchase program was implemented and through December 31, 2023, our general partner repurchased 1,221,240 common units pursuant to this repurchase program. As of February 28, 2024, our general partner is authorized to acquire up to 216,187 of our common units in the aggregate over an extended period of time, consistent with the general partner’s obligations under the LTIP and employment agreements. Common units may be repurchased from time to time in open market transactions, including block purchases, or in privately negotiated transactions. Such authorized unit repurchases may be modified, suspended or terminated at any time, and are subject to price, economic and market conditions, applicable legal requirements and available liquidity.

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ITEM 6. SELECTED FINANCIAL DATA
Item 6. [Reserved]

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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
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.
This section generally discusses 2023 and 2022 items and year-to-year comparisons between 2023 and 2022. Discussions of 2021 items and year-to-year comparisons between 2022 and 2021 that are not included in this Form 10-K can be found in Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our Annual Report on Form 10-K for the year ended December 31, 2022.
We account for our investment in Spring Partners Retail LLC (“SPR”) as an equity method investment. Under this method with regard to SPR, our share of income and losses is included in the income from equity method investments in the accompanying consolidated statement of operations of Global Partners LP, and our investment balance in the joint venture is included in equity method investments in the accompanying consolidated balance sheet of Global Partners LP. See Note 17 of Notes to Consolidated Financial Statements. Except as otherwise specifically indicated, the information and discussion and analysis in this section does not otherwise take into account the financial condition and results of operations of SPR.
Overview
We are a master limited partnership formed in March 2005. We own, control or have access to a large terminal network of refined petroleum products and renewable fuels-with strategic rail and/or marine assets-spanning from Maine to Florida and into the U.S. Gulf states. We are one of the largest independent owners, suppliers and operators of gasoline stations and convenience stores, primarily in Massachusetts, Maine, Connecticut, Vermont, New Hampshire, Rhode Island, New York, New Jersey and Pennsylvania (collectively, the “Northeast”) and Maryland and Virginia. As of December 31, 2023, we had a portfolio of 1,627 owned, leased and/or supplied gasoline stations, including 341 directly operated convenience stores, primarily in the Northeast, as well as 64 gasoline stations located in Texas that are operated by our unconsolidated affiliate, SPR. We are also one of the largest distributors of gasoline, distillates, residual oil and renewable fuels to wholesalers, retailers and commercial customers in the New England states and New York. We engage in the purchasing, selling, gathering, blending, storing and logistics of transporting petroleum and related products, including gasoline and gasoline blendstocks (such as ethanol), distillates (such as home heating oil, diesel and kerosene), residual oil, renewable fuels, crude oil and propane and in the transportation of petroleum products and renewable fuels by rail from the mid-continent region of the United States and Canada.
Collectively, we sold approximately $15.9 billion of refined petroleum products, gasoline blendstocks, renewable fuels and crude oil for the year ended December 31, 2023. In addition, we had other revenues of approximately $0.6 billion for the year ended December 31, 2023 from convenience store and prepared food sales at our directly operated stores, rental income from dealer leased and commissioned agent leased gasoline stations and from cobranding arrangements, and sundries.
We base our pricing on spot prices, fixed prices or indexed prices and routinely use the New York Mercantile Exchange (“NYMEX”), Chicago Mercantile Exchange (“CME”) and Intercontinental Exchange (“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.
2024 Events
Credit Agreement Facility Reallocation and Accordion Reduction-On February 5, 2024, we and the lenders under our credit agreement agreed, pursuant to the terms of our credit agreement, to (i) a reallocation of $300.0 million of the revolving credit facility to the working capital revolving credit facility and (ii) reduce the accordion feature from $200.0 million to $0. After giving effect to the reallocation and the accordion reduction, the working capital revolving credit facility is $950.0 million and the revolving credit facility is $600.0 million, for a total commitment of
$1.55 billion, effective February 8, 2024. This reallocation and accordion reduction return our credit facilities to the terms in place prior to the reallocation and accordion exercise previously agreed to by us and the lenders on December 7, 2023. Please read “-Liquidity and Capital Resources-Credit Agreement.”
2032 Notes Offering-On January 18, 2024, we and GLP Finance Corp. (the “Issuers”) issued $450.0 million aggregate principal amount of 8.250% senior notes due 2032 (the “2032 Notes”) that are guaranteed by certain of our subsidiaries in a private placement exempt from the registration requirements under the Securities Act of 1933, as amended (the “Securities Act”). We used the net proceeds from the offering to repay a portion of the borrowings outstanding under our credit agreement and for general corporate purposes. Please read “-Liquidity and Capital Resources-Senior Notes.”
Pending Acquisition of Terminals from Gulf Oil-On December 15, 2022, we entered into a purchase agreement with Gulf Oil Limited Partnership (“Gulf”) pursuant to which we were to acquire five refined-products terminals located in New Haven, CT, Thorofare, NJ, Portland, ME, Linden, NJ and Chelsea, MA for approximately $273.0 million in cash. On February 23, 2024, we entered into an amended and restated purchase agreement with Gulf in response to concerns raised by the Federal Trade Commission and the State Attorney General of Maine, pursuant to which (a) the refined-products terminal located in Portland, ME was removed from the transaction and (b) the purchase price was reduced to $212.3 million, subject to certain customary adjustments. We expect to finance the transaction with borrowings under our revolving credit facility. We continue to work through the process of obtaining regulatory approvals and other customary closing conditions.
2023 Events
Acquisition of Terminals from Motiva Enterprises LLC-On December 21, 2023, we acquired 25 refined product terminals and related assets from Motiva Enterprises LLC (“Motiva”) which are located along the Atlantic Coast, in the Southeast and in Texas (the “Terminal Facilities”), pursuant to an Asset Purchase Agreement dated November 8, 2023. The Terminal Facilities have an aggregate shell capacity of approximately 8.4 million barrels. The transaction is underpinned by a 25-year take-or-pay throughput agreement with Motiva that includes minimum annual revenue commitments. The purchase price was approximately $313.2 million, including inventory. We financed the transaction with borrowings under our revolving credit facility. See Note 3 of Notes to Consolidated Financial Statements.
Investment in Real Estate-On October 23, 2023, we, through our wholly owned subsidiary, Global Everett Landco, LLC, entered into a Limited Liability Agreement (the “Everett LLC Agreement”) of Everett Landco GP, LLC (“Everett”), a Delaware limited liability company formed as a joint venture with Everett Investor LLC (the “Everett Investor”), an entity controlled by an affiliate of The Davis Companies, a company primarily involved in the acquisition, development, management and sale of commercial real estate. In accordance with the Everett LLC Agreement, we agreed to invest up to $30.0 million for an initial 30% ownership interest in the joint venture. See Note 17 of Notes to Consolidated Financial Statements.
Expansion of Retail Operations into Texas-In June 2023, SPR, a joint venture between us and ExxonMobil Corporation (“ExxonMobil”), acquired a portfolio of 64 Houston-area convenience and fueling facilities from Landmark Industries, LLC and its related entities. SPR was formed for the purpose of engaging in the business of operating retail locations in Texas and such other states as may be approved by SPR’s board of directors. We hold a 49.99% ownership interest in SPR and ExxonMobil holds the remaining 50.01% ownership interest. SPR is managed by a two-person board of directors, one of whom is designated by us. The day-to-day activities of SPR are operated by SPR Operator LLC, one of our wholly owned subsidiaries. See Note 17 of Notes to Consolidated Financial Statements.
Amendments to the Credit Agreement and Accordion Exercise and Facility Reallocation-On February 2, 2023, we entered into the eighth amendment to the third amended and restated credit agreement which, among other things, permits us to request up to two reallocations per calendar year of the lending commitments among the facilities under our credit agreement. On May 2, 2023, we entered into the ninth amendment to third amended and restated credit agreement and joinder which, among other things, increased the applicable revolver rate by 25 basis points on borrowings under the revolving credit facility and extended the maturity date from May 6, 2024 to May 2, 2026. On
December 7, 2023, pursuant to the terms of our credit agreement, we exercised a portion of the accordion feature and increased the aggregate working capital revolving commitments by $200.0 million for a period not to exceed 364 days. Also on December 7, 2023, pursuant to the terms of our credit agreement, we reallocated $300.0 million of the working capital revolving credit facility to the revolving credit facility. After giving effect to such reallocation, the working capital revolving credit facility was $850.0 million and the revolving credit facility was $900.0 million. Please read “-Liquidity and Capital Resources-Credit Agreement.”
Operating Segments
We purchase refined petroleum products, gasoline blendstocks, 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. We operate our businesses under three segments: (i) Wholesale, (ii) Gasoline Distribution and Station Operations (“GDSO”) and (iii) Commercial.
Wholesale
In our Wholesale segment, we engage in the logistics of selling, gathering, blending, storing and transporting refined petroleum products, gasoline blendstocks, renewable fuels, crude oil and propane. We transport these products by railcars, barges, trucks and/or pipelines pursuant to spot or long-term contracts. We sell home heating oil, branded and unbranded gasoline and gasoline blendstocks, diesel, kerosene and residual oil to home heating oil and propane retailers and wholesale distributors. Generally, customers use their own vehicles or contract carriers to take delivery of the gasoline, distillates and propane at bulk terminals and inland storage facilities that we own or control or at which we have throughput or exchange arrangements. Ethanol is shipped primarily by rail and by barge.
Gasoline Distribution and Station Operations
In our GDSO segment, gasoline distribution includes sales of branded and unbranded gasoline to gasoline station operators and sub-jobbers. Station operations include (i) convenience store and prepared food sales, (ii) rental income from gasoline stations leased to dealers, from commissioned agents and from cobranding arrangements and (iii) sundries (such as car wash sales and lottery and ATM commissions).
As of December 31, 2023, we had a portfolio of owned, leased and/or supplied gasoline stations, primarily in the Northeast, that consisted of the following:
Company operated (1)
Commissioned agents
Lessee dealers
Contract dealers
Total
1,627
(1) Excludes 64 sites operated by our joint venture, SPR (see Note 17 of Notes to Consolidated Financial Statements).
At our company-operated stores, we operate the gasoline stations and convenience stores with our employees, and we set the retail price of gasoline at the station. At commissioned agent locations, we own the gasoline inventory, and we set the retail price of gasoline at the station and pay the commissioned agent a fee related to the gallons sold. We receive rental income from commissioned agent leased gasoline stations for the leasing of the convenience store premises, repair bays and/or other businesses that may be conducted by the commissioned agent. At dealer-leased locations, the dealer purchases gasoline from us, and the dealer sets the retail price of gasoline at the dealer’s station. We also receive rental income from (i) dealer-leased gasoline stations and (ii) cobranding arrangements. We also supply gasoline to locations owned and/or leased by independent contract dealers. Additionally, we have contractual relationships with distributors in certain New England states pursuant to which we source and supply these distributors’ gasoline stations with Exxon- or Mobil-branded gasoline.
Commercial
In our Commercial segment, we include 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 and bunker fuel. In the case of public sector commercial and industrial end user customers, we sell products primarily either through a competitive bidding process or through contracts of various terms. We respond to publicly issued requests for product proposals and quotes. We generally arrange for the delivery of the product to the customer’s designated location. Our Commercial segment also includes sales of custom blended fuels delivered by barges or from a terminal dock to ships through bunkering activity.
Seasonality
Due to the nature of our businesses and our reliance, in part, on consumer travel and spending patterns, we may experience more demand for gasoline during the late spring and summer months than during the fall and winter months. Travel and recreational activities are typically higher in these months in the geographic areas in which we operate, increasing the demand for gasoline. Therefore, our volumes in gasoline 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 volumes are generally higher during the first and fourth quarters of the calendar year. These factors may result in fluctuations in our quarterly operating results.
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 businesses are influenced by the overall markets for refined petroleum products, gasoline blendstocks, renewable fuels, crude oil and propane 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 blending operations are influenced by prices for refined petroleum products, gasoline blendstocks, renewable fuels, crude oil and propane, price volatility and the market for such products. Prices in the overall markets 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 future 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 future prices are lower than current prices, referred to as backwardation, inventories can depreciate in value and hedging costs are more expensive. For this reason, in these backward markets, we attempt to reduce our inventories in order to minimize these effects. Our inventory management is dependent on the use of hedging instruments which are managed based on the structure of the forward pricing curve. Daily market changes may impact periodic results due to the point-in-time valuation of these positions. Volatility in petroleum markets may impact our results. 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 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 market price from a competitor.
● We commit substantial resources to pursuing acquisitions and expending capital for growth projects, although there is no certainty that we will successfully complete any acquisitions or growth projects or receive the economic results we anticipate from completed acquisitions or growth projects. We are continuously engaged in discussions with potential sellers and lessors of existing (or suitable for development) terminalling, storage, logistics and/or marketing assets, including gasoline stations, convenience stores and related businesses, and also consider organic growth projects. Our growth largely depends on our ability to make accretive acquisitions and/or accretive development projects. We may be unable to execute such accretive transactions for a number of reasons, including the following: (1) we are unable to identify attractive transaction candidates or negotiate acceptable terms; (2) we are unable to obtain financing for such transactions on economically acceptable terms; or (3) we are outbid by competitors. Many of these transactions involve numerous regulatory, environmental, commercial and legal uncertainties beyond our control, which may materially alter the expected return associated with the underlying transaction. We may consummate transactions that we believe will be accretive but that ultimately may not be accretive.
● We may not be able to realize expected returns or other anticipated benefits associated with our joint ventures. We are currently involved in two joint ventures. We may not always be in complete alignment with our unaffiliated joint venture counterparties due to, for example, conflicting strategic objectives, change in control, change in market conditions or applicable laws, or other events. We may disagree on governance matters with respect to the respective joint venture or the jointly-owned assets and may be outvoted by our respective joint venture counterparty. Our joint venture arrangements may also require us to expend additional resources that could otherwise be directed to other areas of our business. As a result of such challenges, the anticipated benefits associated with our joint ventures may not be achieved and could negatively impact our results of operations.
● The condition of credit markets may adversely affect our liquidity. In the 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 could require us to provide collateral. In addition, we could experience a tightening of trade credit from our suppliers.
● We depend upon marine, pipeline, rail and truck transportation services for a substantial portion of our logistics activities in transporting the petroleum products we purchase and sell. Disruption in any of these 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 the transportation services we depend upon and could affect the flow of service. In addition, accidents, labor disputes between providers and their employees and labor renegotiations, including strikes, lockouts or a work stoppage, shortage of railcars, trucks and barges, mechanical difficulties or bottlenecks and disruptions in transportation logistics could also disrupt our business operations. These events could result in service disruptions and increased costs 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 businesses.
● We have contractual obligations for certain transportation assets such as barges and railcars. A decline in demand for the products we sell could result in a decrease in the utilization of our transportation assets. Certain costs associated with our contractual obligations for certain transportation assets are fixed and do not vary with volumes transported. Should we experience a reduction in our logistics activities, costs associated with our contractual obligations for related transportation assets may not decrease ratably or at
all. As a result, our financial condition, results of operations and cash available for distribution to our unitholders may be negatively impacted.
● Our gasoline financial results in our GDSO segment can be lower in the first and fourth quarters of the calendar year due to seasonal fluctuations in demand. Due to the nature of our businesses and our reliance, in part, on consumer travel and spending patterns, we may experience more demand for gasoline during the late spring and summer months than during the fall and winter months. Travel and recreational activities are typically higher in these months in the geographic areas in which we operate, increasing the demand for gasoline. Therefore, our results of operations in gasoline can be lower in the first and fourth quarters of the calendar year.
● Our heating oil and residual oil financial results can be 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.
● 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 can decrease the total volume we sell and the gross profit realized on those sales.
● Our gasoline, convenience store and prepared food sales could be significantly reduced by a reduction in demand due to higher prices and inflation in general and new technologies and alternative fuel sources, such as electric, hybrid, battery powered, hydrogen or other alternative fuel-powered motor vehicles and changing consumer preferences and driving habits. Technological advances and alternative fuel sources, such as electric, hybrid, battery powered, hydrogen or other alternative fuel-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 number of new legal incentives and regulatory requirements, and executive initiatives, including various government subsidies including the extension of certain tax credits for renewable energy, have made these alternative forms of energy more competitive. Changing consumer preferences or driving habits could lead to new forms of fueling destinations or potentially fewer customer visits to our sites, resulting in a decrease in gasoline sales and/or sales of food, sundries and other on-site services. In addition, higher prices and inflation in general could reduce the demand for gasoline and the products and services we offer at our convenience stores and adversely impact our sales. A reduction in our 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 heating oil and residual oil. 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 several decades. We could face additional competition from alternative energy sources as a result of future government-mandated controls or regulations 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, electric heat pumps or other alternative fuels. 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, electric heat pumps or other alternative fuels. As described above, such switching or conversion 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 and renewable fuels, which could negatively impact our sales. The EPA has implemented a
RFS pursuant to the Energy Policy Act of 2005 and the Energy Independence and Security Act of 2007. The RFS program seeks to promote the incorporation of renewable fuels in the nation’s fuel supply and, to that end, sets annual quotas for the quantity of renewable fuels (such as ethanol) that must be blended into transportation fuels consumed in the United States. A RIN is assigned to each gallon of renewable fuel produced in or imported into the United States. We are exposed to volatility in the market price of RINs. We cannot predict the future prices of RINs. RIN prices are dependent upon a variety of factors, including EPA regulations related to the amount of RINs required and the total amounts that can be generated, the availability of RINs for purchase, the price at which RINs can be purchased, and levels of transportation fuels produced, all of which can vary significantly from quarter to quarter. If sufficient RINs are unavailable for purchase or if we have to pay a significantly higher price for RINs, or if we are otherwise unable to meet the EPA’s RFS mandates, our results of operations and cash flows could be adversely affected. 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. In addition, changes in blending requirements or broadening the definition of what constitutes a renewable fuel could affect the price of RINs which could impact the magnitude of the mark-to-market liability recorded for the deficiency, if any, in our RIN position relative to our RVO at a point in time. Future changes proposed by EPA for the renewable volume obligations may increase the cost to consumers for transportation fuel, which could result in a decline in demand for fuels and lower revenues for our business.
● Governmental action and campaigns to discourage smoking and use of other products may have a material adverse effect on our financial condition, results of operations, and cash available for distribution to our unitholders. Congress has given the FDA broad authority to regulate tobacco and nicotine products, and the FDA, states and some municipalities have enacted and are pursuing enaction of numerous regulations restricting the sale of such products. These governmental actions, as well as national, state and municipal campaigns to discourage smoking, tax increases, and imposition of regulations restricting the sale of flavored tobacco products, e-cigarettes and vapor products, have and could result in reduced consumption levels, higher costs which we may not be able to pass on to our customers, and reduced overall customer traffic. Also, increasing regulations related to and restricting the sale of flavored tobacco products, e-cigarettes and vapor products may offset some of the gains we have experienced from selling these types of products. These factors could materially affect the sale of this product mix which in turn could have an adverse effect on our financial condition, results of operations and cash available for distribution to our unitholders.
● Environmental laws and other industry-related regulations or environmental litigation could significantly impact our operations and/or increase our costs, which could adversely affect our results of operations and financial condition. Our operations are subject to federal, state and municipal laws and regulations regulating, among other matters, logistics activities, product quality specifications and other environmental matters. The trend in environmental regulation has been towards more restrictions and limitations on activities that may affect the environment over time. For example, President Biden signed an executive order calling for new or more stringent emissions standards for new, modified and existing oil and gas facilities, and the EPA finalized rules to that effect. Our businesses 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. 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. Risks related to our environmental permits, including the risk of noncompliance, permit interpretation, permit modification, renewal of permits on less favorable terms, judicial or administrative challenges to permits by citizens groups or federal, state or municipal entities or permit revocation are inherent in the operation of our businesses, as it is with other companies engaged in similar businesses. We may not be able to renew the permits necessary for our
operations, or we may be forced to accept terms in future permits that limit our operations or result in additional compliance costs.
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) product margin, (2) gross profit, (3) earnings before interest, taxes, depreciation and amortization (“EBITDA”) and adjusted EBITDA, (4) distributable cash flow and adjusted distributable cash flow, (5) selling, general and administrative expenses (“SG&A”), (6) operating expenses and (7) degree days.
Product Margin
We view product margin as an important performance measure of the core profitability of our operations. We review product margin monthly for consistency and trend analysis. We define product margin as our product sales minus product costs. Product sales primarily include sales of unbranded and branded gasoline, distillates, residual oil, renewable fuels and crude oil, as well as convenience store and prepared food sales, gasoline station rental income and revenue generated from our logistics activities when we engage in the storage, transloading and shipment of products owned by others. Product costs include the cost of acquiring products 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 and costs associated with our logistics activities. We also look at product margin on a per unit basis (product margin divided by volume). Product margin is a non-GAAP financial measure used by management and external users of our consolidated financial statements to assess our business. 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 product margin may not be comparable to product margin or a similarly titled measure of other companies.
Gross Profit
We define gross profit as our product margin minus terminal and gasoline station related depreciation expense allocated to cost of sales.
EBITDA and Adjusted EBITDA
EBITDA and adjusted EBITDA are non-GAAP financial measures used as supplemental financial measures by management and may be used by 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, gasoline blendstocks, renewable fuels, crude oil and propane, and in the gasoline stations and convenience stores business, 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.
Adjusted EBITDA is EBITDA further adjusted for gains or losses on the sale and disposition of assets, goodwill and long-lived asset impairment charges and our proportionate share of EBITDA related to our SPR joint venture, which is accounted for using the equity method. EBITDA and adjusted EBITDA should not be considered as alternatives 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 and adjusted EBITDA exclude some, but not all, items that affect net income, and these measures may vary among other companies. Therefore, EBITDA and adjusted EBITDA may not be comparable to similarly titled measures of other companies.
Distributable Cash Flow and Adjusted 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 as defined by our partnership agreement is 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.
Distributable cash flow as used in our partnership agreement also determines our ability to make cash distributions on our incentive distribution rights. The investment community also uses a distributable cash flow metric similar to the metric used in our partnership agreement with respect to publicly traded partnerships to indicate whether or not such partnerships have generated sufficient earnings on a current or historical level that can sustain distributions on preferred or common units or support an increase in quarterly cash distributions on common units. Our partnership agreement does not permit adjustments for certain non-cash items, such as net losses on the sale and disposition of assets and goodwill and long-lived asset impairment charges.
Adjusted distributable cash flow is a non-GAAP financial measure intended to provide management and investors with an enhanced perspective of our financial performance. Adjusted distributable cash flow is distributable cash flow (as defined in our partnership agreement) further adjusted for our proportionate share of distributable cash flow related to our SPR joint venture, which is accounted for using the equity method. Adjusted distributable cash flow is not used in our partnership agreement to determine our ability to make cash distributions and may be higher or lower than distributable cash flow as calculated under our partnership agreement.
Distributable cash flow and adjusted distributable cash flow should not be considered as alternatives 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 and adjusted distributable cash flow may not be comparable to distributable cash flow or similarly titled measures of other companies.
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, are reimbursed for these expenses by us.
Operating Expenses
Operating expenses are costs associated with the operation of the terminals, transload facilities and gasoline stations and convenience stores used in our businesses. Lease payments, maintenance and repair, property taxes, utilities, credit card fees, taxes, labor and labor-related expenses comprise the most significant portion of our operating expenses. While the majority of these expenses remains relatively stable, independent of the volumes through our system, they can
fluctuate depending on the activities performed during a specific period. In addition, they can be impacted by new directives issued by federal, state and local governments.
Degree Days
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.
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 (gallons and dollars in thousands):
Year Ended December 31,
Net income
$
152,506
$
362,207
EBITDA (1)
$
356,363
$
565,084
Adjusted EBITDA (1)
$
356,264
$
485,211
Distributable cash flow (2)(3)
$
202,709
$
413,395
Adjusted distributable cash flow (2)
$
201,715
$
413,395
Wholesale Segment:
Volume (gallons)
3,681,530
3,408,709
Sales
Gasoline and gasoline blendstocks
$
5,897,428
$
6,408,184
Distillates and other oils (4)
3,715,888
4,455,309
Total
$
9,613,316
$
10,863,493
Product margin
Gasoline and gasoline blendstocks
$
105,165
$
106,982
Distillates and other oils (4)
96,747
180,715
Total
$
201,912
$
287,697
Gasoline Distribution and Station Operations Segment:
Volume (gallons)
1,628,305
1,648,104
Sales
Gasoline
$
5,268,268
$
6,140,823
Station operations (5)
572,266
559,826
Total
$
5,840,534
$
6,700,649
Product margin
Gasoline
$
558,516
$
588,676
Station operations (5)
276,040
267,941
Total
$
834,556
$
856,617
Commercial Segment:
Volume (gallons)
421,223
414,871
Sales
$
1,038,324
$
1,313,744
Product margin
$
31,722
$
40,973
Combined sales and product margin:
Sales
$
16,492,174
$
18,877,886
Product margin (6)
$
1,068,190
$
1,185,287
Depreciation allocated to cost of sales
(94,550)
(87,638)
Combined gross profit
$
973,640
$
1,097,649
GDSO portfolio as of December 31, 2023 and 2022:
Company operated (7)
Commissioned agents
Lessee dealers
Contract dealers
Total GDSO portfolio
1,627
1,673
Year Ended December 31,
Weather conditions:
Normal heating degree days
5,630
5,630
Actual heating degree days
4,741
5,072
Variance from normal heating degree days
(16)
%
(10)
%
Variance from prior period actual heating degree days
(7)
%
%
(1) EBITDA and adjusted EBITDA are non-GAAP financial measures which are discussed above under “-Evaluating Our Results of Operations.” The table below presents reconciliations of EBITDA and adjusted EBITDA to the most directly comparable GAAP financial measures.
(2) Distributable cash flow and adjusted distributable cash flow are non-GAAP financial measures which are discussed above under “-Evaluating Our Results of Operations.” As defined by our partnership agreement, distributable cash flow is not adjusted for certain non-cash items, such as net losses on the sale and disposition of assets and goodwill and long-lived asset impairment charges. The table below presents reconciliations of distributable cash flow and adjusted distributable cash flow to the most directly comparable GAAP financial measures.
(3) Distributable cash flow for 2023 includes $2.5 million of income from our equity method investment related to our 49.99% interest in our SPR joint venture (see Note 17 of Notes to Consolidated Financial Statements). Distributable cash flow for 2022 includes a net gain on sale and disposition of assets of $79.9 million, primarily related to the sale of our terminal in Revere, Massachusetts (the “Revere Terminal”) in June 2022 (see Note 18 of Notes to Consolidated Financial Statements).
(4) Distillates and other oils (primarily residual oil and crude oil). Segment reporting results for 2022 have been reclassed within the Wholesale segment to conform to our current presentation. Specifically, results from crude oil previously shown separately are included in distillates and other oils as results from crude oil are immaterial.
(5) Station operations consist of convenience store and prepared food sales, rental income and sundries.
(6) 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 product margin on a combined basis to gross profit, a directly comparable GAAP measure.
(7) Excludes 64 sites at December 31, 2023 that are operated by our SPR joint venture (see Note 17 of Notes to Consolidated Financial Statements).
The following table presents reconciliations of EBITDA and adjusted EBITDA to the most directly comparable GAAP financial measures on a historical basis (in thousands):
Year Ended December 31,
Reconciliation of net income to EBITDA and adjusted EBITDA:
Net income
$
152,506
$
362,207
Depreciation and amortization
110,090
104,796
Interest expense
85,631
81,259
Income tax expense
8,136
16,822
EBITDA
356,363
565,084
Net gain on sale and disposition of assets
(2,626)
(79,873)
Income from equity method investments (1)
(2,503)
-
EBITDA related to equity method investments (1)
5,030
-
Adjusted EBITDA
$
356,264
$
485,211
Reconciliation of net cash provided by operating activities to EBITDA and adjusted EBITDA:
Net cash provided by operating activities
$
512,441
$
479,996
Net changes in operating assets and liabilities and certain non-cash items
(249,845)
(12,993)
Interest expense
85,631
81,259
Income tax expense
8,136
16,822
EBITDA
356,363
565,084
Net gain on sale and disposition of assets
(2,626)
(79,873)
Income from equity method investments (1)
(2,503)
-
EBITDA related to equity method investments (1)
5,030
-
Adjusted EBITDA
$
356,264
$
485,211
(1) Represents our proportionate share of income and EBITDA, as applicable, related to our 49.99% interest in our SPR joint venture (see Note 17 of Notes to Consolidated Financial Statements).
The following table presents reconciliations of distributable cash flow and adjusted distributable cash flow to the most directly comparable GAAP financial measures on a historical basis (in thousands):
Year Ended December 31,
Reconciliation of net income to distributable cash flow and adjusted distributable cash flow:
Net income
$
152,506
$
362,207
Depreciation and amortization
110,090
104,796
Amortization of deferred financing fees
5,651
5,432
Amortization of routine bank refinancing fees
(4,700)
(4,596)
Maintenance capital expenditures
(60,838)
(54,444)
Distributable cash flow (1)(2)
202,709
413,395
Income from equity method investments (3)
(2,503)
-
Distributable cash flow from equity method investments (3)
1,509
-
Adjusted distributable cash flow (1)
201,715
413,395
Distributions to preferred unitholders (4)
(14,559)
(13,852)
Adjusted distributable cash flow after distributions to preferred unitholders
$
187,156
$
399,543
Reconciliation of net cash provided by operating activities to distributable cash flow and adjusted distributable cash flow:
Net cash provided by operating activities
$
512,441
$
479,996
Net changes in operating assets and liabilities and certain non-cash items
(249,845)
(12,993)
Amortization of deferred financing fees
5,651
5,432
Amortization of routine bank refinancing fees
(4,700)
(4,596)
Maintenance capital expenditures
(60,838)
(54,444)
Distributable cash flow (1)(2)
202,709
413,395
Income from equity method investments (3)
(2,503)
-
Distributable cash flow from equity method investments (3)
1,509
-
Adjusted distributable cash flow (1)
201,715
413,395
Distributions to preferred unitholders (4)
(14,559)
(13,852)
Adjusted distributable cash flow after distributions to preferred unitholders
$
187,156
$
399,543
(1) Distributable cash flow and adjusted distributable cash flow are non-GAAP financial measures which are discussed above under “-Evaluating Our Results of Operations.” As defined by our partnership agreement, distributable cash flow is not adjusted for certain non-cash items, such as net losses on the sale and disposition of assets and goodwill and long-lived asset impairment charges.
(2) Distributable cash flow for 2023 includes $2.5 million of income from our equity method investment related to our 49.99% interest in our SPR joint venture (see Note 17 of Notes to Consolidated Financial Statements). Distributable cash flow for 2022 includes a net gain on sale and disposition of assets of $79.9 million, primarily related to the sale of the Revere Terminal (see Note 18 of Notes to Consolidated Financial Statements
(3) Represents our proportionate share of net income and distributable cash flow, as applicable, related to our 49.99% interest in our SPR joint venture (see Note 17 of Notes to Consolidated Financial Statements).
(4) Distributions to preferred unitholders represent the distributions payable to the Series A preferred unitholders and the Series B preferred unitholders earned during the period. These distributions are cumulative and payable quarterly in arrears on February 15, May 15, August 15 and November 15 of each year.
Results of Operations
Consolidated Sales
Our total sales were $16.5 billion and $18.9 billion for 2023 and 2022, respectively, a decrease of $2.4 billion, or 13%, primarily due to a decrease in prices, partially offset by an increase in volume sold. Our aggregate volume of product sold was 5.7 billion gallons and 5.5 billion gallons for 2023 and 2022, respectively, increasing 259 million gallons (consisting of increases of 273 million gallons in our Wholesale segment, primarily in gasoline and gasoline blendstocks but also in distillates and other oils, and 6 million gallons in our Commercial segment, offset by a decrease of 20 million gallons in our GDSO segment).
Gross Profit
Our gross profit was $973.6 million and $1.1 billion for 2023 and 2022, respectively, decreasing $124.0 million, or 11%. Our Wholesale segment product margins decreased in 2023 due to less favorable market conditions, largely in distillates but also in residual oil, compared to 2022 when market conditions were more favorable, offset by an increase in crude oil product margin due to the expiration of a pipeline connection agreement. In our GDSO segment, our gasoline distribution product margin decreased due in part to lower fuel margins (cents per gallon), while our station operations product margin increased due to an increase in activity at our convenience stores in part due to the September 2022 acquisition of Tidewater Convenience, Inc. (“Tidewater”). In our Commercial segment, our product margin decreased, primarily due to less favorable market conditions in bunkering.
Results for Wholesale Segment
Gasoline and Gasoline Blendstocks. Sales from wholesale gasoline and gasoline blendstocks were $5.9 billion and $6.4 billion for 2023 and 2022, respectively, a decrease of $0.5 billion, or 8%, primarily due to a decrease in prices, partially offset by an increase in volume sold. Our gasoline and gasoline blendstocks product margin was $105.2 million and $107.0 million for 2023 and 2022, respectively, a decrease of $1.8 million, or 2%, primarily due to less favorable market conditions in gasoline, offset by more favorable market conditions in gasoline blendstocks.
Distillates and Other Oils. Sales from distillates and other oils (primarily residual oil and crude oil) were $3.7 billion and $4.5 billion for 2023 and 2022, respectively, a decrease of $0.8 billion, or 17%, primarily due to a decrease in distillate prices, partially offset by an increase in volume sold. Our product margin from distillates and other oils was $96.7 million and $180.7 million for 2023 and 2022, respectively, a decrease of $84.0 million, or 46%, primarily due to less favorable market conditions, largely in distillates but also in residual oil, compared to 2022 when market conditions were more favorable. The decrease in product margin was offset by an increase in crude oil product margin due to the expiration of a pipeline connection agreement in December of 2022.
Results for Gasoline Distribution and Station Operations Segment
Gasoline Distribution. Sales from gasoline distribution were $5.3 billion and $6.1 billion for 2023 and 2022, respectively, a decrease of $0.8 billion, or 13%, primarily due to decreases in prices and in volume sold. Our product margin from gasoline distribution was $558.5 million and $588.7 million for 2023 and 2022, respectively, a decrease of $30.2 million, or 5%, primarily due to lower fuel margins (cents per gallon), largely during the third quarter in 2023 compared to significantly higher fuel margins in the third quarter of 2022 due to especially favorable market conditions experienced in 2022.
Station Operations. Our station operations, which include (i) convenience store and prepared food sales at our directly operated stores, (ii) rental income from gasoline stations leased to dealers or from commissioned agents and from cobranding arrangements and (iii) sale of sundries, such as car wash sales and lottery and ATM commissions, collectively generated revenues of $572.2 million and $559.8 million for 2023 and 2022, respectively, an increase of $12.4 million, or 2%. Our product margin from station operations was $276.0 million and $267.9 million for 2023 and 2022, respectively, an increase of $8.1 million, or 3%. The increases in sales and product margin are primarily due to an increase in activity at our convenience stores, in part due to the acquisition of Tidewater, partially offset by the sale of non-strategic sites.
Results for Commercial Segment
Our commercial sales were $1.0 billion and $1.3 billion for 2023 and 2022, respectively, decreasing $275.4 million, or 21%, due a decrease in prices, partially offset by an increase in volume sold. Our commercial product margin was $31.7 million and $41.0 million for 2023 and 2022, respectively, a decrease of $9.3 million, or 23%, primarily due to less favorable market conditions in bunkering.
Selling, General and Administrative Expenses
SG&A expenses were $273.7 million and $263.1 million for 2023 and 2022, respectively, an increase of $10.6 million, or 4%, including increases of $8.4 million of expenses associated with the sale of the Revere Terminal (see Note 18 of Notes to Consolidated Financial Statements), $7.7 million in wages and benefits, $3.2 million in acquisition costs and $1.4 million in professional fees. The increase in SG&A expenses was offset by a decrease of $1.3 million in accrued discretionary incentive compensation and $1.3 million in various other SG&A expenses. In addition, in 2022 we incurred approximately $7.5 million in connection with an ongoing dispute between us and the landlord at certain of our sites, a dispute in which we believe we have meritorious defenses.
Operating Expenses
Operating expenses were $450.6 million and $445.3 million for 2023 and 2022, respectively, an increase of $5.3 million, or 1%, including an increase of $6.3 million associated with our GDSO operations, including the Tidewater acquisition, in part due to increases in salary expense, maintenance and repair expenses and other various operating expenses, offset by decreases in our environmental reserve and in credit card fees due to lower gasoline prices and operating expenses related to the sale of non-strategic sites during 2023. Operating expenses associated with our terminal operations decreased $1.0 million, in part due to a decrease in maintenance and repair expenses, offset by an increase in rent and lease expenses.
Amortization Expense
Amortization expense related to our intangible assets was $8.1 million and $8.9 million for 2023 and 2022, respectively.
Net Gain on Sale and Disposition of Assets
Net gain on sale and disposition of assets was $2.6 million for 2023, primarily due to the sale of GDSO sites. Net gain on sale and disposition of assets was $79.9 million for 2022, consisting of a net gain of $76.8 million related to the sale of the Revere Terminal (see Note 18 of Notes to Consolidated Financial Statements for more information) and to a net gain of $3.1 million, primarily due to the sale of GDSO sites.
Income from Equity Method Investments
Income from equity method investments was $2.5 million and $0 for 2023 and 2022, respectively, representing our proportional share of earnings from our SPR joint venture. There was no income from equity method investments related to our Everett joint venture in 2023 or 2022. See Note 17 of Notes to Consolidated Financial Statements for information on our equity method investments.
Interest Expense
Interest expense was $85.6 million and $81.3 million for 2023 and 2022, respectively, an increase of $4.3 million, or 5%, due in part to higher interest rates and a $0.5 million write-off of deferred financing fees associated with the amendment to our credit agreement in May 2023, offset by lower average balances on our credit facilities.
Income Tax Expense
Income tax expense was $8.1 million and $16.8 million 2023 and 2022, respectively. The respective income tax expense predominantly reflects the income tax expense from the operating results of GMG, which is a taxable entity for federal and state income tax purposes.
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. Our primary sources of liquidity are cash generated from operations, amounts available under our working capital revolving credit facility and equity and debt offerings. Please read “-Credit Agreement” for more information on our working capital revolving credit facility.
Working capital was $115.0 million and $197.8 million at December 31, 2023 and 2022, respectively, a decrease of $82.8 million. Changes in current assets and current liabilities decreasing our working capital primarily include, in part, a decrease of $169.4 million in inventories and an increase of $117.8 million in accounts payable. The decrease in working capital was offset by a decrease of $136.6 million in the current portion of our working capital revolving credit facility and an increase of $72.9 million in accounts receivable.
Cash Distributions
Common Units
During 2023, we paid the following cash distributions to our common unitholders and our general partner:
Distribution Paid for the
Cash Distribution Payment Date
Total Paid
Quarterly Period Ended
February 14, 2023 (1)
$
55.4 million
Fourth quarter 2022
May 15, 2023
$
24.0 million
First quarter 2023
August 14, 2023
$
25.2 million
Second quarter 2023
November 14, 2023
$
25.8 million
Third quarter 2023
(1) This distribution consists of a quarterly distribution of $0.6350 per unit and a one-time special distribution of $0.9375 per unit. Our general partner agreed to waive its incentive distribution rights with respect to the special distribution.
In addition, on January 24, 2024, the board of directors of our general partner declared a quarterly cash distribution of $0.7000 per unit ($2.80 per unit on an annualized basis) on all of our outstanding common units for the period from October 1, 2023 through December 31, 2023 to unitholders of record as of the close of business on February 8, 2024. On February 14, 2024, we paid the total cash distribution of approximately $26.8 million.
Preferred Units
During 2023, we paid the following cash distributions to holders of the Series A Preferred Units and the Series B Preferred Units:
Cash Distribution
Series A Preferred Units
Series B Preferred Units
Distribution Paid for the
Payment Date
Total Paid
Rate
Total Paid
Rate
Quarterly Period Covering
2/15/2023
$
1.7 million
9.75%
$
1.8 million
9.50%
11/15/22 - 2/14/23
5/15/2023
$
1.7 million
9.75%
$
1.8 million
9.50%
2/15/23 - 5/14/23
8/15/2023
$
1.7 million
9.75%
$
1.8 million
9.50%
5/15/23 - 8/14/23
11/15/2023
$
2.1 million
12.40%
$
1.8 million
9.50%
8/15/23 - 11/14/23
In addition, on January 16, 2024, the board of directors of our general partner declared a quarterly cash distribution of $0.77596 per unit ($3.10 per unit on an annualized basis) on the Series A Preferred Units for the period from November 15, 2023 through February 14, 2024 to our Series A preferred unitholders of record as of the opening of business on February 1, 2024. The applicable distribution rate on the Series A Preferred Units for such period, as calculated by our calculation agent, was approximately 12.42%. On February 15, 2024, we paid the total cash distribution of approximately $2.1 million.
The board of directors of our general partner also declared a quarterly cash distribution of $0.59375 per unit ($2.375 per unit on an annualized basis) on the Series B Preferred Units for the period from November 15, 2023 through February 14, 2024 to our Series B preferred unitholders of record as of the opening of business on February 1, 2024. On February 15, 2024, we paid the total cash distribution of approximately $1.8 million.
Contractual Obligations
We have contractual obligations that are required to be settled in cash. The amounts of our contractual obligations at December 31, 2023 were as follows (in thousands):
Payments Due by Period
Contractual Obligations
Next 12 Months
Beyond 12 Months
Total
Credit facility obligations (1)
$
45,174
$
409,481
$
454,655
Senior notes obligations (2)
52,063
942,283
994,346
Operating lease obligations (3)
76,903
233,193
310,096
Other long-term liabilities (4)
14,125
45,508
59,633
Financing obligations (5)
15,777
82,171
97,948
Total
$
204,042
$
1,712,636
$
1,916,678
(1) Includes principal and interest on our working capital revolving credit facility and our revolving credit facility at December 31, 2023 and assumes a ratable payment through the expiration date. Our credit agreement has a contractual maturity of May 2, 2026 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 consolidated 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. Please read “-Credit Agreement” for more information on our working capital revolving credit facility.
(2) Includes principal and interest on our 7.00% senior notes due 2027 and our 6.875% senior notes due 2029. No principal payments are required prior to maturity. Excludes principal and interest on our 8.250% senior notes due 2032 issued on January 18, 2024. See “-Liquidity and Capital Resources-Senior Notes” for additional information.
(3) Includes operating lease obligations related to leases for office space and computer equipment, land, gasoline stations, railcars and barges. See Note 4 of Notes to Consolidated Financial Statements for additional information.
(4) Includes amounts related to our brand fee agreement, amounts related to our access right agreements and our pension and deferred compensation obligations.
(5) Includes lease rental payments in connection with (i) the acquisition of Capitol Petroleum Group (“Capitol”) related to properties previously sold by Capitol within two sale-leaseback transactions; and (ii) the sale of real property assets and convenience stores. See “-Liquidity and Capital Resources-Financing Obligations” for additional information.
See Note 4 of Notes to Consolidated Financial Statements with respect to sublease information related to certain lease agreements and Note 12 of Notes to Consolidated Financial Statements with respect to purchase commitments.
Capital Expenditures
Our operations require investments to maintain, expand, upgrade and enhance existing operations and to meet environmental and operational 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 also include expenditures required to maintain equipment reliability, tank 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 $60.8 million and $54.4 million in maintenance capital expenditures for the years ended December 31, 2023 and 2022, respectively, which are included in capital expenditures in the accompanying consolidated statements of cash flows, of which approximately $52.9 million and $45.0 million for 2023 and 2022, respectively, are related to our investments in our gasoline station business. 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 businesses or expand our existing facilities, such as projects that increase our operating capacity or revenues by, for example, increasing dock capacity and tankage, diversifying product availability, investing in raze and rebuilds and new-to-industry gasoline stations and convenience stores, increasing storage flexibility at various terminals and by adding terminals to our storage network. 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 $28.0 million and $52.4 million in expansion capital expenditures, excluding acquired property and equipment, for the years ended December 31, 2023 and 2022, respectively, primarily related to investments in our gasoline station business.
We currently expect maintenance capital expenditures of approximately $50.0 million to $60.0 million and expansion capital expenditures, excluding acquisitions, of approximately $60.0 million to $70.0 million in 2024, relating primarily to investments in our gasoline station and terminal businesses. These current estimates depend, in part, on the timing of completion of projects, availability of equipment and workforce, weather and unanticipated events or opportunities requiring additional maintenance or investments.
We believe that we will have sufficient cash flow from operations, borrowing capacity under our credit agreement and the ability to issue additional equity 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 have an adverse effect on our borrowing capacity as well as our ability to issue additional equity and/or debt securities.
Cash Flow
The following table summarizes cash flow activity for the years ended December 31 (in thousands):
Net cash provided by operating activities
$
512,441
$
479,996
Net cash used in investing activities
$
(492,380)
$
(236,193)
Net cash used in financing activities
$
(4,459)
$
(250,612)
Operating Activities
Cash flow from operating activities generally reflects our net income, balance sheet changes arising from inventory purchasing patterns, the timing of collections on our accounts receivable, the seasonality of parts of our businesses, fluctuations in product prices, working capital requirements and general market conditions.
Net cash provided by operating activities was $512.4 million and $480.0 million for 2023 and 2022, respectively, for a period-over-period increase in cash flow from operating activities of $32.4 million. The period-over-period change reflects a net gain on the sale and disposition of assets of $79.9 million in 2022, primarily related to the sale of the Revere Terminal (see Note 18 of Notes to Consolidated Financial Statements).
Except for net income, the primary drivers of the changes in operating activities include the following for the years ended December 31 (in thousands):
Increase in accounts receivable
$
(73,782)
$
(67,774)
Decrease (increase) in inventories
$
172,112
$
(52,086)
Increase in accounts payable
$
117,777
$
177,644
In 2023, the increases in accounts receivable and accounts payable are in part due to timing of sales and payments, offset by a decrease in prices. The decrease in inventories is primarily due to the decrease in prices.
In 2022, the increases in accounts receivable inventories and accounts payable are in part due to the increase in prices.
Investing Activities
Net cash used in investing activities was $492.4 million for 2023 and included $313.2 million related to the acquisition of the Terminal Facilities from Motiva (see Note 3 to Notes to Consolidated Financial Statements), $95.3 million in expenditures associated with our equity method investments (see Note 17 of Notes to Consolidated Financial Statements), $88.8 million in capital expenditures, $8.5 million in seller note issuances which represent notes we received from buyers in connection with the sale of certain of our gasoline stations and $1.5 million in an immaterial acquisition. Net cash used in investing activities was offset by $12.9 million in proceeds from the sale of property and equipment and $2.0 million in dividends received of equity method investment in SPR.
Net cash used in investing activities was $236.2 million for 2022 and included $256.2 million in acquisitions (see Note 3 to Notes to Consolidated Financial Statements), $106.8 million in capital expenditures and $1.7 million in seller note issuances, offset by $128.5 million in proceeds from the sale of property and equipment, primarily related to the sale of the Revere Terminal.
Please read “-Capital Expenditures” for a discussion of our capital expenditures for the years ended December 31, 2023 and 2022.
Financing Activities
Net cash used in financing activities was $4.4 million for 2023 and included $144.7 million in cash distributions to our limited partners (preferred and common unitholders) and our general partner, $136.6 million in net payments on our working capital revolving credit facility, $3.5 million in the repurchase of common units pursuant to our repurchase program for future satisfaction of our LTIP obligations, $0.5 million in LTIP units withheld for tax obligations and $0.1 million in distribution equivalent rights. Net cash used in financing activities was offset by $281.0 million in net borrowings on our revolving credit facility, in part due to fund the acquisition of the Terminal Facilities from Motiva.
Net cash used in financing activities was $250.6 million for 2022 and included $201.3 million in net payments on our working capital revolving credit facility, $100.4 million in cash distributions to our limited partners (preferred and common unitholders) and our general partner, $2.9 million in the repurchase of common units pursuant to our repurchase program for future satisfaction of our LTIP obligations and $1.6 million in LTIP units withheld for tax obligations related to awards that vested in 2022. Net cash used in financing activities was offset by $55.6 million in net borrowings from our revolving credit facility, primarily to fund our acquisitions.
See Note 9 of Notes to Consolidated Financial Statement for supplemental cash flow information related to our working capital revolving credit facility and revolving credit facility for 2023 and 2022.
Credit Agreement
Certain subsidiaries of ours, as borrowers, and we and certain of our subsidiaries, as guarantors, had a $1.75 billion senior secured credit facility as of December 31, 2023. As discussed below, effective February 5, 2024, the total commitment under the credit agreement was reduced to $1.55 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 expires on May 2, 2026.
On February 2, 2023, we and certain of our subsidiaries entered into the eighth amendment to the third amended and restated credit agreement, pursuant to which we and the lenders under our credit agreement agreed to a reallocation of $150.0 million of the working capital revolving credit facility to the revolving credit facility. After giving effect to such reallocation, the working capital revolving credit facility was $950.0 million, and the revolving credit facility was $600.0 million.
On May 2, 2023, we and certain of our subsidiaries entered into the ninth amendment to third amended and restated credit agreement and joinder which, among other things, increased the applicable revolver rate by 25 basis points on borrowings under the revolving credit facility and extended the maturity date from May 6, 2024 to May 2, 2026.
On December 7, 2023, we exercised a portion of the accordion feature included in our credit agreement (as further described below) and increased the aggregate working capital revolving commitments by $200.0 million, to $1.75 billion from $1.55 billion, for a period not to exceed 364 days. Also on December 7, 2023, we and the lenders under our credit agreement agreed to reallocate $300.0 million of the working capital revolving credit facility to the revolving credit facility.
As of December 31, 2023, there were two facilities under the 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 the Partnership’s borrowing base and $850 million; and
● a $900.0 million revolving credit facility to be used for general corporate purposes.
On February 5, 2024, we and the lenders under our credit agreement agreed, pursuant to the terms of our credit agreement, to (i) a reallocation of $300.0 million of the revolving credit facility to the working capital revolving credit facility and (ii) reduce the accordion feature from $200.0 million to $0. After giving effect to the reallocation and the accordion reduction, the working capital revolving credit facility is $950.0 million and the revolving credit facility is $600.0 million, for a total commitment of $1.55 billion, effective February 8, 2024. This reallocation and accordion reduction return our credit facilities to the terms in place prior to the reallocation and accordion exercise previously agreed to by us and the lenders on December 7, 2023.
The credit agreement has an accordion feature whereby we may request on the same terms and conditions then applicable to the credit agreement, provided no 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 $300.0 million, in the aggregate, for a total credit facility of up to $1.85 billion. Any such request for an increase must be in a minimum amount of $25.0 million. We cannot provide assurance, however, that our lending group and/or other lenders outside our lending group will agree to fund any request by us for additional amounts in excess of the total available commitments of $1.55 billion.
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 U.S. dollars in an aggregate amount equal to the lesser of (a) $75.0 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 $1.55 billion.
Availability under the 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. Availability under the 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.
Borrowings under the working capital revolving credit facility bear interest at (1) the Daily or Term secured overnight financing rate (“SOFR”) plus a 0.10% SOFR adjustment plus a margin of 2.00% to 2.50% depending on the Utilization Amount (as defined in the credit agreement), or (2) the base rate plus a margin of 1.00% to 1.50% depending on the Utilization Amount. Borrowings under the revolving credit facility bear interest at (1) the Daily or Term SOFR plus a 0.10% SOFR adjustment plus a margin of 2.00% to 3.00% depending on the Combined Total Leverage Ratio (as defined in the credit agreement), or (2) the base rate plus a margin of 1.00% to 2.00% depending on the Combined Total Leverage Ratio.
The average interest rates for the credit agreement were 7.2% and 3.7% for the years ended December 31, 2023
and 2022, respectively.
The credit agreement provides for a letter of credit fee equal to the then applicable working capital rate or then applicable revolver rate 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 0.35% to 0.50% per annum.
As of December 31, 2023, we had $16.8 million outstanding on the working capital revolving credit facility and $380.0 million outstanding on the revolving credit facility. In addition, we had outstanding letters of credit of $220.2 million. Subject to borrowing base limitations, the total remaining availability for borrowings and letters of credit was $1.13 billion and $1.12 billion at December 31, 2023 and 2022, respectively.
The credit agreement is secured by substantially all of our assets and the assets of our wholly owned subsidiaries and is guaranteed by us and certain of our subsidiaries.
The credit agreement also includes certain baskets, including (i) a $25.0 million general secured indebtedness basket, (ii) a $25.0 million general investment basket, (iii) a $75.0 million secured indebtedness basket to permit the borrowers to enter into a Contango Facility (as defined in the credit agreement), (iv) a Sale/Leaseback Transaction (as defined in the credit agreement) basket of $100.0 million, and (v) a basket of $150.0 million in an aggregate amount for the purchase of our common units, provided that, among other things, no Default exists or would occur immediately following such purchase(s).
In addition, the credit agreement provides the ability for the borrowers to repay certain junior indebtedness, subject to a $100.0 million cap, so long as, among other things, no Default has occurred or will exist immediately after making such repayment.
The credit agreement imposes financial covenants that require us to maintain certain minimum working capital amounts, 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, 2023.
Senior Notes
8.250% Senior Notes Due 2032
On January 18, 2024, we and GLP Finance Corp. (the “Issuers”) issued $450.0 million aggregate principal amount of 8.250% senior notes due 2032 (the “2032 Notes”) to several initial purchasers in a private placement exempt from the registration requirements under the Securities Act of 1933, as amended (the “Securities Act”). We used the net proceeds from the offering to repay a portion of the borrowings outstanding under our credit agreement and for general corporate purposes.
In connection with the private placement of the 2032 Notes, the Issuers and the subsidiary guarantors and Regions Bank, as trustee, entered into an indenture as may be supplemented from time to time (the “2032 Notes Indenture”).
The 2032 Notes mature on January 15, 2032 with interest accruing at a rate of 8.250% per annum. Interest will be payable beginning July 15, 2024 and thereafter semi-annually in arrears on January 15 and July 15 of each year. The 2032 Notes are guaranteed on a joint and several senior unsecured basis by each of the Issuers and the subsidiary guarantors to the extent set forth in the 2032 Notes Indenture. Upon a continuing event of default, the trustee or the holders of at least 25% in principal amount of the 2032 Notes may declare the 2032 Notes immediately due and payable, except that an event of default resulting from entry into a bankruptcy, insolvency or reorganization with respect to the Issuers, any restricted subsidiary of ours that is a significant subsidiary or any group of our restricted subsidiaries that, taken together, would constitute a significant subsidiary of ours, will automatically cause the 2032 Notes to become due and payable.
The Issuers will have the option to redeem up to 35% of the 2032 Notes prior to January 15, 2027 at a redemption price (expressed as a percentage of principal amount) of 108.250% plus accrued and unpaid interest, if any. The Issuers will have the option to redeem the 2032 Notes, in whole or in part, at any time on or after January 15, 2027, at the redemption prices of 104.125% for the twelve-month period beginning January 15, 2027, 102.063% for the twelve-month period beginning January 15, 2028, and 100% beginning on January 15, 2029 and at any time thereafter, together with any accrued and unpaid interest to the date of redemption. In addition, before January 15, 2027, the Issuers may redeem all or any part of the 2032 Notes at a redemption price equal to the sum of the principal amount thereof, plus a make whole premium, plus accrued and unpaid interest, if any, to the redemption date. The holders of the 2032 Notes may require the Issuers to repurchase the 2032 Notes following certain asset sales or a Change of Control Triggering Event (as defined in the 2032 Notes Indenture) at the prices and on the terms specified in the 2032 Notes Indenture.
The 2032 Notes Indenture contains covenants that limit our ability to, among other things, incur additional indebtedness and issue preferred securities, make certain dividends and distributions, make certain investments and other restricted payments, restrict distributions by our subsidiaries, create liens, sell assets or merge with other entities. Events of default under the 2032 Notes Indenture include (i) a default in payment of principal of, or interest or premium, if any, on, the 2032 Notes, (ii) breach of our covenants under the 2032 Notes Indenture, (iii) certain events of bankruptcy and insolvency, (iv) any payment default or acceleration of indebtedness of our or certain subsidiaries if the total amount of such indebtedness unpaid or accelerated exceeds $50.0 million and (v) failure to pay within 60 days uninsured final judgments exceeding $50.0 million.
6.875% Senior Notes Due 2029
On October 7, 2020, the Issuers issued $350.0 million aggregate principal amount of 6.875% senior notes due 2029 (the “2029 Notes”) to several initial purchasers in a private placement exempt from the registration requirements under the Securities Act. We used the net proceeds from the offering to fund the redemption of our 7.00% senior notes due 2023 and to repay a portion of the borrowings outstanding under our credit agreement.
In connection with the private placement of the 2029 Notes, the Issuers and the subsidiary guarantors and Regions Bank, as trustee, entered into an indenture as may be supplemented from time to time (the “2029 Notes Indenture”).
The 2029 Notes mature on January 15, 2029 with interest accruing at a rate of 6.875% per annum. Interest is payable beginning July 15, 2021 and thereafter semi-annually in arrears on January 15 and July 15 of each year. The 2029 Notes are guaranteed on a joint and several senior unsecured basis by each of the Issuers and the subsidiary guarantors to the extent set forth in the 2029 Notes Indenture. Upon a continuing event of default, the trustee or the holders of at least 25% in principal amount of the 2029 Notes may declare the 2029 Notes immediately due and payable, except that an event of default resulting from entry into a bankruptcy, insolvency or reorganization with respect to the Issuers, any restricted subsidiary of ours that is a significant subsidiary or any group of our restricted subsidiaries that, taken together, would constitute a significant subsidiary of ours, will automatically cause the 2029 Notes to become due and payable.
The Issuers have the option to redeem the 2029 Notes, in whole or in part, at any time on or after January 15, 2024, at the redemption prices of 103.438% for the twelve-month period beginning on January 15, 2024, 102.292% for the twelve-month period beginning January 15, 2025, 101.146% for the twelve-month period beginning January 15, 2026, and 100% beginning on January 15, 2027 and at any time thereafter, together with any accrued and unpaid interest to the date of redemption. In addition, prior to January 15, 2024, the Issuers may redeem all or any part of the 2029 Notes at a redemption price equal to the sum of the principal amount thereof, plus a make whole premium, plus accrued and unpaid interest, if any, to the redemption date. The holders of the 2029 Notes may require the Issuers to repurchase the 2029 Notes following certain asset sales or a Change of Control Triggering Event (as defined in the 2029 Notes Indenture) at the prices and on the terms specified in the 2029 Notes Indenture.
The 2029 Notes Indenture contains covenants that limit our ability to, among other things, incur additional indebtedness and issue preferred securities, make certain dividends and distributions, make certain investments and other
restricted payments, restrict distributions by our subsidiaries, create liens, sell assets or merge with other entities. Events of default under the 2029 Notes Indenture include (i) a default in payment of principal of, or interest or premium, if any, on, the 2029 Notes, (ii) breach of our covenants under the 2029 Notes 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 $50.0 million and (v) failure to pay within 60 days uninsured final judgments exceeding $50.0 million.
7.00% Senior Notes Due 2027
On July 31, 2019, the Issuers issued $400.0 million aggregate principal amount of 7.00% senior notes due 2027 (the “2027 Notes”) to several initial purchasers in a private placement exempt from the registration requirements under the Securities Act. We used the net proceeds from the offering to fund the repurchase of our 6.25% senior notes due 2022 in a tender offer and to repay a portion of the borrowings outstanding under our credit agreement.
In connection with the private placement of the 2027 Notes on July 31, 2019, the Issuers and the subsidiary guarantors and Regions Bank (as successor trustee to Deutsche Bank Trust Company Americas), as trustee, entered into an indenture as may be supplemented from time to time (the “2027 Notes Indenture”).
The 2027 Notes mature on August 1, 2027 with interest accruing at a rate of 7.00% per annum and payable semi-annually in arrears on February 1 and August 1 of each year, commencing February 1, 2020. The 2027 Notes are guaranteed on a joint and several senior unsecured basis by each of the Issuers and the subsidiary guarantors to the extent set forth in the 2027 Notes Indenture. Upon a continuing event of default, the trustee or the holders of at least 25% in principal amount of the 2027 Notes may declare the 2027 Notes immediately due and payable, except that an event of default resulting from entry into a bankruptcy, insolvency or reorganization with respect to the Issuers, any restricted subsidiary of ours that is a significant subsidiary or any group of our restricted subsidiaries that, taken together, would constitute a significant subsidiary of ours, will automatically cause the 2027 Notes to become due and payable.
The Issuers have the option to redeem the 2027 Notes, in whole or in part, at any time on or after August 1, 2023, at the redemption prices of 102.333% for the twelve-month period beginning August 1, 2023, 101.167% for the twelve-month period beginning August 1, 2024, and 100% beginning on August 1, 2025 and at any time thereafter, together with any accrued and unpaid interest to the date of redemption. The holders of the 2027 Notes may require the Issuers to repurchase the 2027 Notes following certain asset sales or a Change of Control Triggering Event (as defined in the 2027 Notes Indenture) at the prices and on the terms specified in the 2027 Notes Indenture.
The 2027 Notes Indenture contains covenants that will limit our ability to, among other things, incur additional indebtedness and issue preferred securities, make certain dividends and distributions, make certain investments and other restricted payments, restrict distributions by our subsidiaries, create liens, sell assets or merge with other entities. Events of default under the 2027 Notes Indenture include (i) a default in payment of principal of, or interest or premium, if any, on, the 2027 Notes, (ii) breach of our covenants under the 2027 Notes 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 $50.0 million and (v) failure to pay within 60 days uninsured final judgments exceeding $50.0 million.
Financing Obligations
Capitol Acquisition
In connection with the June 2015 acquisition of retail gasoline stations and dealer supply contracts from Capitol, we assumed a financing obligation of $89.6 million associated with two sale-leaseback transactions for 53 leased sites. During the terms of these leases, which expire in May 2028 and September 2029, in lieu of recognizing lease expense for the lease rental payments, we incur interest expense associated with the financing obligation. Interest expense of approximately $8.8 million and $9.0 million was recorded for the years ended December 31, 2023 and 2022, respectively. The financing obligation will amortize through expiration of the leases based upon the lease rental
payments which were $10.9 million and $10.6 million for the years ended December 31, 2023 and 2022, respectively. The financing obligation balance outstanding at December 31, 2023 was $81.3 million associated with the acquisition.
Sale-Leaseback Transaction
In connection with a sale in June 2016 of real property assets, including the buildings, improvements and appurtenances thereto, at 30 gasoline stations and convenience stores, we entered into a Master Unitary Lease Agreement to lease back certain of the real property assets sold. The initial term of the Master Unitary Lease Agreement expires in 2031. We have one successive option to renew the lease for a ten-year period followed by two successive options to renew the lease for five-year periods on the same terms, covenants, conditions and rental as the primary non-revocable lease term.
In connection with this transaction, we recognized a corresponding financing obligation of $62.5 million. During the term of the lease, which expires in June 2031, we incur interest expense associated with the financing obligation. Lease rental payments are recognized as both interest expense and a reduction of the principal balance associated with the financing obligation. Interest expense was $4.2 million for both years ended December 31, 2023 and 2022, and lease rental payments were $4.9 million and $4.8 million for the years ended December 31, 2023 and 2022, respectively. The financing obligation balance outstanding at December 31, 2023 was $60.5 million associated with this transaction.
Environmental Matters
Our businesses of purchasing, storing, supplying and distributing refined petroleum products, gasoline blendstocks, renewable fuels, crude oil and propane and other business activities, 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 businesses, please read Items 1 and 2, “Business and Properties-Environmental.” For additional information regarding our environmental liabilities, see Note 15 of Notes to Consolidated Financial Statements included elsewhere in this report.
Critical Accounting Policies and Estimates
Our consolidated financial statements are prepared in accordance with U.S. GAAP. A summary of our significant accounting policies used 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; therefore, our actual results could differ from these estimates under different assumptions or conditions. We believe our critical accounting estimates that are subjective in nature, require the exercise of judgment and involve complex analysis include the valuation of physical forward derivative contracts, valuation of goodwill and environmental liabilities.
Valuation of Physical Forward Derivative Contracts
As described in Note 10 and Note 11 of Notes to Consolidated Financial Statements, we enter into different commodity contracts that qualify as derivative instruments. These include physical forward purchase and sale contracts and are accounted for at fair value. These contracts are considered Level 2 derivative instruments under the fair value hierarchy as inputs used to determine fair value are not quoted prices in active markets. As of December 31, 2023, derivative assets of $17.7 million and derivative liabilities of $5.0 million were recorded for physical forward derivative contracts based on Level 2 fair value measurements. There were no Level 3 physical forward derivative contracts as of December 31, 2023 and 2022.
Accounting for the fair value measurement of physical forward derivative instruments is complex given the judgmental nature of the assumptions used as inputs into the valuation models. These include inputs used to value commodity products at locations whereby active market pricing may not be available. These assumptions are forward-looking and could be affected by future economic and market conditions.
We utilize published and quoted prices, broker quotes, and estimates of market prices to estimate the fair value of these contracts; however, actual amounts could vary materially from estimated fair values as a result of changes in market prices. In addition, changes in the methods used to determine the fair value of these contracts could have a material effect on our results of operations. We do not anticipate future changes in the methods used to determine the fair value of these derivative contracts.
Business Combinations
Under the purchase method of accounting, we recognize tangible and identifiable intangible assets acquired and liabilities assumed based on their estimated fair values. We record any excess of the purchase price over the fair value of the net tangible and intangible assets acquired as goodwill. The accounting for business combinations requires us to make significant estimates and assumptions when determining the value of acquired assets and liabilities. Estimates in valuing purchased dealer supply contracts include, in part, the expected use of the assets acquired, the expected useful life of another asset (or group of assets) related to the acquired assets and legal, regulatory or other contractual provisions that may limit the useful life of an acquired asset. If the subsequent actual results and updated projections of the underlying business activity change compared with the assumptions and projections used to develop these values, we could experience impairment charges. In addition, we have estimated the economic lives of certain acquired assets and these lives are used to calculate depreciation and amortization expense. If our estimates of the economic lives change, depreciation or amortization expenses could be accelerated or slowed.
Valuation of Goodwill
We allocate the fair value of the purchase price associated in a business combination to the tangible and intangible assets acquired and liabilities assumed based on their estimated fair values. The excess of the fair value of the purchase price over the fair values of these identifiable assets and liabilities is recorded as goodwill and allocated to our reporting units based on the future expected benefit arising from the business combination.
Such valuations require management to make significant estimates and assumptions. Management’s estimates of fair value are based upon assumptions believed to be reasonable at the time, but which are inherently uncertain and unpredictable and, as a result, actual results may differ from estimates. During the measurement period, which is not to exceed one year from the acquisition date, we may record adjustments to the assets acquired and liabilities assumed, with the corresponding offset to goodwill. Upon the conclusion of the measurement period, any subsequent adjustments are recorded to earnings.
We have concluded that our operating segments are also our reporting units. 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.
All of our goodwill is allocated to the GDSO segment. During 2023 and 2022, we completed a quantitative assessment for the GDSO reporting unit. Factors included in the assessment included both macro-economic conditions and industry specific conditions, and the fair value of the GDSO reporting unit was estimated using a weighted average of a discounted cash flow approach and a market comparables approach. Based on our assessment, no impairment was identified.
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 when related contingencies are resolved, generally upon cash receipt.
We are subject to other contingencies, including legal proceedings and claims arising out of our businesses that cover a wide range of matters, including, environmental matters and contract and employment claims. Environmental and other legal proceedings may also include matters with respect to businesses 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.
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.

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
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 currently utilize various derivative instruments to manage exposure to commodity risk.
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.
As of December 31, 2023, we had total borrowings outstanding under our credit agreement of $396.8 million. Please read Part II, Item 7, “Management’s Discussion and Analysis-Liquidity and Capital Resources-Credit Agreement,” for information on interest rates related to our borrowings. 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 $4.0 million annually, assuming, however, that our indebtedness remained constant throughout the year.
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 exchange-traded 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 commodity product purchase and sales activities, we may experience net unbalanced positions for short periods of time as a result of variances in daily purchases and sales and transportation and delivery schedules as well as other logistical issues inherent in our businesses,
such as weather conditions. In connection with managing these positions, we are aided by maintaining a constant presence in the marketplace. We also engage in a controlled trading program for up to an aggregate of 250,000 barrels of commodity products at any one point in time. Changes in the fair value of these derivative instruments are recognized in the consolidated statements of operations through cost of sales. In addition, because a portion of our crude oil business may be conducted in Canadian dollars, we may use foreign currency derivatives to minimize the risks of unfavorable exchange rates. These instruments may 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.
We utilize exchange-traded 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 exchanges for the respective 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.
At December 31, 2023, 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):
Fair Value at
Gain (Loss)
December 31,
Effect of 10%
Effect of 10%
Price Increase
Price Decrease
Exchange traded derivative contracts
$
33,421
$
(18,458)
$
18,458
Forward derivative contracts
12,669
(13,072)
13,072
Total
$
46,090
$
(31,530)
$
31,530
The fair values of the futures contracts are based on quoted market prices obtained from the NYMEX, CME and ICE. 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, 2023. 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 $12.8 million at December 31, 2023.
We are exposed to credit loss in the event of nonperformance by counterparties to our exchange-traded derivative contracts, physical 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. Exchange-traded derivative contracts, the primary derivative instrument utilized by us, are traded on regulated exchanges, greatly reducing potential credit risks. We utilize major financial institutions as our clearing brokers for all NYMEX, CME and ICE derivative transactions and the right of offset exists with these financial institutions. Accordingly, the fair value of our exchange-traded derivative instruments is presented on a net basis in the consolidated balance sheet. Exposure on physical forward contracts and swap agreements is limited to the amount of the recorded fair value as of the balance sheet dates.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
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.

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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
Item 9. Changes in and Disagreements With Accountants on Accounting and Financial Disclosure.
None.

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ITEM 9A. CONTROLS AND PROCEDURES
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 this evaluation, our principal executive officer and principal financial officer concluded that our disclosure controls and procedures were operating and effective as of December 31, 2023.
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). Our 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 (2013 framework). Based on that evaluation, management concluded that our internal control over financial reporting was effective as of December 31, 2023.
The effectiveness of our internal control over financial reporting as of December 31, 2023 has been audited by Ernst & Young LLP, our independent registered public accounting firm, as stated in their report. See “Report of Independent Registered Public Accounting Firm” on page of our consolidated financial statements.
Changes in Internal Control Over Financial Reporting
There were no changes in our internal control over financial reporting that occurred during the quarter ended December 31, 2023 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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ITEM 9B. OTHER INFORMATION
Item 9B. Other Information.
During the three months ended December 31, 2023, no director or executive officer of the Partnership adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as each term is defined in Item 408(a) of Regulation S-K.

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
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. Unitholders are not entitled to elect the directors of our general partner or directly or indirectly participate in our management or operation. Affiliates of the Slifka family own 100% of the ownership interests in our general partner. Our general partner is controlled by Richard Slifka and Eric Slifka, through their beneficial ownership of entities that own membership interests in our general partner. 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.
Five 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 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 five independent members of the board of directors of our general partner, Messrs. Hailer, McCool, Owens and Pereira and Ms. McGrory, 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 to 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 Jaime Pereira, 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 businesses and affairs, but from time to time certain executive officers perform or have performed services for other entities controlled by the Slifka family. Please read Part III, Item 13, “Certain Relationships and Related Transactions, and Director Independence-Services Agreement.” Our non-management directors devote as much time as is necessary to prepare for and attend board of directors and committee meetings.
Set forth below are the names, ages (as of February 22, 2024) and titles of persons currently serving as directors and executive officers of our general partner:
Name
Age
Position with Global GP LLC
Richard Slifka
Chairman
Eric Slifka
President, Chief Executive Officer and Vice Chairman
Mark A. Romaine
Chief Operating Officer
Gregory B. Hanson
Chief Financial Officer
Matthew Spencer
Chief Accounting Officer
Sean T. Geary
Chief Legal Officer and Secretary
Robert J. McCool
Director
Jaime Pereira
Director
John T. Hailer
Director
Robert W. Owens
Director
Clare McGrory
Director
Richard Slifka was elected Vice Chairman of the Board of our general partner in March 2005 and became Chairman in March 2014. 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. Mr. Slifka also was a shareholder, a director and the President of Global Petroleum Corp., a privately held affiliated company that had owned, operated and leased to us our petroleum products storage terminal located in Revere, Massachusetts until we acquired the terminal in January 2015. Mr. Slifka is a past director of the New England Fuel Institute and currently serves as president of the Independent Fuel Terminal Operators Association. He served on the Boston Medical Center Corporation Board of Trustees from 2006-2019 and on the BMC Health System, Inc., Board of Trustees from 2013-2021. He currently serves on the board of directors of St. Francis House. Mr. Slifka served as a director of the National Multiple Sclerosis Society from 1988-2019. 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 is the brother of the late Alfred A. Slifka.
Eric Slifka was elected President, Chief Executive Officer and director of Global GP LLC, the general partner of Global Partners LP, in March 2005 and became Vice Chairman in March 2014. 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. He is a member of the National Petroleum Council and serves on the board of directors of the Energy Policy Research Foundation, Inc. and Massachusetts General Hospital President’s Council. Mr. Slifka’s extensive knowledge of the energy industry in general and of our history, customers and suppliers make him uniquely qualified to serve as our Vice Chairman of the Board. Mr. Slifka is the son of the late Alfred A. Slifka and the nephew of Richard Slifka.
Mark A. Romaine has been Chief Operating Officer of Global Partners LP since July 2013. Mr. Romaine served as the Senior Vice President of Light Oil Supply and Distribution for Global Partners LP from 2006 until June 2013. He joined a predecessor company to Global Companies LLC in 1998 as Premium Fuels Marketing Manager. His experience in the petroleum products industry includes operations and marketing positions with Plymouth, MA-based Volta Oil. Mr. Romaine received a bachelor’s degree from Providence College and an MBA from the University of Massachusetts.
Gregory B. Hanson was appointed by the Board of Directors of our general partner to serve as the Chief Financial Officer of Global Partners LP, commencing September 1, 2021. Mr. Hanson previously served as Treasurer of our general partner and of Global Partners LP from August 2014 through August 2021. Mr. Hanson has more than 20 years of financial experience. Before joining the Partnership in 2013, he served as a Senior Vice President at GE Energy Financial Services and RBS Citizens Financial Group. Before that, he worked for Merrill Lynch Capital and Bank of America. Mr. Hanson received a bachelor’s degree from Colby College and an MBA from Babson College’s
Franklin W. Olin School of Business.
Matthew Spencer was appointed by the Board of Directors of our general partner to serve as the Chief Accounting Officer of Global Partners LP, commencing January 1, 2018. Mr. Spencer served as Controller of the general partner from September 2012 through December 2017. Mr. Spencer joined the Partnership from SharkNinja Operating LLC (formerly Euro-Pro Operating LLC), where he served as Assistant Controller. Prior to that, he was a Senior Manager at Ernst & Young LLP. Mr. Spencer is a member of the Northborough-Southborough Regional School Committee.
Sean T. Geary was appointed by the Board of Directors of our general partner to serve as the Chief Legal Officer of Global Partners LP, commencing March 1, 2022. Mr. Geary joined the Partnership in 2005, bringing more than a decade of experience at large law firms. He later became the Partnership’s Deputy General Counsel and Vice President, Mergers & Acquisitions before being named Acting General Counsel in 2021. Mr. Geary received a bachelor’s degree from the University of Vermont and a J.D. from Boston University School of Law. Mr. Geary serves on the board of directors of Christmas in the City, Inc. and is the President, Director and Secretary of Global for Good Fund, Inc.
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. In September 2020, he was designated co-chair of the conflicts committee. He served as an Advisor to Tetco Inc., a privately held company in the energy industry, for 15 years and 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. Mr. McCool has announced his retirement as a director of our general partner and as a member of the conflicts, compensation and audit committees of the board, effective March 1, 2024.
Jaime Pereira was elected to serve as a director of our general partner and as a member of the conflicts, compensation and audit committees of the board of directors of our general partner in October 2021. Mr. Pereira was appointed as the chair of the audit committee as of January 1, 2022. Mr. Pereira has over forty years of accounting and advisory experience working with a wide variety of domestic and international, public and private companies, including serving as a partner at international accounting firm Ernst & Young LLP for 20 years. At Ernst & Young, Mr. Pereira was responsible for the Consumer Products practice in the Northeast Region and was the coordinating partner for Global Partners LP and other clients such as Bruker Corporation and Au Bon Pain. Mr. Pereira has been a member of the American Institute of Certified Public Accountants, and he currently serves on the Boards of Roche Bros. Supermarkets Co.. Mr. Pereira is a graduate of the University of Massachusetts Amherst and presently serves on the Business Advisory Council for the Isenberg School of Management. Mr. Pereira’s prior audit history with the Partnership and his extensive experience with the accounting aspects of the energy and retail industries make him well qualified to serve as a director of our general partner.
John T. Hailer was elected to serve as a director of our general partner and as a member of the conflicts, compensation and audit committees of the board of directors of our general partner in July 2018. In September 2020, he was designated co-chair of the conflicts committee. He is President of the 1251 Asset Management division of 1251 Capital Group, a Boston-based financial services company that owns a concentrated group of companies in the asset management and insurance sectors. Prior to joining 1251 Capital Group, he spent more than 18 years at Natixis Investment Managers (formerly Natixis Global Asset Management; “Natixis”) and joined that firm in 1999. Mr. Hailer formerly served as Natixis’ President and Chief Executive Officer for the Americas and Asia, where he helped that company strategically reposition as a global solutions provider and grow to become one of the world’s largest asset managers. Before joining Natixis, Mr. Hailer was responsible for new business development in North and Latin America at Fidelity Investments Institutional Services Company and was director of retail business development for Putnam Investments. He serves as a trustee on several other boards including Boston Medical Center and the Boston Public Library. Mr. Hailer also serves as the Chairman of the Board for each of the New England Council and the Back Bay
Association. Mr. Hailer previously served as a member of Beloit College’s Board of Trustees. Mr. Hailer’s broad experience in the financial services industry, as well as his significant capital markets and financial experience, make him a valuable member of our board of directors.
Robert W. Owens was elected to serve as a director of our general partner and as a member of the conflicts, compensation and audit committees of the board of directors of our general partner in October 2020. On January 1, 2022, he was designated chair of the compensation committee. He has more than 40 years of experience in the energy industry. He served as President and Chief Executive Officer of Sunoco LP (“Sunoco”) from 2012 until his retirement in 2017, and as a member of the board of directors of Sunoco from 2014 through 2018. Mr. Owens helped successfully grow Sunoco through a series of strategic transactions, including the acquisition of Susser Holdings Corporation. Prior to joining Sunoco in 1997, he served in executive roles for Ultramar Diamond Shamrock Corporation, Amerada Hess Corporation and Mobil Oil Corporation. Mr. Owens served as a member of the board of directors of Philadelphia Energy Solutions, Inc. (“PES”) from 2012 through the sales of the PES refinery to Hilco Redevelopment Partners in June 2020. Mr. Owens’ executive leadership experience and governance expertise, built over more than four decades in diverse aspects of the energy industry, make him well qualified to serve as a director of our general partner.
Clare McGrory was elected to serve as a director of our general partner and as a member of the conflicts, compensation and audit committees of the board of directors of our general partner in March 2023. Since 2016, Ms. McGrory has served as Chief Financial Officer (“CFO”), Chief Compliance Officer and partner of Atairos Management LP (“Atairos”). Atairos is an independent strategic investment firm focused on backing growth-oriented businesses across a wide range of industries. Ms. McGrory has over 13 years of experience in the energy industry, including serving as the CFO, Executive Vice President, and Treasurer of Sunoco, LP (“Sunoco”), a publicly traded retail marketing and fuel distribution business. At Sunoco, Ms. McGrory had responsibility for investor relations, business strategy, treasury, accounting, external reporting, internal audit, and other oversight responsibilities. Ms. McGrory received a Bachelor of Science degree in accounting from Villanova University and a Master of Business Administration from the Villanova School of Business Executive MBA Program. She is an adjunct professor at Villanova University and serves on the Board of Directors for the Boys & Girls Clubs of Philadelphia. Ms. McGrory’s financial, accounting, and executive leadership experience, including 13 years within the energy industry, make her well qualified to serve as a director of our general partner.
Delinquent Section 16(a) Reports
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 (“Reporting Persons”) 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 all Reporting Persons complied with all Section 16(a) filing requirements in the year ended December 31, 2023, with the exception of: (i) two Form 4s for each of our Named Executive Officers with respect to reporting their March 3, 2023 and May 3, 2023 Phantom Unit Award grants on their August 31, 2023 Form 4 filings; (ii) the August 31, 2023 Form 4 filing for our President, CEO and Vice-Chair also included reporting on the February 28, 2023 receipt of common units from a family member’s Grantor Retained Annuity Trust by himself, and by certain family trusts of which he is the trustee; (iii) one Form 4 filing dated January 6, 2023 for each of our Independent Directors (other than Ms. McGrory) with respect to reporting on their receipt of October 14, 2022 Phantom Unit Award grants while also reporting on the January 1, 2023 vesting of those awards; and (iv) Form 4s filed on August 24, 2023 by two of our Independent Directors, one of which included reporting on a May 17, 2023 sale of common units by his spouse, and one of which included reporting on an August 9, 2023 purchase of common units by the Independent Director.
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.
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 500, Waltham, MA 02454-9161, Fax: 781-398-9211.
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 Chief Legal Officer at: Global Partners LP, P.O. Box 9161, 800 South Street, Suite 500, 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 2023.
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
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 who are employed by Global Montello Group Corp. (“GMG”) or SPR Operator LLC (“SPR Operator”) and certain union personnel. 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 also are 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 (“NEOs”) 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.
In 2023, our NEOs were (i) Mr. Eric Slifka, our Chief Executive Officer (“CEO”); (ii) Mr. Gregory B. Hanson, our Chief Financial Officer (“CFO”); and (iii) the three most highly compensated executive officers of our general partner other than our CEO and CFO during 2023, who were Mr. Mark A. Romaine, our Chief Operating Officer (“COO”), Mr. Sean T. Geary, our Chief Legal Officer and Mr. Matthew Spencer, our Chief Accounting Officer. Each of our NEOs had an employment agreement with our general partner during 2023.
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 any employment agreement or arrangement 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 NEOs other than our CEO based upon our CEO's recommendations, including awards under any incentive plans in which the NEOs participate, and our general partner's contractual obligations pursuant to any employment agreements or arrangements with our NEOs.
Compensation Objectives
The objectives of our compensation program with respect to our NEOs 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 NEO 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 incentive and discretionary cash and/or equity-based bonus awards designed to focus employees on key business objectives for a particular year; and
● Long-term, equity-based incentive awards designed to support the achievement of our long-term business objectives and the retention of key personnel.
Compensation Methodology
Under our executive compensation structure, our goal is to target our NEOs’ total compensation within a competitive range of market benchmarks. Specific competitive positioning is determined based on various factors, including specifically the scope and responsibilities of the NEOs, their experience and tenure in their roles, and their performance. Overall Partnership performance and individual performance may result in realized compensation being higher or lower than the targeted compensation levels.
Our general partner uses a third-party compensation consultant to study and supply market compensation data and to assist our management and the Compensation Committee in formulating competitive compensation plans and arrangements. The Compensation Committee retained Meridian Compensation Partners, LLC (“MCP”) as its compensation consultant for 2023.
MCP is an independent compensation consulting firm and does not provide any services to us outside of matters pertaining to executive officer and director compensation. MCP reports directly to the Compensation Committee, which is solely responsible for determining the scope of services performed by MCP and the directions given to MCP regarding the performance of such services. MCP attends Compensation Committee meetings as requested by the Compensation Committee.
The Compensation Committee determined that the services provided by MCP to the Compensation Committee during 2023 did not give rise to any conflicts of interest. The Compensation Committee made this determination by assessing the independence of MCP under the six independence factors adopted by the SEC and incorporated into the NYSE Corporate Governance Listing Standards. Further, in making this assessment, the Compensation Committee considered MCP’s written correspondence to the Compensation Committee that affirmed the independence of MCP and the partners, consultants and employees who provide services to the Compensation Committee on executive and director compensation matters.
MCP worked with the Compensation Committee in 2023 to (i) review and update our reference group of peer companies for performance assessment purposes; (ii) help determine competitive compensation ranges and target compensation opportunities for each of our NEOs; (iii) review and consider the design of, create the payment grid for, and update performance targets, performance metrics and related award levels for our NEO under, our general partner’s short-term incentive plan (the “STIP”) for 2023; (iv) review and consider the design of, create the payment grid for, and update performance targets, performance metrics and related award levels for our NEOs under, our general partner’s long-term incentive plan (“LTIP”) for 2023; (v) assist with a review of updated information for current three-year (2022-2024) employment agreements for our NEOs; (vi) assist with compensation information related to the 2023 Form 10-K and support discussions between the Compensation Committee and our CEO; and (vii) assist with determination of compensation for independent directors.
Highlights of Compensation Program Policies for Named Executive Officers
The key highlights of our 2023 compensation program for our NEOs is outlined below:
● A significant portion of total direct compensation for our NEOs is variable, dependent upon the Partnership’s actual performance (e.g., short-term, performance-based incentives and equity-based long-term incentives, some of which are performance-based);
● Annual equity awards;
● Performance-based incentive awards are capped at 200% of target;
● Performance-based incentive awards are earned based on achievement against pre-determined performance metrics, which are tied to our business plan and drive unitholder value; and
● The Compensation Committee engages the assistance of an independent compensation consultant.
Elements of Compensation
Our NEO 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 NEOs to fall within a competitive range of market benchmarks, which typically means between the median (50th percentile) and 75th percentile of 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.
The elements of the 2023 NEO compensation of our general partner were base salaries, short-term incentive awards, discretionary bonuses, long-term equity 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. Descriptions of the elements of the compensation program, their relationship to our compensation objectives, and principles used to guide their administration appear below:
Component
Objective
Base salaries; other benefits and perquisites
Attract and retain high caliber employees.
Short-term (cash-based) awards; discretionary bonus awards
Focus employees on key business objectives for a particular year.
Long-term (equity-based and/or cash-based) awards
Support the achievement of our long-term business objectives and the retention of key personnel.
We use base salaries to provide financial stability and to compensate our NEOs for fulfillment of their respective job duties.
Our STIP, along with the use of discretionary bonus awards, align a significant portion of our NEOs’ compensation with annual business performance and success, and provide rewards and recognition for key business outcomes such as achieving increased quarterly distributions in line with our financial results, expanding our distribution, marketing and sales of petroleum products, expanding our gasoline station and convenience store assets and the geographic markets that we serve, 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 equity awards and cash awards provide incentives 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 employee benefits and other perquisites such as automobile fringe benefits and, for our CEO, country/golf club memberships that are tailored to address our NEOs’ individual needs in order to facilitate the performance of their job duties and to be competitive with the total compensation packages available to other executive officers generally.
2023 NEO Compensation
Base Salaries
Each NEO’s base salary is a fixed component of compensation for each year. Base salary is designed to compensate each NEO for his role and responsibilities and sustained individual performance (including experience,
scope of responsibility, results achieved and future potential). Historically, the base salaries for our NEOs with employment agreements have been set by the terms of their respective employment agreements in effect from time to time. In March 2023, the Compensation Committee ratified and approved increases in base salary for the NEOs with the exception of Mr. Slifka, based upon its desire to bring pay levels closer to competitive market levels. As such, the annualized base salaries in effect as of the end of 2023 for our NEOs were as follows: $1,000,000 for Mr. Slifka, $675,000 for Mr. Romaine; $475,000 for Mr. Hanson; $410,000 for Mr. Geary; and $325,000 for Mr. Spencer.
Short-Term Incentive Plans
Our general partner established a STIP for each of our NEOs in March 2023, at which time payout targets (expressed as a percentage of each NEO’s base salary) were established by the Compensation Committee. Target awards under our general partner’s 2023 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”). The STIP Performance Component of incentive awards earned under the 2023 STIP were based on the Partnership’s actual performance in relation to goals for (i) our earnings before interest, taxes, depreciation and amortization (“EBITDA”), with a 35% weighting towards the STIP Performance Component, and (ii) our distributable cash flow before payment to preferred unitholders (“DCF”), with a 15% weighting towards the STIP Performance Component (the EBITDA and DCF goals, collectively, the “2023 Performance Objective”). The 2023 Performance Objective was established by the Compensation Committee in May 2023. The EBITDA component of the 2023 Performance Objective was selected by the Compensation Committee because it represents an accurate indicator of our performance over a specific period of time. The DCF component of the 2023 Performance Objective was selected by the Compensation Committee because it represents an accurate indicator of our success to provide a cash return on our limited partners’ investment in us. EBITDA and DCF are discussed in more detail under “Results of Operations - Evaluating Our Results of Operations”. Under the 2023 STIP, due to unpredictable and volatile variables outside of the control of the Partnership that may positively or negatively impact the Partnership’s 2023 results of operations, for purposes of determining whether the 2023 Performance Objective was achieved, EBITDA may be adjusted by the Compensation Committee in its discretion to account for unusual, one-time factors that occurred during the year and could have increased or decreased EBITDA.
The Compensation Committee ratified and approved increases in the STIP target values for the NEOs under the 2023 STIP as compared to the 2022 STIP based upon its desire to bring pay levels closer to competitive market levels. The 2023 incentive target values were: 150% (or $1,500,000) for Mr. Slifka; 100% (or $675,000) for Mr. Romaine; 85% (or $404,000) for Mr. Hanson; 80% (or $328,000) for Mr. Geary; and 75% (or $244,000) for Mr. Spencer. 50% of the incentive target value for each NEO was allocated to their STIP Performance Component and 50% was allocated to their STIP Discretionary Component.
STIP Performance Component (50% of the incentive target value).-Under the terms of the 2023 STIP, each NEO could have earned between 0% and 200% of their respective incentive target value based on achieved performance against pre-set performance goals, specifically EBITDA (weighted at 70% of the STIP Performance Component) and DCF (weighted at 30% of the STIP Performance Component). With respect to the EBITDA performance goal, the threshold was set at $225,000,000, the target was set at $300,000,000 and the maximum was set at $330,000,000. With respect to the DCF performance goal, the threshold was set at $117,774,750, the target was set at $157,033,000 and the maximum was set at $172,736,300. If the applicable threshold was not achieved for the EBITDA performance goal and the DCF performance goal, then no amounts would have been paid under the 2023 STIP with respect to the STIP Performance Component.
With respect to the EBITDA performance goal, we exceeded the maximum level of performance based on our EBITDA of $356,363,000. With respect to the DCF performance goal, we also exceeded the maximum level of performance based on our DCF of $202,709,000. Accordingly, our NEOs received the following payouts under the STIP Performance Component for 2023: $1,500,000 for Mr. Slifka; $675,000 for Mr. Romaine; $404,000 for Mr. Hanson; $328,000 for Mr. Geary; and $244,000 for Mr. Spencer.
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 analyze other factors that it may
consider for determining the STIP Discretionary Component. Such factors may include, without limitation, market factors and significant acquisitions, developments and ventures accomplished by us, management of our business in the face of adverse market conditions and, as may be applicable, the contributions of any or all of the NEOs. Mr. Slifka’s evaluation of our NEOs’ performance in 2023 included the recognition that their individual and collective performances were excellent, completing over $400 million in transformative acquisitions and investments which significantly increased our operational footprint (providing additional scale, diversification and opportunities for growth), strong financial performance exceeding both EBITDA and DCF goal ranges, continued optimization of our existing business, and prudent and proactive balance sheet management (including significant and successful capital raising to facilitate acquisitions), enhancing liquidity and strengthening our balance sheet.
In considering whether, and in what amount(s), to grant any or all of our NEOs 2023 STIP Discretionary Component awards, the Compensation Committee recognized that our business performance in 2023 was strong, with our leadership team successfully managing external challenges and fulfilling many important initiatives. The Compensation Committee noted that our NEOs, individually and collectively, have continued to effectively oversee development of activities and staffing consistent with our strategies and growth objectives, and that they encourage the identification of and response to new opportunities as they arise. The following initiatives were undertaken by us under the leadership of Mr. Slifka and executed by our NEOs to strategically continue to acquire, invest in and optimize synergistic, high-quality assets that complement our operational capabilities, strengthen our balance sheet, and enhance our liquidity in order to be in a position to pursue opportunities fundamental to our growth strategy. Our 2023 initiatives included:
● On December 21, 2023, we completed the acquisition of twenty-five (25) refined product terminals along the Atlantic Coast, in the Southeast and in Texas from Motiva Enterprises LLC (“Motiva”), which terminals have an aggregate shell capacity of approximately 8.4 million barrels. The acquisition is underpinned by a twenty-five (25) year take-or-pay throughput agreement with Motiva that includes minimum annual revenue commitments. The purchase price was approximately $312.2 million, including inventory.
● On June 1, 2023, Spring Partners Retail LLC, a joint venture owned by us and Exxon Mobil Corporation (the “Spring Partners JV”), completed its acquisition of 64 Houston-area convenience and fueling facilities from certain Landmark entities. The Spring Partners JV’s assets are managed and operated by SPR Operator LLC, our wholly owned and indirect subsidiary.
● On October 23, 2023, we, through our wholly owned subsidiary, Global Everett Landco, LLC, and Everett Investor LLC entered into a Limited Liability Company Agreement of Everett Landco GP, LLC to form a joint venture to acquire, decommission and redevelop the former ExxonMobil terminal in Everett, MA (the “Joint Venture”). Everett Investor LLC is an entity controlled by an affiliate of The Davis Companies, a company primarily involved in the acquisition, development, management and sale of commercial real estate. We agreed to invest up to $30.0 million for an initial 30% ownership interest in the Joint Venture.
● On February 2, 2023, we amended our credit agreement to, among other things, (i) permit us to request up to two reallocations per calendar year (each, a “Reallocation”) of a portion of the working capital commitment, the aggregate working capital interim commitment, and/or the aggregate revolver commitment to the aggregate working capital commitment, the aggregate working capital interim commitment and/or the aggregate revolver commitment, as applicable, each such Reallocation to be a minimum of $50 million and, after giving effect to any such Reallocation, the amount of the aggregate commitments shall remain the same; and (ii) Reallocation of $150 million of the aggregate working capital commitment to the aggregate revolver commitment, effective February 2, 2023, after which the aggregate working capital commitments are $950 million, and the revolver commitment is $600 million.
● On December 7, 2023, we amended our credit agreement to, among other things, (i) reallocate $300 million of the aggregate working capital commitment to the aggregate revolver commitment; and (ii) exercise the accordion feature in the credit agreement to increase the aggregate working capital interim commitments by $200 million.
● Continuing commitment to invest in our infrastructure.
● Continuing optimization of fuel margins and volumes in both our GDSO and Wholesale segments.
● Ongoing divestiture of non-strategic assets and optimization of our retail portfolio through strategic conversion class of trade conversions.
Taking into account Mr. Slifka’s assessment, the Partnership’s results of operations for 2023, as well as the Compensation Committee’s review of the individual performance of each of our NEOs in 2023, the Compensation Committee awarded our NEOs the following payouts under the STIP Discretionary Component for 2023: $1,500,000 for Mr. Slifka; $675,000 for Mr. Romaine; $404,000 for Mr. Hanson; $328,000 for Mr. Geary; and $244,000 for Mr. Spencer.
Discretionary Bonuses
Our compensation program for NEOs contains a provision for the Compensation Committee to award discretionary bonus(es) to recognize significant contributions made by one or more of the NEOs during the course of the year. These are non-guaranteed awards and are 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 any or all of the other NEOs for consideration and approval by the Compensation Committee for similar purposes.
On February 23, 2023, based on the specific contributions made by each NEO during their 2022 service, the Compensation Committee awarded the following discretionary cash bonuses to our NEOs which were paid in March 2023: $500,000 for Mr. Slifka; $287,500 for Mr. Romaine; $159,500 for Mr. Hanson; $140,500 for Mr. Geary; and $112,500 for Mr. Spencer. At the same time, the Compensation Committee also awarded to each of our NEOs a supplemental discretionary equity-based award under the LTIP for an equivalent grant date value as their discretionary cash bonus. The February 23, 2023 LTIP awards, which vested on February 23, 2024, were granted in the following amounts: 14,501 phantom units for Mr. Slifka; 8,338 phantom units for Mr. Romaine; 4,626 phantom units for Mr. Hanson; 4,075 phantom units for Mr. Geary; and 3,263 phantom units for Mr. Spencer. Please see Long-Term Equity Incentive Awards-2023 Phantom Unit Awards.
Long-Term Equity Incentive Awards
The Compensation Committee uses time-based phantom unit awards (each, a “Time Phantom Unit Award”) and performance-based phantom units awards (each, a “Performance Unit Award”), each with distribution equivalent rights (“DERs”) under the LTIP in its NEO compensation design.
2023 Phantom Unit Awards.- On March 3, 2023, the Compensation Committee authorized the grant to each of our NEOs of a Performance Phantom Unit Award and a Time Phantom Unit Award. In addition, the Compensation Committee authorized the following two supplemental discretionary awards: (a) on February 23, 2023, awards each comprised of a (i) 50% cash component, and (ii) 50% Time Phantom Unit Award component that has a one (1) year cliff vest (see the table in the section titled “2023 NEO Compensation-Discretionary Awards” above); and (b) on May 3, 2023, a 2023 Time Phantom Unit Award with a two (2) year cliff vest as follows: 50,471 for Mr. Slifka; 33,647 for Mr. Romaine; 8,412 for Mr. Hanson; 8,412 for Mr. Geary; and 5,047 for Mr. Spencer.
The 2023 Performance Phantom Unit Awards represent the right to receive phantom units (or an equivalent amount of cash) in an amount up to 200% of the target number of phantom units subject to (i) such 2023 Performance Phantom Unit Award, and (ii) the NEO’s continued employment and satisfaction of performance criteria based on our DCF for a three (3) year cumulative performance period that begins on January 1, 2023 and ends on December 31, 2025, with the phantom units vesting upon completion of the overall three-year performance period and certification of the applicable level of achievement by the Compensation Committee. The Compensation Committee will calculate our cumulative DCF for the overall three-year performance period and, based on the aggregate results for such years, the number of phantom units earned under each 2023 Performance Phantom Unit Award could range from 0% to 200% of target. The Performance Phantom Unit Award targets are as follows: 64,378 for Mr. Slifka; 23,605 for Mr. Romaine; 16,309 for Mr. Hanson; 11,803 for Mr. Geary; and 7,869 for Mr. Spencer.
The 2023 Time Phantom Unit Awards represent the right to receive phantom units (or an equivalent amount of cash) on the applicable vesting date(s). On February 23, 2023, the Compensation Committee granted to our NEOs the following Time Phantom Unit Awards: 14,501 phantom units for Mr. Slifka; 8,338 phantom units for Mr. Romaine; 4,626 phantom units for Mr. Hanson; 4,075 phantom units for Mr. Geary; and 3,263 phantom units for Mr. Spencer, all of which vested on February 23, 2024. On March 3, 2023, the Compensation Committee granted to our NEOs the following Time Phantom Unit Awards: 64,377 phantom units for Mr. Slifka; 23,605 phantom units for Mr. Romaine; 16,309 phantom units for Mr. Hanson; 11,802 phantom units for Mr. Geary; and 7,868 phantom units for Mr. Spencer, all of which vested or are eligible to vest in three substantially equal installments on January 5 of 2024, 2025 and 2026, subject to the NEO’s continued employment through such vesting dates. On May 3, 2023, the Compensation Committee granted to our NEOs the following Time Phantom Unit Awards: 50,471 phantom units for Mr. Slifka; 33,647 phantom units for Mr. Romaine; 8,412 phantom units for Mr. Hanson; 8,412 phantom units for Mr. Geary; and 5,047 phantom units for Mr. Spencer, all of which will cliff vest on May 3, 2025, subject to the NEO’s continued employment through such vesting date.
The 2023 Time Phantom Unit Awards granted on March 3, 2023 represent our traditional annual equity incentive award grants designed to incentivize and reward our NEOs and provide a long-term retentive goal. The 2023 Time Phantom Unit Awards granted on February 23, 2023 and May 3, 2023 represent supplemental discretionary awards designed to reward the NEOs for their extraordinary performance in 2022 and the Partnership’s outstanding financial performance in 2022, as well as for positioning the Partnership for future growth and strength in the face of volatility in the commodity markets, geopolitical and logistical challenges, and a changing industry.
2022 Phantom Unit Awards- In 2022, each of our NEOs received (i) a performance-based phantom unit award with DERs (a “2022 Performance Phantom Unit Award”) and (ii) a time-based phantom unit award with DERs (a “2022 Time Phantom Unit Award”). The 2022 Performance Phantom Unit Awards are subject to three consecutive one-year performance periods, with the first one-year performance period having commenced on January 1, 2022. Based on the aggregate results for each of the three one-year performance subperiods within the overall three-year performance period, an NEO may earn between 0% and 200% of the target number of phantom units based on achieved performance against the applicable DCF performance goal for such one-year performance period. Generally, an NEO must be continuously employed over the three-year period ending on December 31, 2024 in order for any earned 2022 Performance Phantom Unit Awards to vest, subject to certain exceptions.
The 2022 Time Phantom Unit Awards represent the right to receive phantom units (or an equivalent amount of cash) and vested or are eligible to vest in three substantially equal installments on January 1 of 2023, 2024 and 2025 (as defined in the 2022 phantom unit award agreement under the LTIP), subject to the NEO’s continued employment through such vesting dates.
For a discussion of the treatment of the 2022 and 2023 Phantom Unit Awards in the event of certain termination events, see the section titled “Potential Payments upon Termination or Change of Control” below.
Long-Term Cash Incentive Awards
Long-Term Cash Incentive Plans-The Global Partners LP 2018 Long-Term Cash Incentive Plan (as amended from time to time, the “LTCIP”) allows the board of directors of our general partner or the Compensation Committee to
grant cash incentive awards (collectively, the “LTCIP Awards”) to our NEOs (as well as to other employees and directors) who provide services to the Partnership or its affiliates in recognition of their respective contributions to our financial results.
Once a portion of an LTCIP award vests, it is paid to the recipient as soon as practicable thereafter. Upon the occurrence of a Change of Control (as defined in the LTCIP), the unvested portion of such recipient’s LTCIP award(s) shall immediately become fully vested.
From 2018 through 2022, we granted awards to our NEOs under the LTCIP. However, no LTCIP awards were granted to our NEOs during 2023, as the Compensation Committee determined that it was more appropriate to grant phantom unit awards under the LTIP instead. For more information on such phantom unit awards, see the section titled “-Long-Term Equity Incentive Awards” above.
On June 10, 2022, the board of directors of our general partner granted awards under the LTCIP to our NEOs (each, a “2022 LTCIP Award”) in the following amounts: $4,500,000 for Mr. Slifka; $1,500,000 for Mr. Romaine; $600,000 for Mr. Hanson; $400,000 for Mr. Geary; and $600,000 for Mr. Spencer. Each 2022 LTCIP Award is subject to the following vesting schedule: 33.4% of the award vests on March 11, 2024, 33.3% of the award vests on March 11, 2025, and 33.3% of the award vests on March 11, 2026, subject to each NEO’s continued employment through such vesting dates.
In addition, on March 31, 2022, the board of directors of our general partner also granted awards under the LTCIP in the amount of $90,000 for Mr. Hanson and $50,000 for Mr. Geary in respect of their respective partial year of service prior to their becoming executive officers. We also refer to such awards as 2022 LTCIP Awards herein, which are subject to the following vesting schedule: 33.4% of the award vests on March 11, 2024, 33.3% of the award vests on March 11, 2025, and 33.3% of the award vests on March 11, 2026, subject to each such NEO’s continued employment through such vesting dates.
On October 22, 2021, the board of directors of our general partner granted awards under the LTCIP to our NEOs (each, a “2021 LTCIP Award”) in the following amounts: $3,500,000 for Mr. Slifka; $1,300,000 for Mr. Romaine; and $600,000 for Mr. Spencer. Each 2021 LTCIP Award is subject to the following vesting schedule: 33.4% of the award vested on July 10, 2023, 33.3% of the award vests on July 10, 2024, and 33.3% of the award vests on July 10, 2025, subject to each such NEO’s continued employment through such vesting dates.
On August 25, 2020, the board of directors of our general partner granted awards under the LTCIP to our NEOs (each, a “2020 LTCIP Award”) in the following amounts: $3,300,000 for Mr. Slifka; $1,200,000 for Mr. Romaine; and $400,000 for Mr. Spencer. Each 2020 LTCIP Award is subject to the following vesting schedule: 33.4% of the award vested on September 25, 2022, 33.3% of the award vested on September 25, 2023, and 33.3% of the award vests on September 25, 2024, subject to each such NEO’s continued employment through such vesting dates.
Retirement and Health Benefits; Perquisites
Global Partners 401(k) Savings and Profit Sharing Plan
The Global Partners LP 401(k) Savings and Profit Sharing Plan (the “Global 401(k) Plan”) permits all eligible employees (including our NEOs) to make voluntary pre-tax contributions to the plan, subject to applicable tax limitations. The Global 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 eligible compensation. Eligible employees may elect to contribute up to 100% of their compensation to the plan for each plan year, subject to annual dollar limitations. 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 our general partner's contributions, if any, will be deductible when made.
Pension Benefits
Each of our NEOs, other than Messrs. Hanson and Spencer, is eligible to participate in our general partner's pension plan 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 death or disability. Please read “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, and notice of its termination election effective as of December 31, 2023 was delivered to plan participants on November 1, 2023. Settlement of obligations is expected to be completed in the second half of 2024.
Other Benefits
Each of our NEOs is eligible to participate in our general partner's health insurance plans 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.
Additional perquisites for our NEOs may include payment of premiums for long-term disability insurance, automobile fringe benefits and club membership dues and, in 2021 only, with respect to our CEO, payment of fees for professional financial planning, tax and/or legal advice.
Employment Agreements
Each of our NEOs entered into a new three-year employment agreement with our general partner effective as of January 1, 2022. We believe that the post-termination and change in control payments in the employment agreements allow our NEOs to focus on making business decisions that maximize our interests and the interests of our unitholders without allowing personal considerations to influence the decision-making process. Please read “Potential Payments upon Termination or Change of Control” for a discussion of the provisions in each employment agreement relating to termination, change in control and related payment obligations.
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 our NEOs.
Clawback Policy
On November 7, 2023, we adopted the Global Partners LP Clawback Policy (the “Clawback Policy”). The
Clawback Policy is intended to comply with the requirements of Section 10D of the Exchange Act and Section 303A.14 of the NYSE Listing Company Manual. Under the terms of the Clawback Policy, in the event of a restatement of our financial statements due to material non-compliance with any financial reporting requirement under applicable securities laws, the Compensation Committee shall take reasonably prompt action to cause us to recover the amount of any incentive compensation granted, awarded or paid to a covered employee within the preceding 36-month period to the extent the value of such compensation was in excess of the amount of incentive compensation that would have been granted, awarded or paid had the financial statements been in compliance with the financial reporting requirements. Each executive officer, including our NEOs and certain former executive officers, are considered “Covered Persons” for purposes of the Clawback Policy.
Anti-Hedging and Pledging Policies
Our Insider Trading Policy prohibits our NEOs from engaging in speculative transactions involving our securities (such as our common units), including buying or selling puts or calls, short sales, purchasing securities on margin, or otherwise hedging the risk of ownership of such securities. The Insider Trading Policy also prohibits our NEOs from pledging our securities as collateral.
Compensation Committee Report
The Compensation Committee has reviewed and discussed the Compensation Discussion and Analysis required by Item 402(b) of Regulation S-K with management. Based upon such review, the related discussions and such other matters deemed relevant and appropriate by the Compensation Committee, the Compensation Committee has recommended to the board of directors that the Compensation Discussion and Analysis be included in this Form 10-K.
Robert W. Owens (Chair)
John T. Hailer
Robert J. McCool
Clare McGrory
Jaime Pereira
February 27, 2024
Compensation Committee Interlocks and Insider Participation
The Compensation Committee is currently comprised of Robert W. Owens (Chair), John T. Hailer, Robert J. McCool, Clare McGrory and Jaime Pereira. Clare McGrory was appointed to the board of directors of our general partner and became a member of the Compensation Committee effective March 1, 2023. None of the members of the Compensation Committee are officers or employees of our general partner or any of its affiliates. Mr. Richard Slifka has served as Chairman of our general partner’s board of directors since March 12, 2014 and previously served as Vice-Chairman of our general partner’s board of directors since its inception. Mr. Eric Slifka has served as Vice-Chairman of our general partner’s board of directors since March 12, 2014.
Compensation of Named Executive Officers
The following table sets forth certain information with respect to compensation during 2023, 2022 and 2021 of our NEOs.
Change in
Pension Value
and Deferred
Non-Equity
Nonqualified
Unit
Incentive Plan
Compensation
All Other
Name and Principal
Salary
Awards
Bonus
Compensation
Earnings
Compensation
Total
Position
Year
($)(1)
($)(2)
($)(3)
($)(4)
($)(5)
($)(6)
($)
Eric Slifka
1,000,000
6,499,980
500,000
7,500,000
7,606
81,871
15,589,457
President and CEO
1,000,000
3,929,415
-
6,500,000
-
67,181
11,496,596
1,000,000
-
-
5,500,000
-
92,919
6,592,919
Gregory B. Hanson
475,000
1,549,508
159,500
1,498,000
-
60,659
3,742,667
Chief Financial Officer
425,000
785,894
-
1,328,000
-
51,518
2,590,412
292,468
-
250,000
400,000
-
42,634
985,102
Mark A. Romaine
675,000
2,937,473
287,500
2,850,000
1,323
56,933
6,808,229
Chief Operating Officer
575,000
1,571,760
-
2,650,000
-
49,261
4,846,021
575,000
-
-
2,450,000
2,286
42,455
3,069,741
Matthew Spencer
325,000
812,513
112,500
1,088,000
-
53,540
2,391,553
Chief Accounting Officer
300,000
505,222
-
1,050,000
-
53,414
1,908,636
300,000
-
-
600,000
-
48,655
948,655
Sean T. Geary
410,000
1,574,994
140,500
1,106,000
59,786
3,292,004
Chief Legal Officer and Secretary
375,000
561,345
-
1,012,000
-
46,767
1,995,112
(1) Amounts reported in this column reflect the base salary earned by our NEOs for services performed during the applicable fiscal year.
(2) The grant date fair value of the 2023 Performance Phantom Unit Awards and 2023 Time Phantom Unit Awards granted to our NEOs are determined in accordance with FASB ASC Topic 718. Regarding assumptions underlying the valuation of these equity awards, please see Note 18 to Consolidated Financial Statements. Amounts in this column reflect the total of the following for 2023:
a. The grant date fair value of the February 23, 2023 Time Phantom Unit Awards granted to our named executed officers is calculated using the closing price of our common units on the grant date ($34.48) and is $499,994 for Mr. Slifka, $159,504 for Mr. Hanson, $287,494 for Mr. Romaine, $112,508 for Mr. Spencer and $140,506 for Mr. Geary.
b. The grant date fair value of the March 3, 2023 Time Phantom Unit Awards granted to our named executed officers is calculated using the closing price of our common units on the grant date ($34.95) and is $2,249,976 for Mr. Slifka, $570,000 for Mr. Hanson, $824,995 for Mr. Romaine, $274,987 for Mr. Spencer and $412,480 for Mr. Geary.
c. The grant date fair value of the 2023 Performance Phantom Unit Awards is based on achievement of the target level of performance with respect to the applicable performance criteria and is $2,250,011 for Mr. Slifka, $570,000 for Mr. Hanson, $824,995 for Mr. Romaine, $275,022 for Mr. Spencer, and $412,515 for Mr. Geary. Assuming that, instead of target, the highest level of performance with respect to the applicable performance criteria is achieved, the aggregate grant date fair value of the 2023 Performance Phantom Units would be $4,500,022 for Mr. Slifka, $1,139,999 for Mr. Hanson, $1,649,990 for Mr. Romaine, $550,043 for Mr. Spencer, and $825,030 for Mr. Geary.
d. The grant date fair value of the May 3, 2023 Time Phantom Unit Awards granted to our named executed officers is calculated using the closing price of our common units on the grant date ($29.72) and is $1,499,998 for Mr. Slifka, $250,005 for Mr. Hanson, $999,989 for Mr. Romaine, $149,997 for Mr. Spencer and $250,005 for Mr. Geary.
(3) In 2023, Messrs. Slifka, Hanson, Romaine, Spencer and Geary were paid discretionary bonuses of $500,000, $159,500, $287,500, $112,500, and $140,500, respectively, for services performed during 2022. No discretionary bonuses were paid to our NEOs for services performed during 2021. The amounts shown in the table above do not reflect long-term incentive awards granted in 2023 or discretionary cash bonuses paid after the date of this report as such long-term incentive awards were granted in 2023, and such discretionary cash bonuses have not yet been paid as of the date of this Annual Report on Form 10-K.
(4) Amounts reported in this column reflect the bonuses paid to each of the NEOs for services performed during 2023, 2022 and 2021, which were determined in accordance with our general partner’s Short-Term Incentive Plans described above under “Elements of Compensation-Short-Term Incentive Plans” and our general partner’s Long-Term Cash Incentive Plans described above under “Elements of Compensation-Long-Term Cash Incentive Awards.” Note that: (i) the amounts reported in this column do not reflect the grant date fair value of bonuses or non-equity incentive plan compensation granted to the NEOs in respect of their service during 2022, 2021 or 2020; and (ii) payment of the 2023 STIP was accelerated and paid in December 2022.
(5) Messrs. Hanson and Spencer are not eligible to participate in our general partner’s pension plan because it was frozen prior to their commencement of employment with us.
(6) With respect to Mr. Slifka, “All Other Compensation” for the years ended December 31, 2023, 2022 and 2021 includes, among other things, (a) club membership dues, and (b) with respect to 2021 only, professional financial planning and tax advice fees, paid by us in the amounts of $23,960 for 2023; $15,754 for 2022; $23,518 and $26,700, respectively, for 2021. The amounts in this column for 2023 are described further in the All Other Compensation table below.
All Other Compensation Table
The following table describes each component of the “All Other Compensation” column of the Summary Compensation Table for the fiscal year ended December 31, 2023:
Employer
Contributions to
Personal
Global 401(k)
Club Membership
Benefits
Total All Other
Name
Plan ($)
Dues ($)
($)(1)
Compensation ($)
Eric Slifka
12,200
23,960
45,711
81,871
Gregory B. Hanson
12,713
-
47,946
60,659
Mark A. Romaine
13,200
-
43,733
56,933
Matthew Spencer
9,916
-
43,624
53,540
Sean T. Geary
13,200
-
46,586
59,786
(1) The amounts in this column include the estimated incremental cost of an automobile provided by us for the NEO’s use; medical and dental premiums (or opt-out payments for declining coverage under our group healthcare policies) paid by us; and life insurance and long-term disability premiums paid by us.
Grants of Plan-Based Awards
The following table sets forth information regarding non-equity awards and equity awards granted to the NEOs in 2023.
Estimated Possible Payouts Under
Estimated Possible Payouts Under
Non-Equity Incentive Plan Awards (2)
Equity Incentive Plan Awards (3)
Grant Date
Award
Minimum
Minimum
All Other
Fair Value of
Type
Threshold
Target
Maximum
Threshold
Target
Maximum
Awards
Unit Awards
Name
(1)
($)
($)
($)
(#)
(#)
(#)
(#)(4)
($)(5)
Eric Slifka
(a)
525,000
1,500,000
3,000,000
-
-
-
-
-
(b)
-
-
-
-
-
-
14,501
499,994
(c)
-
-
-
-
-
-
64,377
2,249,976
(d)
-
-
-
-
-
-
50,471
1,499,998
(e)
-
-
-
22,532
64,378
128,756
-
2,250,011
Gregory B. Hanson
(a)
141,400
404,000
808,000
-
-
-
-
-
(b)
-
-
-
-
-
-
4,626
159,504
(c)
-
-
-
-
-
-
16,309
570,000
(d)
-
-
-
-
-
-
8,412
250,005
(e)
-
-
-
5,708
16,309
32,618
-
570,000
Mark A. Romaine
(a)
236,250
675,000
1,350,000
-
-
-
-
-
(b)
-
-
-
-
-
-
8,338
287,494
(c)
-
-
-
-
-
-
23,605
824,995
(d)
-
-
-
-
-
-
33,647
999,989
(e)
-
-
-
8,262
23,605
47,210
-
824,995
Matthew Spencer
(a)
85,400
244,000
488,000
-
-
-
-
-
(b)
-
-
-
-
-
-
3,263
112,508
(c)
-
-
-
-
-
-
7,868
274,986
(d)
-
-
-
-
-
-
5,047
149,997
(e)
-
-
-
2,754
7,869
15,738
-
275,022
Sean T. Geary
(a)
114,800
328,000
656,000
-
-
-
-
-
(b)
-
-
-
-
-
-
4,075
140,506
(c)
-
-
-
-
-
-
11,802
412,480
(d)
-
-
-
-
-
-
8,412
250,005
(e)
-
-
-
4,131
11,803
23,606
-
412,515
(1) Award types:
(a) STIP - Grant date: March 3, 2023
(b) 2023 Time Phantom Unit Awards - Grant date: February 23, 2023
(c) 2023 Time Phantom Unit Awards - Grant date: March 3, 2023
(d) 2023 Time Phantom Unit Awards - Grant date: May 3, 2023
(e) 2023 Performance Phantom Unit - Grant date: August 22, 2023; priced on approval date of March 3, 2023
(2) For calendar year 2023, each NEO’s STIP award consisted of the STIP Performance Component (weighted 50%) and the STIP Discretionary Component (weighted 50%). Amounts shown represent the “threshold,” “target” and “maximum” amounts payable under the STIP awards. On February 26, 2024, the Compensation Committee determined that two hundred percent (200%) of the STIP Performance Component and two hundred percent (200%) of the STIP Discretionary Component were earned by the NEOs for calendar year 2023. Actual payout of the STIP awards (the Performance Component and the Discretionary Component) for calendar year 2023 is shown in the “Non-Equity Incentive Plan Compensation” column of the Summary Compensation Table above.
(3) This column includes the threshold, target, and maximum payouts under the 2023 Performance Phantom Unit Awards granted to the NEOs. For more information on these awards, see “Elements of Compensation-Long-Term Equity Incentive Awards.”
(4) This column includes the 2023 Time Phantom Unit Awards granted to the NEOs. For more information on these awards, see “Elements of Compensation-Long-Term Equity Incentive Awards.”
(5) Amounts in this column reflect the grant date fair value of 2023 Performance Phantom Unit Awards and 2023 Time Phantom Unit Awards granted to our NEOs are determined in accordance with FASB ASC Topic 718. For more information on the assumptions underlying the valuation of these equity awards, please see Note 19 to Consolidated Financial Statements.
Outstanding Equity Awards at Fiscal Year End
The following table presents the full amount of the equity awards held by our NEOs as of December 31, 2023, which consist of time-based and performance-based phantom units granted on June 8, 2022, February 23, 2023, March 3, 2023 and May 5, 2023 under the LTIP. The awards shown on the table below were the only equity awards held by the NEOs at the end of the last fiscal year:
Performance Phantom Unit Awards
Equity Incentive
Equity Incentive
Time Phantom Unit Awards
Plan Awards
Plan Awards
Number of
Market Value of
Number of
Market Value of
Units That Have
Units That Have
Units That Have
Units That Have
Name
Not Vested (#)(1)
Not Vested ($)(2)
Not Vested (#)(3)
Not Vested ($)(2)
Eric Slifka
175,371
7,419,947
266,824
11,289,323
Gregory B. Hanson
38,551
1,631,093
60,232
2,548,416
Mark A. Romaine
83,998
3,553,955
102,438
4,334,152
Matthew Spencer
22,095
934,839
33,490
1,416,962
Sean T. Geary
30,863
1,305,814
43,330
1,833,292
(1) Reflects the following Awards:
a. 2022 Time Phantom Unit Awards, which vest over a three-year period, with one-third of the award having vested on January 1, 2023, one-third of the award having vested on January 1, 2024, and the final one-third of the award scheduled to vest on January 1, 2025.
b. 2023 Time Phantom Unit Awards granted on February 23, 2023, which vested in full on February 23, 2024.
c. 2023 Time Phantom Unit Awards granted on March 3, 2023, which vest over a three-year period, with one-third of the award having vested on January 5, 2024, one-third of the award scheduled to vest on January 5, 2025, and the final one-third of the award scheduled to vest on January 5, 2026.
d. 2023 Time Phantom Unit Awards granted on May 3, 2023, which vest in full on May 3, 2025.
(2) The market value of unvested 2022 and 2023 Performance Phantom Unit Awards and Time Phantom Unit Awards is calculated based on the closing price of our common units on December 29, 2023 (the last trading day of 2023), which was $42.31. With respect to the 2022 and 2023 Performance Phantom Unit Awards, the amount shown is based on achievement of 200% of target performance with respect to the applicable performance criteria.
(3) Reflects the target number of phantom units subject to the 2022 Performance Phantom Unit Awards and the 2023 Performance Phantom Unit Awards, which vest after a three-year performance period that consists of three one-year performance subperiods, based on the level of achievement with respect to the applicable performance criteria during such period. The number of phantom units earned could range from 0% to 200% of the target number of phantom units subject to each 2022 Performance Phantom Unit Award and each 2023 Performance Phantom Unit Award.
Units Vested in the 2023 Fiscal Year
The following table presents phantom units awarded to the NEOs that vested during the year ended December 31, 2023:
Unit Awards
Number of
Market Value of
Vested
Vested
Name
Phantom Units (#)
Phantom Units ($)(1)
Eric Slifka
23,012
797,596
Gregory B. Hanson
4,603
159,540
Mark A. Romaine
9,205
319,045
Matthew Spencer
2,959
102,559
Sean T. Geary
3,288
113,962
(1) The market values of these phantom units shown in the table above were calculated based on the price of $34.66 per common unit on December 30, 2022, the last business day before the vesting date of such phantom units.
Potential Payments upon a Change of Control or Termination
The following tables show potential payments to each of our NEOs under contracts, agreements, plans or arrangements, whether written or unwritten (including the employment agreements with each of our NEOs that were in effect as of December 31, 2023), for various scenarios involving a change of control or termination of employment of each such NEO assuming a December 31, 2023 termination date. In addition, amounts reflected in the tables below with respect to LTIP awards were calculated based on the closing price of our common units of $42.31 per unit as of December 29, 2023, which was the last day on which the market was open in 2023.
LTIP Awards.
If an officer’s employment with our general partner is terminated by our general partner without cause or by the NEO for good reason, the NEO will be deemed to have satisfied the continued employment requirement with respect to the phantom units subject to the NEO’s 2022 or 2023 Performance Phantom Unit Award and such phantom units will be eligible to become earned based on actual achievement with respect to the applicable performance criteria; provided that, if such termination without cause or for good reason occurs within the 24-month period following a change in control, the number of phantom units that become earned will be equal to the greater of (i) the target number of phantom units subject to the 2022 or 2023 Performance Phantom Unit Award, and (ii) the number of phantom units that would become earned based on actual achievement with respect to the applicable performance criteria through the date of the change in control.
If a NEO’s employment with our general partner is terminated due to death or disability, the NEO will be deemed to have satisfied the continued employment requirement with respect to a portion of the unvested phantom units subject to the NEO’s 2022 or 2023 Performance Phantom Unit Award based on the number of days that the NEO was employed between the performance period commencement date and the date of termination and such phantom units will be eligible to become earned based on actual achievement with respect to the applicable performance criteria. If a NEO’s employment with our general partner is terminated by our general partner due to retirement, the Compensation Committee will generally have sole discretion to determine whether the NEO will be deemed to have satisfied the service requirement with respect to any or all of the phantom units subject to the NEO’s 2022 or 2023 Performance Phantom Unit Award, which phantom units would then be eligible to become earned based on actual achievement with respect to the applicable performance criteria. If a NEO’s employment with our general partner is terminated by our general partner for cause or by the NEO other than for good reason, all unvested phantom units subject to such NEO’s 2022 or 2023 Performance Phantom Unit Award will immediately be forfeited.
If a NEO’s employment with our general partner is terminated by our general partner without cause or by the NEO for good reason, all unvested phantom units subject to the NEO’s 2022 or 2023 Time Phantom Unit Award will immediately vest. If a NEO’s employment with our general partner is terminated due to death or disability, a portion of the unvested phantom units subject to the NEO’s 2022 or 2023 Time Phantom Unit Award will immediately vest based on the number of days that the NEO was employed between the vesting commencement date and the date of termination. If a NEO’s employment with our general partner is terminated by our general partner due to retirement, the Compensation Committee will generally have sole discretion to determine whether any or all of the unvested phantom units subject to the NEO’s 2022 or 2023 Time Phantom Unit Award will vest or be forfeited. If a NEO’s employment with our general partner is terminated by our general partner for cause or by the NEO other than for good reason, all unvested phantom units subject to such NEO’s 2022 or 2023 Time Phantom Unit Award will immediately be forfeited. Upon vesting of each 2022 or 2023 Phantom Unit Award, phantom units will be settled in our common units unless the Compensation Committee decides, in its sole discretion, to settle such phantom units in cash or a combination of common units and cash.
LTCIP Awards. Certain of our NEOs were granted a 2022 LTCIP Award, a 2021 LTCIP Award, and a 2020 LTCIP Award. Each of these awards was accelerated and paid in December 2022. Upon a change of control event, the unvested portion of each of the LTCIP Awards held by our NEOs will become fully vested, which is reflected in the tables below.
Eric Slifka
If Mr. Slifka’s employment is terminated for any reason, he shall be paid (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, including vacation pay, that may be due to him as of the date of termination (the “Slifka Accrued Obligations”).
If Mr. Slifka’s employment is terminated by death or “Disability” (as defined in the employment agreement), he (or his estate) will be paid (i) the Slifka Accrued Obligations, plus (ii) a lump sum payment equal to his then base salary multiplied by 200%, plus (iii) an amount equal to the target incentive amount under the then applicable short-term incentive plan multiplied by 200%, plus (iv) his interests in the long-term incentive plans, including (a) the amounts due, if any, in respect of his interests in the Partnership’s long-term incentive plans, including, but not limited to the Long-Term Performance-Based Cash Incentive Plan and (b) the Long-Term Cash Incentive Plan, plus (v) group health and similar insurance premiums on behalf of his spouse and dependents, if any, for 18 months following the date of termination.
If Mr. Slifka’s employment is terminated by our general partner without “Cause” or by Mr. Slifka for reasons constituting “Constructive Termination,” each as defined in the employment agreement, he shall be paid (i) the Slifka Accrued Obligations, plus (ii) a lump sum payment equal to his then base salary multiplied by 200% (provided, however, that this multiplier shall be 300% if Mr. Slifka terminates his employment for reasons constituting Constructive Termination and such termination occurs within 12 months following a “Change in Control” (as defined in the employment agreement)), plus (iii) an amount equal to the target incentive amount under the then applicable short-term incentive plan multiplied by 200% (provided, however, that this multiplier shall be 300% if Mr. Slifka terminates his employment for reasons constituting Constructive Termination and such termination occurs within 12 months following a Change in Control), plus (iv) his interests in the long-term incentive plans, including (a) the amounts due, if any, in respect of his interests in the Partnership’s long-term incentive plans, including, but not limited to the Long-Term Performance-Based Cash Incentive Plan and (b) the Long-Term Cash Incentive Plan, plus (v) group health and similar insurance premiums on behalf of his spouse and dependents, if any, for 18 months following the date of termination.
If Mr. Slifka’s employment is terminated by our general partner for Cause, Mr. Slifka will be paid the Slifka Accrued Obligations. If Mr. Slifka’s employment agreement is not renewed by our general partner and he does not continue to serve as our general partner’s President and Chief Executive Officer following the expiration of his employment agreement (a “Non-Renewal”), he shall be paid (i) the Slifka Accrued Obligations, plus (ii) a lump sum payment equal to 200% of his then base salary, plus the performance-based and discretionary components, if any, of his STIP award for such year.
Upon a Change of Control, the unvested portions of any outstanding LTCIP Awards held by Mr. Slifka automatically shall become fully vested.
Termination by general
partner without Cause /
Constructive Termination /
Breach by general partner
Change in
No Change
With a Change
Control
Death
Disability
in Control
in Control
Nonrenewal
Name
($)
($)
($)
($)
($)
($)(1)
Eric Slifka
Severance Amount
-
5,000,000
5,000,000
5,000,000
7,500,000
5,000,000
LTIP awards (2)
-
5,848,860
5,848,860
13,064,609
13,064,609
-
LTCIP award
7,929,900
7,929,900
7,929,900
7,929,900
7,929,900
-
Fringe benefits
-
56,804
56,804
56,804
56,804
-
Life insurance benefits
-
500,000
-
-
-
-
Total
7,929,900
19,335,564
18,835,564
26,051,313
28,551,313
5,000,000
(1)
In the event of non-renewal, for purposes of this calculation, we have assumed that Mr. Slifka would receive payment of (a) 100% of the performance-based component ($1,500,000), and (b) 100% of the discretionary component associated with his 2023 STIP target amount ($1,500,000), which represent the amounts awarded to Mr. Slifka under the 2023 STIP. See the section titled “Compensation Discussion and Analysis-2023 NEO Compensation-Short-Term Incentive Plans” for more information.
(2)
With respect to the 2022 and 2023 Performance Phantom Unit Awards, it has been assumed for purposes of calculating the amounts shown that the actual level of achievement with respect to the applicable performance criteria through December 31, 2023 was equal to target performance. However, this is merely an estimate and the actual level of achievement is subject to change and may be higher or lower than target performance.
Gregory B. Hanson
If Mr. Hanson’s employment is terminated for any reason, Mr. Hanson shall be paid (i) all amounts of his base salary due and owing up through the date of termination, (ii) all earned, but unpaid, bonuses, (iii) all reimbursements of expenses appropriately and timely submitted, and (iv) any and all other amounts, including vacation pay, that may be due to his as of the date of termination (the “Hanson Accrued Obligations”).
If Mr. Hanson’s employment is terminated by death or “Disability” (as defined in the employment agreement), he (or his estate) will be paid or receive (i) the Hanson Accrued Obligations, plus (ii) a lump sum payment equal to 200% of his then base salary, plus (iii) an amount equal to 200% of the target incentive amount under the then applicable short-term incentive plan, plus (iv) the amounts due, if any, in respect of his interests in the Partnership’s long-term incentive plans, including, but not limited to the Long-Term Performance-Based Cash Incentive Plan and (b) the LTIP, plus (v) group health and similar insurance premiums on behalf of his and his spouse and dependents, if any, for 18 months following the date of termination.
If Mr. Hanson’s employment is terminated by our general partner without “Cause” or by Mr. Hanson for reasons constituting “Constructive Termination” (each quoted term as defined in the employment agreement), Mr. Hanson shall be paid (i) the Hanson Accrued Obligations, plus (ii) a lump sum payment equal to 200% of his then base salary, plus (iii) an amount equal to 200% of target incentive amount under the then applicable short-term incentive plan, plus (iv) the amounts due, if any, in respect of his interests in the Partnership’s long-term incentive plans, including, but not limited to the Long-Term Performance-Based Cash Incentive Plan and (b) the LTIP, (v) group health and similar insurance premiums on behalf of his spouse and dependents, if any, for 18 months following the date of termination, plus (vi) a potential gross-up payment in the event that any of the payments described above result in taxes being imposed on Mr. Hanson pursuant to Section 4999 of the Code.
If Mr. Hanson’s employment agreement is not renewed by our general partner and he does not continue to serve as our general partner’s Chief Financial Officer following the expiration of his employment agreement pursuant to a different employment agreement with our general partner, he shall be paid (i) the Hanson Accrued Obligations, (ii) a
lump sum payment equal to 200% of his then base salary, and (iii) the performance-based and discretionary components, if any, of his STIP award for such year.
Upon a Change of Control, the unvested portions of any outstanding LTCIP Awards held by Mr. Hanson automatically shall become fully vested.
Termination by general
partner without Cause /
Constructive Termination /
Breach by general partner
Change in
No Change
With a Change
Control
Death
Disability
in Control
in Control
Nonrenewal
Name
($)
($)
($)
($)
($)
($)(1)
Gregory B. Hanson
Severance Amount
-
1,758,000
1,758,000
1,758,000
1,758,000
1,758,000
LTIP awards
-
1,299,167
1,299,167
2,905,301
2,905,301
-
LTCIP award
823,200
823,200
823,200
823,200
823,200
-
Fringe benefits
-
56,804
56,804
56,804
56,804
-
Life insurance benefits
-
500,000
-
-
-
-
Total
823,200
4,437,171
3,937,171
5,543,305
5,543,305
1,758,000
(1)
In the event of non-renewal, for purposes of this calculation, we have assumed that Mr. Hanson would receive payment of (a) 100% of the performance-based component ($404,000), and (b) 100% of the discretionary component associated with his 2023 STIP target amount ($404,000), which represent the amounts awarded to Mr. Hanson under the 2023 STIP. See the section titled “Compensation Discussion and Analysis-2023 NEO Compensation-Short-Term Incentive Plans” for more information.
Mark A. Romaine
If Mr. Romaine’s employment is terminated for any reason, Mr. Romaine shall be paid (i) all amounts of his base salary due and owing up through the date of termination, (ii) all earned, but unpaid, bonuses, (iii) all reimbursements of expenses appropriately and timely submitted, and (iv) any and all other amounts, including vacation pay, that may be due to him as of the date of termination (the “Romaine Accrued Obligations”).
If Mr. Romaine’s employment is terminated by death or “Disability” (as defined in the employment agreement), he (or his estate) will be paid (i) the Romaine Accrued Obligations, (ii) a lump sum payment equal to 200% of his then base salary, (iii) an amount equal to 200% of the target incentive amount under the then applicable short-term incentive plan, (iv) the amounts due, if any, in respect of his interests in the Partnership’s long-term incentive plans, including, but not limited to the Long-Term Performance-Based Cash Incentive Plan and (b) the LTIP, and (v) group health and similar insurance premiums on behalf of him and his spouse and dependents, if any, for 18 months following the date of termination.
If Mr. Romaine’s employment is terminated by our general partner without “Cause” or by Mr. Romaine for reasons constituting “Constructive Termination” (each quoted term as defined in the employment agreement), Mr. Romaine shall be paid (i) the Romaine Accrued Obligations, (ii) a lump sum payment equal to 200% of his then base salary, (iii) an amount equal to 200% of target incentive amount under the then applicable short-term incentive plan, (iv) the amounts due, if any, in respect of his interests in the Partnership’s long-term incentive plans, including, but not limited to the Long-Term Performance-Based Cash Incentive Plan and (b) the LTIP, (v) group health and similar insurance premiums on behalf of his spouse and dependents, if any, for 18 months following the date of termination, and (vi) a potential gross-up payment in the event that any of the payments described above result in taxes being imposed on Mr. Romaine pursuant to Section 4999 of the Code.
If Mr. Romaine’s employment agreement is not renewed by our general partner and he does not continue to serve as our general partner’s Chief Operating Officer following the expiration of his employment agreement pursuant to a different employment agreement with our general partner, he shall be paid (i) the Romaine Accrued Obligations, plus (ii) a lump sum payment equal to 200% of his then base salary, plus (iii) the performance-based and discretionary components, if any, of his STIP award for such year.
Upon a Change of Control, the unvested portions of any outstanding LTCIP Awards held by Mr. Romaine automatically shall become fully vested.
Termination by general
partner without Cause /
Constructive Termination /
Breach by general partner
Change in
No Change
With a Change
Control
Death
Disability
in Control
in Control
Nonrenewal
Name
($)
($)
($)
($)
($)
($)(1)
Mark A. Romaine
Severance Amount
-
2,700,000
2,700,000
2,700,000
2,700,000
2,700,000
LTIP awards
-
2,562,815
2,562,815
5,721,031
5,721,031
-
LTCIP award
2,765,400
2,765,400
2,765,400
2,765,400
2,765,400
-
Fringe benefits
-
65,599
65,599
65,599
65,599
-
Life insurance benefits
-
500,000
-
-
-
-
Total
2,765,400
8,593,814
8,093,814
11,252,030
11,252,030
2,700,000
(1) In the event of non-renewal, for purposes of this calculation, we have assumed that Mr. Romaine would receive payment of (a) 100% of the performance-based component ($675,000), and (b) 100% of the discretionary component associated with his 2023 STIP target amount ($675,000), which represent the amounts awarded to Mr. Romaine under the 2023 STIP. See the section titled “Compensation Discussion and Analysis-2023 NEO Compensation-Short-Term Incentive Plans” for more information.
Matthew Spencer
If Mr. Spencer’s employment is terminated for any reason, he (or his estate, as applicable) shall be paid (i) all amounts of base salary due and owing up through the date of termination, (ii) any earned but unpaid bonus, (iii) all reimbursements of eligible business expenses, and (iv) any and all other amounts, including vacation pay, that may be due to him as of the date of termination (collectively, the “Spencer Accrued Obligations”).
If Mr. Spencer’s employment is terminated due to his death or disability, he (or his estate, as applicable) will be paid (i) the Spencer Accrued Obligations, plus (ii) a lump sum payment equal to 200% of his base salary, plus (iii) an amount equal to 200% of the target incentive amount under the then applicable short-term incentive plan, plus (iv) the amounts due, if any, in respect of his interests in the Partnership’s long-term incentive plans, including, but not limited to the Long-Term Performance-Based Cash Incentive Plan and (b) the LTIP, plus (v) group health and similar insurance premiums on behalf of him and his spouse and dependents, if any, for 18 months following the date of termination.
If Mr. Spencer’s employment is terminated by our general partner without “Cause” or by Mr. Spencer for reasons constituting “Constructive Termination” (each as defined in the employment agreement), he shall be paid (i) the Spencer Accrued Obligations, plus (ii) a lump sum payment equal to 200% of his base salary, plus (iii) an amount equal to 200% of the target incentive amount under the then applicable short-term incentive plan, plus (iv) the amounts due, if any, in respect of his interests in the Partnership’s long-term incentive plans, including, but not limited to the Long-Term Performance-Based Cash Incentive Plan and (b) the LTIP, plus (v) group health and similar insurance premiums on behalf of him and his spouse and dependents, if any, for 18 months following the date of termination, plus (vi) a potential gross-up payment in the event that any of the payments described above result in taxes being imposed on Mr. Spencer pursuant to Section 4999 of the Code.
If Mr. Spencer’s employment agreement is not renewed by our general partner and he does not continue to serve as our general partner’s Chief Accounting Officer following the expiration of his employment agreement pursuant to a different employment agreement with our general partner, the employment agreement provides that he shall be paid (i) the Spencer Accrued Obligations, (ii) a lump sum payment equal to 200% of his then base salary, and (iii) the performance-based and discretionary components, if any, of his STIP award for such year.
Upon a Change of Control, the unvested portions of any outstanding LTCIP Awards held by Mr. Spencer automatically shall become fully vested.
Termination by general
partner without Cause /
Constructive Termination /
Breach by general partner
Change in
No Change
With a Change
Control
Death
Disability
in Control
in Control
Nonrenewal
Name
($)
($)
($)
($)
($)
($)(1)
Matthew Spencer
Severance Amount
-
1,138,000
1,138,000
1,138,000
1,138,000
1,138,000
LTIP awards
-
771,421
771,421
1,643,320
1,643,320
-
LTCIP award
1,132,800
1,132,800
1,132,800
1,132,800
1,132,800
-
Fringe benefits
-
51,046
51,046
51,046
51,046
-
Life insurance benefits
-
500,000
-
-
-
-
Total
1,132,800
3,593,267
3,093,267
3,965,166
3,965,166
1,138,000
(1)(1) In the event of non-renewal, for purposes of this calculation, we have assumed that Mr. Spencer would receive payment of (a) 100% of the performance-based component ($244,000), and (b) 100% of the discretionary component associated with his 2023 STIP target amount ($244,000), which represent the amounts awarded to Mr. Spencer under the 2023 STIP. See the section titled “Compensation Discussion and Analysis-2023 NEO Compensation-Short-Term Incentive Plans” for more information.
Sean T. Geary
If Mr. Geary’s employment is terminated for any reason, Mr. Geary shall be paid (i) all amounts of his base salary due and owing up through the date of termination, (ii) all earned, but unpaid, bonuses, (iii) all reimbursements of expenses appropriately and timely submitted, and (iv) any and all other amounts, including vacation pay, that may be due to his as of the date of termination (the “Geary Accrued Obligations”).
If Mr. Geary’s employment is terminated by death or “Disability” (as defined in the employment agreement), he (or his estate) will be paid or receive (i) the Geary Accrued Obligations, plus (ii) a lump sum payment equal to 200% of his then base salary, plus (iii) an amount equal to 200% of the target incentive amount under the then applicable short-term incentive plan, plus (iv) the amounts due, if any, in respect of his interests in the Partnership’s long-term incentive plans, including, but not limited to the Long-Term Performance-Based Cash Incentive Plan and (b) the LTIP, plus (v) group health and similar insurance premiums on behalf of his and his spouse and dependents, if any, for 18 months following the date of termination.
If Mr. Geary’s employment is terminated by our general partner without “Cause” or by Mr. Geary for reasons constituting “Constructive Termination” (each quoted term as defined in the employment agreement), Mr. Geary shall be paid (i) the Geary Accrued Obligations, plus (ii) a lump sum payment equal to 200% of his then base salary, plus (iii) an amount equal to 200% of target incentive amount under the then applicable short-term incentive plan, plus (iv) the amounts due, if any, in respect of his interests in the Partnership’s long-term incentive plans, including, but not limited to the Long-Term Performance-Based Cash Incentive Plan and (b) the LTIP, (v) group health and similar insurance premiums on behalf of his spouse and dependents, if any, for 18 months following the date of termination, plus (vi) a potential gross-up payment in the event that any of the payments described above result in taxes being imposed on Mr. Geary pursuant to Section 4999 of the Code.
If Mr. Geary’s employment agreement is not renewed by our general partner and he does not continue to serve as our general partner’s Chief Legal Officer following the expiration of his employment agreement pursuant to a different employment agreement with our general partner, he shall be paid (i) the Geary Accrued Obligations, (ii) a lump sum payment equal to 200% of his then base salary, and (iii) the performance-based and discretionary components, if any, of his STIP award for such year.
Upon a Change of Control, the unvested portions of any outstanding LTCIP Awards held by Mr. Geary automatically shall become fully vested.
Termination by general
partner without Cause /
Constructive Termination /
Breach by general partner
Change in
No Change
With a Change
Control
Death
Disability
in Control
in Control
Nonrenewal
Name
($)
($)
($)
($)
($)
($)(1)
Sean T. Geary
Severance Amount
-
1,476,000
1,476,000
1,476,000
1,476,000
1,476,000
LTIP awards
-
993,466
993,466
2,222,460
2,222,460
-
LTCIP award
549,900
549,900
549,900
549,900
549,900
-
Fringe benefits
-
56,804
56,804
56,804
56,804
-
Life insurance benefits
-
500,000
-
-
-
-
Total
549,900
3,576,170
3,076,170
4,305,164
4,305,164
1,476,000
(1)
In the event of non-renewal, for purposes of this calculation, we have assumed that Mr. Geary would receive payment of (a) 100% of the performance-based component ($328,000), and (b) 100% of the discretionary component associated with his 2023 STIP target amount ($328,000), which represent the amounts awarded to Mr. Geary under the 2023 STIP. See the section titled “Compensation Discussion and Analysis-2023 NEO Compensation-Short-Term Incentive Plans” for more information.
Other Benefits
Pension Benefits
The table below sets forth information regarding the present value as of December 31, 2023 of the accumulated benefits of our NEOs under the Global Partners LP Pension Plan.
Pension Benefits at December 31, 2023
Number of Years
Present Value of
Payments During
Name
Plan Name
Credited Service (#)
Accumulated Benefit ($)
Last Fiscal Year ($)
Eric Slifka
(1)
584,264
-
Gregory B. Hanson
-
-
-
-
Mark A. Romaine
(1)
204,763
-
Matthew Spencer
-
-
-
-
Sean T. Geary
(1)
70,816
-
(1) Global Partners LP Pension Plan
Global Partners LP Pension Plan
Effective December 31, 2009, the Global Partners LP Pension Plan (the “Global Pension Plan”) was amended to freeze participation in and benefit accruals under the Global 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 Global Pension Plan were eligible to participate in the Global Pension Plan. An employee is fully vested in benefits under the Global Pension Plan after completing five years of service or upon termination due to death or disability. Certain employees are entitled to a supplemental benefit that vested over five years with 20% vesting on each December 31 beginning in 2010 and lasting through 2014. When an employee retires at age 65 or, if later, upon reaching five years' service, the employee can elect to receive a monthly annuity or an equivalent lump sum payment. An 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 Global 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.
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 equivalent rights pursuant to any long-term incentive plan and any cash payable in lieu of group healthcare coverage. Settlement of obligations is expected to be completed in the second half of 2024.
Compensation of Directors
The following table sets forth (i) certain information concerning the compensation earned by our directors in 2023, and (ii) the aggregate amounts of stock awards and option awards, if any, held by each director at the end of 2023:
Fees Earned
or Paid in
Unit
Name
Cash ($)
Awards ($)(2)
Total ($)
Richard Slifka
250,000
-
250,000
Eric Slifka (1)
-
-
-
Robert J. McCool
295,000
124,996
419,996
Jaime Pereira
295,000
124,996
419,996
John T. Hailer
295,000
124,996
419,996
Robert W. Owens
295,000
124,996
419,996
Clare McGrory
237,500
104,180
341,680
(1) Mr. Slifka, as an executive officer of our general partner, is otherwise compensated for his services and therefore does not receive any separate compensation for his service as director.
(2) Amounts reported in this column reflect the grant date fair value, calculated in accordance with FASB ASC Topic 718, of 3,729 phantom units granted to Messrs. McCool, Pereira, Hailer and Owens, and 3,108 phantom units granted to Ms. McGrory on August 22, 2023. Each award of phantom units cliff vested in full on January 5, 2024. As of December 31, 2023, each of Messrs. McCool, Pereira, Hailer and Owens held a total of 3,729 unvested phantom units, and Ms. McGrory held a total of 3,108 unvested phantom units.
Employees of our general partner who also serve as directors do not receive additional compensation. In 2023, directors who are not employees of our general partner (1) received a $250,000 annual cash retainer, and (2) are eligible to participate in the LTIP. In addition, the chair of the (a) audit committee received a $25,000 annual cash retainer; (b) conflicts committee received a $20,000 annual cash retainer; and (c) Compensation Committee received a $20,000 annual cash retainer. Each member of the (x) audit committee received a $15,000 annual cash retainer; (y) conflicts committee received a $10,000 annual cash retainer; and (z) conflict committee received a $10,000 annual cash retainer.
Each director also is reimbursed for out-of-pocket expenses in connection with attending meetings of the board of directors or committees.
On August 22, 2023, Messrs. McCool, Hailer, Owens and Pereira were each granted an award of 3,729 phantom units with DERs and Ms. McGrory was granted an award of 3,108 phantom units with DERs. Each of these awards cliff vested as to 100% of the phantom units on January 5, 2024.
On October 22, 2021, Messrs. McCool, Hailer and Owens were awarded LTCIP grants in the amounts of
$155,000, $155,000 and $40,000, respectively, in respect of services rendered in 2020. Each such LTCIP award will fully vest as of July 10, 2024, subject to continued service as a director through such date.
On October 5, 2020, each of Messrs. McCool and Hailer was awarded an LTCIP grant in the amount of $128,000 in respect of services rendered in 2019. On December 9, 2022, the Compensation Committee authorized the acceleration of the LTCIP awards, which were paid on December 22, 2022.
On August 7, 2019, Messrs. McCool and Hailer were awarded LTCIP grants in the amounts of $160,000 and $80,000, respectively, in respect of services rendered in 2018. The LTCIP awards fully vested as of August 10, 2022.
On March 6, 2019, Mr. McCool was awarded an LTCIP grant in the amount of $125,000 in respect of services rendered in 2017. The LTCIP award fully vested as of March 1, 2022.
Each director will be fully indemnified by us for actions associated with being a director to the extent permitted under Delaware law.
Pay Ratio Disclosure
As required by Section 953(b) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 402(u) of Regulation S-K, we are providing the following information about the relationship of the annual total compensation of our employees and the annual total compensation of Mr. Eric Slifka, our CEO.
For 2023, our last completed fiscal year:
● The median of the annual total compensation of our employees (other than the CEO) was $36,358.
● The annual total compensation of our CEO, as reported in the Summary Compensation Table above, was $15,589,457.
● Based on this information, for 2023, the ratio of the annual total compensation of our CEO to the median of the annual total compensation of all employees was reasonably estimated to be 429 to 1.
To put this into context, approximately 78% of our employee population consists of convenience store employees, approximately 40% of whom are employed on a part-time basis. Our part-time employees who work less than thirty hours per week receive (i) wages, and (ii) if eligible, sick time and/or 401(k) benefits, but are not eligible for vacation or other fringe benefits. In comparison, if we were to only look at our non-convenience store employee population, the median employee would be employed on a full-time basis, with a total annual compensation of $88,816 in 2023. The ratio of the annual total compensation of our CEO to this median employee was reasonably estimated to be 176 to 1.
To identify the median of the annual total compensation of all of our employees, as well as to determine the annual total compensation of our median employee and our CEO, we took the following steps:
● We determined that, as of December 31, 2023, our employee population consisted of approximately 5,067 individuals with all of these individuals located in the United States. This population consisted of our full-time, part-time, and temporary (including seasonal) employees. We selected December 31, 2023 as identification date for determining our median employee because it enabled us to make such identification in a reasonably efficient and economic manner.
● We used a consistently applied compensation measure to identify our median employee by comparing the amount of salary or wages, bonuses and equity awards, if any, reflected in our payroll records as reported to the Internal Revenue Service on Form W-2 for 2023.
● We identified our median employee by consistently applying this compensation measure to all of our employees included in our analysis. Since all of our employees, including our CEO, are located in the
United States, we did not make any cost of living adjustments in identifying the median employee.
● After we identified our median employee, we combined all of the elements of such employee’s compensation for the 2023 year in accordance with the requirements of Item 402(c)(2)(x) of Regulation S-K, resulting in annual total compensation of $88,816.
● With respect to the annual total compensation of our CEO, we used the amount reported in the “Total” column of the Summary Compensation Table above.

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.
The following table sets forth as of February 22, 2024 the beneficial ownership of common units representing limited partner interests in Global Partners LP held by certain beneficial owners of more than five percent (5%) of the common units, by each director and named executive officer of Global GP LLC, the general partner of Global Partners LP (“General Partner”) and by all directors and executive officers of our General Partner as a group:
Percentage
Common
of Common
Units
Units
Beneficially
Beneficially
Name of Beneficial Owner (1)
Owned
Owned
Alerian MLP ETF (2)
4,431,751
13.0
%
Eric Slifka (3)(4)(5)(6)
3,554,585
10.5
%
Invesco Ltd. (7)
3,164,640
9.3
%
Richard Slifka (6)(8)(9)
2,717,165
8.0
%
Alfred A. Slifka 1990 Trust Under Article II-A
1,871,676
5.5
%
Global GP LLC (6)
39,719
*
Mark Romaine
108,929
*
Gregory B. Hanson
21,242
*
Matthew Spencer
20,245
*
Sean T. Geary
19,895
*
Robert J. McCool
45,018
*
John T. Hailer
8,409
*
Jaime Pereira
10,909
*
Robert W. Owens
8,409
*
Clare McGrory
3,908
*
All directors and executive officers as a group (11 persons)
6,478,995
19.1
%
* Less than 1%
(1)
The address for each person or entity listed other than ALPS Advisors, Inc. / Alerian MLP ETF and Invesco Ltd. is P.O. Box 9161, 800 South Street, Suite 500, Waltham, Massachusetts 02454-9161.
(2)
According to a Schedule 13G filed on February 5, 2024, each of ALPS Advisors, Inc. and Alerian MLP ETF reported shared voting and dispositive power of 4,431,751 common units as of December 31, 2023. The address for Alerian MLP ETF and its investment advisor, ALPS Advisors, Inc., is 1290 Broadway, Suite 1000, Denver, CO 80203.
(3)
Eric Slifka has sole voting and investment power with respect to the common units owned by Larea Holdings LLC. Eric Slifka may, therefore, be deemed to beneficially own the common units held by Larea Holdings LLC.
(4)
Includes common units held in certain family trusts for the benefit of Eric Slifka’s children for which Eric Slifka is the sole trustee. Eric Slifka may, therefore, be deemed to beneficially own the common units held by these family trusts.
(5)
The trustees of the Alfred A. Slifka 1990 Trust Under Article II-A are Eric Slifka and his two siblings. Eric Slifka has been delegated sole voting and investment authority over the common units owned by the Alfred A. Slifka 1990 Trust Under Article II-A, and therefore may be deemed to beneficially own those common units.
(6)
Purchased by our general partner for the purpose of assisting us in meeting our anticipated obligations to deliver common units under our Long-Term Incentive Plan to officers, directors and employees. Since Eric Slifka and Richard Slifka have sole voting authority for all of the members of Global GP LLC, none of which own 50% or more of the membership interests in Global GP LLC, Eric Slifka and Richard Slifka may be deemed to beneficially own the common units owned by Global GP LLC.
(7)
According to a Schedule 13G/A filed on January 10, 2024, Invesco Ltd. reported sole voting and dispositive power of 3,164,640 common units as of December 29, 2023. The address for Invesco Ltd. is 1331 Spring Street NW, Suite 2500, Atlanta, GA 30309.
(8)
Richard Slifka has sole voting and investment power with respect to the common units owned by Chelsea Terminal Limited Partnership and, therefore, may be deemed to beneficially own, the common units owned by Chelsea Terminal Limited Partnership.
(9)
Richard Slifka is the trustee of a voting trust with sole voting and investment power with respect to common units owned by Larea Holdings II LLC. Richard Slifka may, therefore, be deemed to beneficially own, the common units held by Larea Holdings II LLC.
Equity Compensation Plan Table
The following table summarizes information about our equity compensation plans as of December 31, 2023:
Number of securities
Number of Securities
remaining available for
to be issued
Weighted average
future issuance under
upon exercise of
exercise price of
equity compensation plans
outstanding options,
outstanding options,
(excluding securities
Plan Category
warrants and rights
warrants and rights
reflected in column (a))
(a)
(b)
(c)
Equity compensation plans approved by security holders
875,216
(1)
-
2,307,427
Equity compensation plans not approved by security holders
-
-
-
Total
875,216
(1)
-
2,307,427
(1) The 875,216 unvested award units as of December 31, 2023 include: (i) 86,125 units for the time-based 2022 NEO LTIP awards, (ii) 123,961 for the time-based 2023 NEO LTIP awards, (iii) 258,386 units for the 2022 NEO Performance LTIP Awards, (iv) 247,928 units for the 2023 NEO Performance LTIP Awards, (v) 34,803 units for the February 23, 2023 supplemental NEO time-based bonus awards, (vi) 105,989 units for the May 3, 2023 supplemental NEO time-based awards, and (vii) 18,024 units for the August 22, 2023 time-based independent director awards. The numbers of units reserved for the 2022 and 2023 NEO Performance LTIP Awards are calculated using 200% of the 129,193 and 123,964 target phantom units respectively granted for these awards.

---

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Item 13. Certain Relationships and Related Transactions, and Director Independence.
As of February 22, 2024, affiliates of our general partner, including directors and executive officers of our general partner, owned 6,478,995 common units representing 19.1% of the common units. In addition, our general partner owns a 0.67% general partner interest in us.
Affiliates of the Slifka family own 100% of the ownership interests in our general partner. Our general partner is controlled by Richard Slifka and Eric Slifka, through their beneficial ownership of entities that own membership interests in our general partner.
Max Slifka, the son of Eric Slifka, our President, Chief Executive Officer and Vice Chair, is an employee of Global GP LLC. During our fiscal year ended December 31, 2023, his total compensation earned was approximately $227,000.
Steven McCool, the son of Robert J. McCool, one of our independent directors, is an employee of Global GP LLC. During our fiscal year ended December 31, 2023, his total compensation earned was approximately $211,000.
Aaron Slifka, the nephew of Eric Slifka, our President, Chief Executive Officer and Vice Chairman, is an employee of Global GP LLC. During our fiscal year ended December 31, 2023, his total compensation earned was approximately $130,160.
Eric Slifka owns a 20% interest in an entity which leases real property located in Vineyard Haven, Massachusetts to our subsidiary, Drake Petroleum Company, Inc., for the operation of a gasoline station and convenience store. We paid this entity aggregate payments totaling approximately $188,604 during calendar year 2023.
Operational Stage
Distributions of available cash to our general partner and its affiliates
We will generally make cash distributions of 99.33% to the common unitholders, including affiliates of our general partner (including directors and executive officers of our general partner), as the holders of an aggregate of 6,478,995 common units and 0.67% to our general partner. In addition, if distributions exceed the minimum quarterly distribution and other higher target levels, our general partner will be entitled to increasing percentages of the distributions, up to 48.67% of the distributions above the highest target level.
On February 14, 2023, we made a distribution payment of $1.5725 per unit to the common unitholders, consisting of a $0.6350 quarterly distribution and a $0.9375 one-time special distribution. Our general partner waived its incentive distribution rights with respect to the one-time special component of the distribution.
Assuming we have sufficient available cash to pay the full minimum quarterly distribution on all of our outstanding common units for four quarters, our general partner and its affiliates, including directors and executive officers of our general partner, would receive an annual distribution of approximately $12.0 million on their common units and $0.4 million on the 0.67% general partner interest.
Payments to our general partner and its affiliates
Our general partner does not receive a 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. Our partnership agreement provides that our general partner determines the amount of these expenses.
Withdrawal or removal of our general partner
If our general partner withdraws or is removed, its general partner interest and its incentive distribution rights will either be sold to the new general partner for cash or converted into common units, in each case for an amount equal to the fair market value of those interests.
Liquidation Stage
Liquidation
Upon our liquidation, the partners, including our general partner, will be entitled to receive liquidating distributions according to their particular capital account balances.
Noncompetition
We are a party to an omnibus agreement with Mr. Richard Slifka and our general partner that addresses the agreement of Mr. Richard Slifka not to compete with us and to cause his affiliates not to compete with us under certain circumstances. The omnibus agreement also provided for certain environmental indemnity obligations of Global Petroleum Corp. and certain of its affiliates, which indemnity obligations have either expired or been resolved. In connection with our acquisition of Alliance Energy LLC in 2012, Richard Slifka, Chairman of our general partner, entered into a business opportunity agreement with our general partner containing noncompetition provisions which are broader than those contained in the omnibus agreement in order to encompass our expanded lines of business since 2005.
Pursuant to the omnibus agreement and the business opportunity agreement, Richard Slifka agreed, for himself and his respective affiliates, not to engage in, acquire or invest in any of the following businesses: (1) the wholesale and/or retail marketing, sale, distribution and transportation (other than transportation by truck) of refined petroleum products, crude oil, ethanol, propane and biofuels; (2) the storage of refined petroleum products and/or any of the other products identified in (1) or asphalt in connection with any of the activities described in (1); (3) bunkering; and (4) such other activities in which the Partnership, and its direct or indirect subsidiaries, or any of their businesses are engaged or, to the knowledge of Richard Slifka, are planning to become engaged. These noncompetition obligations survive under the omnibus agreement for so long as Richard Slifka, Eric Slifka and/or any of their respective affiliates, individually or as part of a group, control our general partner, and under the business opportunity agreement indefinitely.
Pursuant to Eric Slifka’s employment agreement with our general partner, Eric Slifka agreed, for himself and his affiliates, to not work (as an employee, consultant, advisor, director or otherwise), engage in, acquire or invest in any of the following businesses: (1) the wholesale or retail marketing, sale, distribution and transportation of refined petroleum products, crude oil, renewable fuels (including ethanol and biofuels), and natural gas liquids (including ethane, butane, propane and condensates); (2) the storage of refined petroleum products and/or any of the other products identified in clause (1) above in connection with any of the activities described in said clause (1); (3) the retail sale of convenience store items and sundries and related food service, whether or not related to the retail sale of refined petroleum products including, without limitation, gasoline; (4) bunkering; and (5) any other business in which the general partner or its affiliates (a) becomes engaged during the period that Eric Slifka is employed by the general partner or any of its affiliates, or (b) is preparing to become engaged as of the time that Eric Slifka’s employment with the general partner or any of its affiliates ends and, with respect to parts (a) and (b) of this clause (5), Eric Slifka has participated in or obtained Confidential Information about such business or anticipated business. Eric Slifka further agreed to not directly or indirectly solicit any employees, contractors, vendors, suppliers or customers of the general partner or any of its affiliates to cease to be employed by or otherwise do business with the general partner or any of its affiliates, or to reduce the same. The foregoing noncompetition and nonsolicitation restrictions may be waived only by the conflicts committee of the general partner’s board of directors. Eric Slifka’s noncompetition and nonsolicitation obligations survive for one year following the termination of his employment for any reason other than death or the termination of his employment by the general partner without Cause (as defined in his employment agreement). In consideration for his noncompetition obligations, the general partner shall pay to Eric Slifka a total payment equal to fifty percent (50%) of his highest annualized Base Salary (as defined in his employment agreement) within the two years preceding termination; provided, that the general partner shall have no obligation to make such payment in the event that Eric Slifka breaches any of the terms of his noncompetition obligations.
In addition, Eric Slifka’s employment agreement includes, and Eric Slifka agreed to, a confidentiality provision, which generally will continue for two years following Eric Slifka’s termination of employment.
Services Agreement
We are party to a services agreement effective as of January 1, 2021 with various Slifka-owned entities and their shareholders and/or members (the “Slifka Entities Services Agreement”), pursuant to which we provide certain tax, accounting, treasury, and legal support services and such Slifka entities pay us an annual services fee of $20,000. We believe the terms of this agreement are at least as favorable as could have been obtained from unaffiliated third parties. The Slifka Entities Services Agreement is for an indefinite term, and any party may terminate some or all of the services thereunder upon 90 days’ advance written notice.
Revere Terminal Disposition
On January 14, 2015, we acquired our terminal located on Boston Harbor in Revere, Massachusetts (the “Revere Terminal”) from affiliates of the Slifka family (the “Initial Sellers”) for a purchase price of approximately $23.7 million.
On June 28, 2022, we sold the Revere Terminal to Revere MA Owner LLC (the “Revere Buyer”), a third party not affiliated with us, for a purchase price of $150.0 million in cash. In connection with closing under the purchase agreement between us and the Revere Buyer, we entered into a leaseback agreement with the Revere Buyer pursuant to which we lease back key infrastructure at the Revere Terminal, including certain tanks, dock access rights, and loading rack infrastructure, to allow us to continue business operations at the Revere Terminal. The term of the leaseback agreement, including all renewal options exercisable at our election, could extend through September 30, 2039.
Pursuant to the terms of the purchase agreement entered into with the Initial Sellers in 2015, the Initial Sellers are entitled to an amount equal to fifty percent of the net proceeds (as defined in the 2015 purchase agreement) (the “Initial Sellers Share”) from the sale of the Revere Terminal to the Revere Buyer. At the time of the 2022 closing, the preliminary calculation of the Initial Sellers Share was approximately $44.3 million, which amount is subject to future revisions. To date, there have been no payments of additional net proceeds from the 2022 sale of the Revere Terminal relating to the final calculation of the Initial Sellers Share, as adjusted for such shared expenses and potential operating losses or profits. The final calculation of the Initial Sellers Share, including a sharing of any additional expenses in order to satisfy outstanding obligations under our current government storage contract at the Revere Terminal and potential operating losses or profits relating to the operation of the Revere Terminal during the initial leaseback term, will occur upon the expiration of such storage contract.
Please read Note 18, “Related-Party Transactions,” of Notes to Consolidated Financial Statements included elsewhere in this report for additional information on the sale of the Revere Terminal.
Policies Relating to Conflicts of Interest
Conflicts of interest exist and may arise in the future as a result of the relationships between our general partner and its affiliates, on the one hand, and us and our unaffiliated limited partners, on the other hand. The directors and officers of our general partner have fiduciary duties to manage our general partner in a manner beneficial to its owners. At the same time, our general partner has a fiduciary duty to manage us in a manner beneficial to our unitholders and us. Our partnership agreement modifies and limits our general partner’s fiduciary duties to unitholders. Our partnership agreement also restricts the remedies available to unitholders for actions taken by our general partner that might otherwise constitute breaches of fiduciary duty under applicable Delaware law. The Delaware Revised Uniform Limited Partnership Act provides that Delaware limited partnerships may, in their partnership agreements, expand, restrict or eliminate the fiduciary duties otherwise owed by a general partner to limited partners and the partnership.
Under our partnership agreement, whenever a conflict arises between our general partner or its affiliates, on the one hand, and us or any other partner, on the other, our general partner will resolve that conflict. Our general partner will
not be in breach of its obligations under our partnership agreement or its duties to us or our unitholders if the resolution of the conflict is:
● approved by the conflicts committee of our general partner, although our general partner is not obligated to seek such approval;
● approved by the vote of a majority of the outstanding common units, excluding any common units owned by our general partner or any of its affiliates;
● on terms no less favorable to us than those generally being provided to or available from unaffiliated third parties; or
● fair and reasonable to us, taking into account the totality of the relationships between the parties involved, including other transactions that may be particularly favorable or advantageous to us.
Our general partner may, but is not required to, seek the approval of such resolution from the conflicts committee of the board of directors of our general partner. If our general partner does not seek approval from the conflicts committee and its board of directors determines that the resolution or course of action taken with respect to the conflict of interest satisfies either of the standards set forth in the third and fourth bullet points above, then it will be presumed that, in making its decision, the board acted in good faith, and in any proceeding brought by or on behalf of us or any limited partner of ours, the person bringing or prosecuting such proceeding will have the burden of overcoming such presumption. Unless the resolution of a conflict is specifically provided for in our partnership agreement, our general partner or the conflicts committee may consider any factors it determines in good faith to consider when resolving a conflict. When our partnership agreement requires someone to act in good faith, it requires that person to reasonably believe that he is acting in the best interests of the partnership, unless the context otherwise requires.
Director Independence
Please read Part III, Item 10, “Directors, Executive Officers and Corporate Governance” for information regarding director independence.

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
Item 14. Principal Accounting Fees and Services.
The audit committee of the board of directors of Global GP LLC selected Ernst & Young LLP, Boston, Massachusetts (PCAOB ID: 42), Independent Registered Public Accounting Firm, to audit the books, records and accounts of Global Partners LP for the 2023 and 2022 calendar years. The audit committee’s charter, which is available on our website at www.globalp.com, requires the audit committee to approve in advance all audit and non-audit services to be provided by our independent registered public accounting firm. All services reported in the audit, audit-related, tax and all other fees categories below were approved by the audit committee.
Pre-approved fees to Ernst & Young LLP for the fiscal years ended December 31, 2023 and 2022 were as follows (in thousands):
Audit Fees (1)
$
4,425
$
4,113
Audit-Related Fees (2)
Tax Fees (3)
1,060
1,062
All other fees (4)
Total
$
5,614
$
5,356
(1) Represents fees for professional services provided primarily in connection with the audits of our annual financial statements and reviews of our quarterly financial statements. Audit fees also included Ernst & Young’s audits of the effectiveness of our internal control over financial reporting at December 31, 2023 and 2022.
(2) Represents fees for assurance and related services and consists primarily of audits of employee benefit plans.
(3) Tax fees included tax planning and tax return preparation.
(4) Represents fees for an accounting research tool subscription.
PART IV

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
Item 15. Exhibits and Financial Statement Schedules.
(a) The following documents are included with the filing of this Annual Report:
1. Financial statements-See “Index to Financial Statements” on page.
2. Financial statement schedules-Financial statement schedules have been omitted as they are not required, not applicable or otherwise included in the consolidated financial statements or notes thereto.
3. Exhibits-The following is a list of exhibits required by Item 601 of Registration S-K to be filed as part of this Annual Report.
Exhibit
Number
Description
2.1#
-
Agreement of Purchase and Sale dated as of January 14, 2015 between Global Revco Dock, L.L.C, Global Revco Terminal, L.L.C., Global South Terminal, L.L.C., Global Petroleum Corp. and Global Companies LLC (incorporated herein by reference to Exhibit 2.1 to the Current Report on Form 8-K filed on January 21, 2015).
2.2
-
Purchase and Sale Agreement, dated as of November 24, 2021, by and between Global Companies LLC, as Seller, and Revere MA Owner LLC, as Buyer (incorporated herein by reference to Exhibit 2.2 to the Annual Report on Form 10-K filed on February 28, 2022).
2.3#
-
Purchase and Sale Agreement, dated as of December 9, 2020, by and between Consumers Petroleum of Connecticut, Incorporated, Putling Greens I, LLC, Wheels of CT, Inc., CPCI, LLC and Wiehl Estate, LLC, as collective Seller, and Global Partners LP, as Buyer (incorporated herein by reference to Exhibit 2.1 to the Current Report on Form 8-K filed on January 31, 2022).
2.4#
-
Equity Purchase Agreement, dated as of December 15, 2022, by and between Gulf Oil Limited Partnership, as Seller, and Global Partners LP, as Buyer (incorporated herein by reference to Exhibit 2.4 to the Annual Report on Form 10-K filed on February 27, 2023).
2.5#
-
Asset Purchase Agreement, dated as of November 8, 2023, by and among Motiva Enterprises LLC, as seller, Global Operating LLC, as purchaser and Global Partners LP, as guarantor (incorporated herein by reference to Exhibit 2.1 to the Current Report on Form 8-K filed on December 21, 2023).
3.1
-
Certificate of Limited Partnership of Global Partners LP (incorporated by reference to Exhibit 3.1 to the Registration Statement on Form S-1 filed on May 10, 2005).
3.2
-
Fifth Amended and Restated Agreement of Limited Partnership of Global Partners LP dated as of March 24, 2021 (incorporated herein by reference to Exhibit 3.1 to the Current Report on Form 8-K filed on March 24, 2021).
4.1
-
Registration Rights Agreement, dated March 1, 2012, by and among Global Partners LP and AE Holdings Corp. (incorporated herein by reference to Exhibit 4.1 to the Current Report on Form 8-K filed on March 7, 2012).
4.2*
-
Description of Common Units registered under Section 12 of the Exchange Act.
4.3*
-
Description of Series A Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units registered under Section 12 of the Exchange Act.
4.4*
-
Description of 9.50% Series B Fixed Rate Cumulative Redeemable Perpetual Preferred Units registered under Section 12 of the Exchange Act.
4.5
-
Indenture, dated as of July 31, 2019, among the Issuers, the Guarantors and Deutsche Bank Trust Company Americas, as trustee (incorporated herein by reference to Exhibit 4.1 to the Current Report on Form 8-K filed on July 31, 2019).
4.6
-
Indenture, dated October 7, 2020, among the Issuers, the Guarantors and Regions Bank, as trustee (incorporated herein by reference to Exhibit 4.1 to the Current Report on Form 8-K filed on October 8, 2020).
4.7
-
First Supplemental Indenture, dated as of October 28, 2020, among the Issuers, the Guarantors and Regions Bank, as trustee (incorporated herein by reference to Exhibit 4.3 to the Registration Statement on Form S-4 filed on December 16, 2020).
4.8
-
First Supplemental Indenture, dated as of October 28, 2020, among the Issuers, the Guarantors and Regions Bank, as successor to Deutsche Bank Trust Company Americas, as trustee (incorporated herein by reference to Exhibit 4.5 to the Registration Statement on Form S-4 filed on December 16, 2020).
4.9
-
Indenture, dated January 18, 2024, among the Issuers, the Guarantors and Regions Bank, as trustee (incorporated herein by reference to Exhibit 4.1 to the Current Report on Form 8-K filed on January 18, 2024).
10.1
-
Omnibus Agreement, dated October 4, 2005, by and among Global Petroleum Corp., Montello Oil Corporation, Global Revco Dock, L.L.C., Global Revco Terminal, L.L.C., Global South Terminal, L.L.C., Sandwich Terminal, L.L.C., Chelsea Terminal Limited Partnership, Global GP LLC, Global Partners LP, Global Operating LLC, Alfred A. Slifka, Richard Slifka and Eric Slifka (incorporated herein by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on October 11, 2005).
10.2††
-
Brand Fee Agreement, dated September 3, 2010, between ExxonMobil Oil Corporation and Global Companies LLC (incorporated herein by reference to Exhibit 10.2 to the Quarterly Report on Form 10-Q filed on November 5, 2020).
10.3
-
Business Opportunity Agreement dated March 1, 2012, by and among Alfred A. Slifka, Richard Slifka and Global Partners LP (incorporated herein by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on March 7, 2012).
10.4˄
-
Global Partners LP Long-Term Incentive Plan (as Amended and Restated Effective June 22, 2012 and further amended as of June 22, 2022) (incorporated herein by reference to Exhibit 10.4 to the Annual Report on Form 10-K filed on February 27, 2023).
10.5˄
-
Form of Phantom Unit Agreement (Cash Settlement) (incorporated herein by reference to Exhibit 10.1 to the Quarterly Report on Form 10-Q filed on November 6, 2015).
10.6#
-
Third Amended and Restated Credit Agreement, dated as of April 25, 2017, among Global Operating LLC, Global Companies LLC, Global Montello Group Corp., Glen Hes Corp., Chelsea Sandwich LLC, GLP Finance Corp., Global Energy Marketing LLC, Global CNG LLC, Alliance Energy LLC, Cascade Kelly Holdings LLC and Warren Equities, Inc. as borrowers, Bank of America, N.A., as Administrative Agent, Swing Line Lender, Alternative Currency Fronting Lender and L/C Issuer, JPMorgan Chase Bank, N.A. as an L/C Issuer, JPMorgan Chase Bank, N.A. and Wells Fargo Bank, N.A. as Co-Syndication Agents, Citizens Bank, N.A., Societe Generale, BNP Paribas and The Bank of Tokyo-Mitsubishi UFJ, Ltd. NY Branch as Co-Documentation Agents, and Merrill Lynch, Pierce, Fenner & Smith Incorporated, JPMorgan Chase Bank, N.A., Wells Fargo Securities, LLC, Citizens Bank N.A., Societe Generale, BNP Paribas, and The Bank of Tokyo-Mitsubishi UFJ, Ltd. NY Branch as Joint Lead Arrangers and Joint Book Managers (incorporated herein by reference to Exhibit 10.1 to the Quarterly Report on Form 10-Q filed on May 5, 2023).
10.7˄
-
Global Partners LP 2018 Long-Term Cash Incentive Plan (incorporated herein by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on October 12, 2018).
10.8
-
First Amendment to Third Amended and Restated Credit Agreement dated September 10, 2018 (incorporated herein by reference to Exhibit 10.1 to the Quarterly Report on Form 10-Q filed on November 8, 2018).
10.9
-
Second Amendment to Third Amended and Restated Credit Agreement dated September 10, 2018 (incorporated herein by reference to Exhibit 10.2 to the Quarterly Report on Form 10-Q filed on November 8, 2018).
10.10
-
Third Amendment to Third Amended and Restated Credit Agreement and First Amendment to Third Amended and Restated Security Agreement, dated as of April 19, 2019 (incorporated herein by reference to Exhibit 10.1 to the Quarterly Report on Form 10-Q filed on May 9, 2019).
10.11
-
Fourth Amendment to Third Amended and Restated Credit Agreement, dated as of May 7, 2020 (incorporated herein by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on May 8, 2020).
10.12
-
Fifth Amendment to Third Amended and Restated Credit Agreement, dated as of May 5, 2021 (incorporated herein by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on May 6, 2021).
10.13
-
Slifka Entities Services Agreement, effective as of January 1, 2021 (incorporated herein by reference to Exhibit 10.2 to the Quarterly Report on Form 10-Q filed on May 7, 2021).
10.14
-
Sixth Amendment to Third Amended and Restated Credit Agreement, dated March 9, 2022 (incorporated herein by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on March 15, 2022).
10.15
-
Seventh Amendment to Third Amended and Restated Credit Agreement, dated March 30, 2022 (incorporated herein by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on April 5, 2022).
10.16˄
-
Employment Agreement by and between Global GP LLC and Eric Slifka (incorporated herein by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on June 13, 2022).
10.17˄
-
Employment Agreement by and between Global GP LLC and Gregory B. Hanson (incorporated herein by reference to Exhibit 10.2 to the Current Report on Form 8-K filed on June 13, 2022).
10.18˄
-
Employment Agreement by and between Global GP LLC and Mark Romaine (incorporated herein by reference to Exhibit 10.3 to the Current Report on Form 8-K filed on June 13, 2022).
10.19˄
-
Employment Agreement by and between Global GP LLC and Matthew Spencer (incorporated herein by reference to Exhibit 10.4 to the Current Report on Form 8-K filed on June 13, 2022).
10.20˄
-
Employment Agreement by and between Global GP LLC and Sean T. Geary (incorporated herein by reference to Exhibit 10.6 to the Current Report on Form 8-K filed on June 13, 2022).
10.21˄
-
Form of Phantom Unit Award Agreement for Executive Officers under Global Partners LP Long-Term Incentive Plan (incorporated herein by reference to Exhibit 10.7 to the Quarterly Report on Form 10-Q filed on August 5, 2022).
10.22˄
-
Form of Performance Phantom Unit Award Agreement for Executive Officers under Global Partners LP Long-Term Incentive Plan (incorporated herein by reference to Exhibit 10.8 to the Quarterly Report on Form 10-Q filed on August 5, 2022).
10.23˄
-
Form of Phantom Unit Award Agreement for Independent Directors under Global Partners LP Long-Term Incentive Plan (incorporated herein by reference to Exhibit 10.1 to the Quarterly Report on Form 10-Q filed on November 4, 2022).
10.24
-
Eighth Amendment to Third Amended and Restated Credit Agreement, dated February 2, 2023 (incorporated herein by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on February 7, 2023).
10.25#
-
Ninth Amendment to Third Amended and Restated Credit Agreement and Joinder, dated May 2, 2023 (incorporated herein by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on May 3, 2023).
10.26
-
Purchase Agreement, dated January 3, 2024, among the Issuers, the General Partner, the Guarantors and the Initial Purchasers (incorporated herein by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on January 4, 2024).
10.27*˄
-
Global Partners LP 2018 Long-Term Cash Incentive Plan Award Agreement (including Restrictive Covenants).
10.28*˄
-
Global Partners LP 2018 Long-Term Cash Incentive Plan Award Agreement (with Non-Competition Agreement).
21.1*
-
List of Subsidiaries of Global Partners LP.
22.1*
-
List of Subsidiary Guarantors and Co-Issuer of Global Partners LP
23.1*
-
Consent of Ernst & Young LLP.
31.1*
-
Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Global GP LLC, general partner of Global Partners LP.
31.2*
-
Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Global GP LLC, general partner of Global Partners LP.
32.1†
-
Section 1350 Certification of Chief Executive Officer of Global GP LLC, general partner of Global Partners LP.
32.2†
-
Section 1350 Certification of Chief Financial Officer of Global GP LLC, general partner of Global Partners LP.
97.1*
-
Global Partners LP Clawback Policy.
101.INS*
-
Inline XBRL Instance Document (the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document).
101.SCH*
-
Inline XBRL Taxonomy Extension Schema Document.
101.CAL*
-
Inline XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF*
-
Inline XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB*
-
Inline XBRL Taxonomy Extension Labels Linkbase Document.
101.PRE*
-
Inline XBRL Taxonomy Extension Presentation Linkbase Document.
104*
-
Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).
* Filed herewith.
˄ Management contract or compensatory plan or arrangement.
# Schedules and similar attachments have been omitted pursuant to Item 601(a)(5) of Regulation S-K. The Partnership undertakes to furnish supplementally copies of any of the omitted schedules and exhibits upon request by the U.S. Securities and Exchange Commission.
† Not deemed “filed” for purposes of Section 18 of the Securities Exchange Act of 1934 or otherwise subject to the liability of that section.
†† Portions of this exhibit have been omitted pursuant to Item 601(b)(10)(iv) of Regulation S-K.