Global Partners (GLP) 10-Q 9 May 16 2016 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2016	May. 05, 2016
Document and Entity Information
Entity Registrant Name	GLOBAL PARTNERS LP
Entity Central Index Key	1,323,468
Document Type	10-Q
Document Period End Date	Mar. 31, 2016
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		33,995,563
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q1

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 17,069	$ 1,116
Accounts receivable, net	308,359	311,354
Accounts receivable-affiliates	3,482	2,578
Inventories	402,872	388,952
Brokerage margin deposits	38,855	31,327
Derivate assets	43,397	66,099
Prepaid expenses and other current assets	73,467	65,609
Total current assets	887,501	867,035
Property and equipment, net	1,217,659	1,242,683
Intangible assets, net	72,871	75,694
Goodwill	435,369	435,369
Other assets	42,038	42,894
Total assets	2,655,438	2,663,675
Current liabilities:
Accounts payable	255,798	303,781
Working capital revolving credit facility-current portion	185,200	98,100
Environmental liabilities-current portion	5,345	5,350
Trustee taxes payable	88,005	95,264
Accrued expenses and other current liabilities	44,584	60,328
Derivative liabilities	25,923	31,911
Total current liabilities	604,855	594,734
Working capital revolving credit facility-less current portion	150,000	150,000
Revolving credit facility	275,100	269,000
Senior notes	657,213	656,564
Environmental liabilities-less current portion	66,795	67,883
Financing obligation	89,845	89,790
Deferred tax liabilities	83,280	84,836
Other long-term liabilities	56,665	56,884
Total liabilities	1,983,753	1,969,691
Global Partners LP equity:
Common unitholders 33,995,563 units issued and 33,517,503 outstanding at March 31, 2016 and 33,995,563 units issued and 33,506,844 outstanding at December 31, 2015)	635,645	657,071
General partner interest (0.67% interest with 230,303 equivalent units outstanding at March 31, 2016 and December 31, 2015)	(1,341)	(1,188)
Accumulated other comprehensive loss	(7,765)	(8,094)
Total Global Partners LP equity	626,539	647,789
Noncontrolling interest	45,146	46,195
Total partners' equity	671,685	693,984
Total liabilities and partners' equity	$ 2,655,438	$ 2,663,675

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Mar. 31, 2016	Dec. 31, 2015
CONSOLIDATED BALANCE SHEETS
Common unitholders, units issued	33,995,563	33,995,563
Common unitholders, units outstanding	33,517,503	33,506,844
General partner interest (as a percent)	0.67%	0.67%
General partner interest, equivalent units outstanding	230,303	230,303

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
CONSOLIDATED STATEMENTS OF OPERATIONS
Sales	$ 1,750,812	$ 2,979,116
Cost of sales	1,620,753	2,810,558
Gross profit	130,059	168,558
Costs and operating expenses:
Selling, general and administrative expenses	34,984	48,786
Operating expenses	72,236	68,656
Amortization expense	2,509	5,341
Loss on sale and disposition of assets and impairment charges	6,105	437
Total costs and operating expenses	115,834	123,220
Operating income	14,225	45,338
Interest expense	(22,980)	(13,963)
(Loss) income before income tax benefit (expense)	(8,755)	31,375
Income tax benefit (expense)	920	(966)
Net (loss) income	(7,835)	30,409
Net loss attributable to noncontrolling interest	811	6
Net (loss) income attributable to Global Partners LP	(7,024)	30,415
Less: General partner’s interest in net (loss) income, including incentive distribution rights	(47)	2,179
Limited partners’ interest in net (loss) income	$ (6,977)	$ 28,236
Basic net (loss) income per limited partner unit	$ (0.21)	$ 0.92
Diluted net (loss) income per limited partner unit	$ (0.21)	$ 0.92
Basic weighted average limited partner units outstanding (in units)	33,517	30,599
Diluted weighted average limited partner units outstanding (in units)	33,517	30,712

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
Net (loss) income	$ (7,835)	$ 30,409
Other comprehensive income:
Change in fair value of cash flow hedges	261	183
Change in pension liability	68	91
Total other comprehensive income	329	274
Comprehensive (loss) income	(7,506)	30,683
Comprehensive loss attributable to noncontrolling interest	811	6
Comprehensive (loss) income attributable to Global Partners LP	$ (6,695)	$ 30,689

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Cash flows from operating activities
Net (loss) income	$ (7,835)	$ 30,409
Adjustments to reconcile net (loss) income to net cash used in operating activities:
Depreciation and amortization	28,669	28,472
Amortization of deferred financing fees	1,429	1,459
Amortization of leasehold interests	313
Amortization of senior notes discount	343	179
Bad debt expense	50	35
Unit-based compensation expense	1,075	945
Write-off of financing fees	1,828
Loss on sale and disposition of assets and impairment charges	6,105	437
Changes in operating assets and liabilities, excluding net assets acquired
Accounts receivable	2,945	52,186
Accounts receivable - affiliate	(904)	58
Inventories	(13,920)	(15,614)
Broker margin deposits	(7,528)	(16,539)
Prepaid expenses, all other current assets and other assets	(9,952)	10,157
Accounts payable	(47,982)	(170,646)
Trustee taxes payable	(7,259)	(21,099)
Change in derivatives	16,714	16,121
Accrued expenses, all other current liabilities and other long-term liabilities	(17,607)	(30,475)
Net cash used in operating activities	(53,516)	(113,915)
Cash flows from investing activities
Acquisitions		(405,478)
Capital expenditures	(16,451)	(14,045)
Proceeds from sale of property and equipment	8,588	1,044
Net cash used in investing activities	(7,863)	(418,479)
Cash flows from financing activities
Net borrowings from working capital revolving credit facility	87,100	175,400
Net borrowings from revolving credit facility	6,100	383,600
Payments on line of credit		(700)
Repurchase of common units		(2,442)
Noncontrolling interest capital contribution	357	1,880
Distribution to noncontrolling interest	(595)	(1,880)
Distributions to partners	(15,630)	(22,357)
Net cash provided by financing activities	77,332	533,501
Cash and cash equivalents
Increase in cash and cash equivalents	15,953	1,107
Cash and cash equivalents at beginning of period	1,116	5,238
Cash and cash equivalents at end of period	17,069	6,345
Supplemental information
Cash paid during the period for interest	$ 17,232	$ 18,860

CONSOLIDATED STATEMENTS OF PART

CONSOLIDATED STATEMENTS OF PARTNERS' EQUITY - 3 months ended Mar. 31, 2016 - USD ($) $ in Thousands	Common Unitholders	General Partner Interest	Accumulated Other Comprehensive Loss	Noncontrolling Interest	Total
Balance, beginning of period at Dec. 31, 2015	$ 657,071	$ (1,188)	$ (8,094)	$ 46,195	$ 693,984
Increase (Decrease) in Partners' Capital
Net (loss) income	(6,977)	(47)		(811)	(7,835)
Noncontrolling interest capital contribution				357	357
Distribution to noncontrolling interest				(595)	(595)
Other comprehensive income			329		329
Unit-based compensation	1,075				1,075
Distributions to partners	(15,723)	(106)			(15,829)
Dividends on repurchased units	199				199
Balance, end of period at Mar. 31, 2016	$ 635,645	$ (1,341)	$ (7,765)	$ 45,146	$ 671,685

Business Combinations

Business Combinations	3 Months Ended
	Mar. 31, 2016
Business Combinations
Business Combinations	Note 2. Business Combinations 2015 Acquisitions Warren Equities, Inc. — On January 7, 2015, the Partnership acquired, through GMG, 100% of the equity interests in Warren, one of the largest independent marketers of petroleum products in the Northeast, from The Warren Alpert Foundation. The acquisition included 147 company-owned Xtra Mart convenience stores and related fuel operations, 53 commission agent locations and fuel supply rights for approximately 330 dealers. The acquired properties are located in the Northeast, Maryland and Virginia. The purchase price, inclusive of post-closing adjustments, was approximately $381.8 million, including working capital. The acquisition was funded with borrowings under the Partnership’s credit facility and with proceeds from its December 2014 public offering of 3,565,000 common units. The acquisition was accounted for using the purchase method of accounting in accordance with the Financial Accounting Standards Board’s (“FASB”) guidance regarding business combinations. The Partnership’s financial statements include the results of operations of Warren subsequent to the acquisition date. In connection with the acquisition of Warren, the Partnership recorded acquisition costs of approximately $4.4 million for the three months ended March 31, 2015 which are included in selling, general and administrative expenses in the accompanying consolidated statement of operations. Additionally, in January 2015 and subsequent to the acquisition date, the Partnership recorded a restructuring charge of approximately $2.3 million, which is included in selling, general and administrative expenses in the accompanying consolidated statement of operations for the three months ended March 31, 2015. Approximately $0.5 million of the restructuring charge was paid during the three months ended March 31, 2015, and the remaining balance of $1.8 million was paid during the year ended December 31, 2015. Revere Terminal — On January 14, 2015, through the Partnership’s wholly owned subsidiary, Global Companies LLC, the Partnership acquired the Revere Terminal located in Boston Harbor in Revere, Massachusetts from GPC, a privately held affiliate of the Partnership, and related entities for a purchase price of $23.7 million. The acquisition includes contingent consideration which would be payable under specific circumstances involving a subsequent sale of the property during the eight years following the acquisition. The contingent consideration was estimated to be $0 as of the acquisition date as the Partnership concluded that the sale of the terminal for non-petroleum use within the eight years following the acquisition is not probable. The Partnership financed the transaction with borrowings under its revolving credit facility. In connection with the Revere Terminal transaction, the pre-existing terminal storage rental and throughput agreement between the Partnership and GPC was terminated. The acquisition was accounted for using the purchase method of accounting in accordance with the FASB’s guidance regarding business combinations. As the acquisition transitioned the Revere Terminal from a formerly leased facility to an owned facility, the transaction did not have a material impact on the Partnership’s consolidated financial statements. Capitol Petroleum Group —On June 1, 2015, the Partnership acquired 97 primarily Mobil and Exxon branded owned or leased retail gasoline stations and seven dealer supply contracts in New York City and Prince George’s County, Maryland, along with certain related supply and franchise agreements and third-party leases and other assets associated with the operations from Liberty Petroleum Realty, LLC, East River Petroleum Realty, LLC, Big Apple Petroleum Realty, LLC, White Oak Petroleum, LLC, Anacostia Realty, LLC, Mount Vernon Petroleum Realty, LLC and DAG Realty, LLC (collectively, “Capitol Petroleum Group”). The purchase price was approximately $155.7 million. The acquisition was financed with borrowings under the Partnership’s revolving credit facility. The acquisition was accounted for using the purchase method of accounting in accordance with the FASB’s guidance regarding business combinations. The Partnership’s financial statements include the results of operations of Capitol subsequent to the acquisition date. No acquisition costs were recorded in connection with the acquisition of Capitol for the three months ended March 31, 2015. Supplemental Pro Forma Information — Revenues and net income not included in the Partnership’s consolidated operating results for Warren from January 1, 2015 through January 7, 2015, the acquisition date, were immaterial. Accordingly, the supplemental pro forma information for the three months ended March 31, 2015 is consistent with the amounts reported in the accompanying consolidated statement of operations for the three months ended March 31, 2015. The following unaudited pro forma information presents the consolidated results of operations of the Partnership as if the acquisition of Capitol occurred on January 1, 2015 (in thousands, except per unit data): Three Months Ended March 31, 2015 Sales $ Net income attributable to Global Partners LP $ Net income per limited partner unit, basic and diluted $

Net (Loss) Income Per Limited P

Net (Loss) Income Per Limited Partner Unit	3 Months Ended
	Mar. 31, 2016
Net (Loss) Income Per Limited Partner Unit
Net (Loss) Income Per Limited Partner Unit	Note 3. Net (Loss) Income Per Limited Partner Unit Under the Partnership’s partnership agreement, for any quarterly period, the incentive distribution rights (“IDRs”) participate in net income only to the extent of the amount of cash distributions actually declared, thereby excluding the IDRs from participating in the Partnership’s undistributed net income or losses. Accordingly, the Partnership’s undistributed net income or losses is assumed to be allocated to the common unitholders, or limited partners’ interest, and to the General Partner’s general partner interest. Common units outstanding as reported in the accompanying consolidated financial statements at March 31, 2016 and December 31, 2015 excluded 478,060 and 488,719 common units, respectively, held on behalf of the Partnership pursuant to its repurchase program (see Note 13) . These units are not deemed outstanding for purposes of calculating net income per limited partner unit (basic and diluted). The following table provides a reconciliation of net (loss) income and the assumed allocation of net (loss) income to the limited partners’ interest for purposes of computing net (loss) income per limited partner unit for the three months ended March 31, 2016 and 2015 (in thousands, except per unit data): Three Months Ended March 31, 2016 Three Months Ended March 31, 2015 Limited General Limited General Partner Partner Partner Partner Numerator: Total Interest Interest IDRs Total Interest Interest IDRs Net (loss) income attributable to Global Partners LP (1) $ $ $ $ — $ $ $ $ — Declared distribution $ $ $ $ — $ $ $ $ Assumed allocation of undistributed net (loss) income — — Assumed allocation of net (loss) income $ $ $ $ — $ $ $ $ Denominator: Basic weighted average limited partner units outstanding Dilutive effect of phantom units — Diluted weighted average limited partner units outstanding Basic net (loss) income per limited partner unit $ $ Diluted net (loss) income per limited partner unit (2) $ $ (1) As a result of the June 2015 issuance of 3,000,000 common units, the general partner interest was reduced to 0.67% for three months ended March 31, 2016 from 0.74% for the three months ended March 31, 2015 . (2) Basic units were used to calculate diluted net income per limited partner unit for the three months ended March 31, 2016, as using the effects of phantom units would have an anti-dilutive effect on net income per limited partner unit. During 2016, the board of directors of the General Partner declared the following quarterly cash distribution: Per Unit Cash Distribution Declared for the Cash Distribution Declaration Date Distribution Declared Quarterly Period Ended April 26, 2016 $ March 31, 2016 See Note 8, “Partners’ Equity and Cash Distributions” for further information.

Inventories

Inventories	3 Months Ended
	Mar. 31, 2016
Inventories
Inventories	Note 4. Inventories The Partnership hedges substantially all of its petroleum and ethanol inventory using a variety of instruments, primarily exchange-traded futures contracts. These futures contracts are entered into when inventory is purchased and are either designated as fair value hedges against the inventory on a specific barrel basis for inventories qualifying for fair value hedge accounting or not designated and maintained as economic hedges against certain inventory of the Partnership on a specific barrel basis. Changes in fair value of these futures contracts, as well as the offsetting change in fair value on the hedged inventory, is recognized in earnings as an increase or decrease in cost of sales. All hedged inventory designated in a fair value hedge relationship is valued using the lower of cost, as determined by specific identification, or market, as determined at the product level. All petroleum and ethanol inventory not designated in a fair value hedging relationship is carried at the lower of historical cost, on a first-in, first-out basis, or market. Convenience store inventory and Renewable Identification Numbers (“RINs”) inventory are carried at the lower of historical cost or market. Inventories consisted of the following (in thousands): March 31, December 31, 2016 2015 Distillates: home heating oil, diesel and kerosene $ $ Gasoline Gasoline blendstocks Crude oil Residual oil Propane and other Renewable identification numbers (RINs) Convenience store inventory Total $ $ In addition to its own inventory, the Partnership has exchange agreements for petroleum products and ethanol with unrelated third-party suppliers, whereby it may draw inventory from these other suppliers and suppliers may draw inventory from the Partnership. Positive exchange balances are accounted for as accounts receivable and amounted to $9.3 million and $3.4 million at March 31, 2016 and December 31, 2015 , respectively. Negative exchange balances are accounted for as accounts payable and amounted to $4.1 million and $12.1 million at March 31, 2016 and December 31, 2015 , respectively. Exchange transactions are valued using current carrying costs.

Derivative Financial Instrument

Derivative Financial Instruments	3 Months Ended
	Mar. 31, 2016
Derivative Financial Instruments
Derivative Financial Instruments	Note 5. Derivative Financial Instruments The Partnership principally uses derivative instruments, which include regulated exchange-traded futures and options contracts (collectively, “exchange-traded derivatives”) and physical and financial forwards and over-the-counter (“OTC”) swaps (collectively, “OTC derivatives”), to reduce its exposure to unfavorable changes in commodity market prices and interest rates. The Partnership uses these exchange-traded and OTC derivatives to hedge commodity price risk associated with its inventory and undelivered forward commodity purchases and sales (“physical forward contracts”) and uses interest rate swap instruments to reduce its exposure to fluctuations in interest rates associated with the Partnership’s credit facilities. The Partnership accounts for derivative transactions in accordance with ASC 815, “Derivatives and Hedging,” and recognizes derivatives instruments as either assets or liabilities in the consolidated balance sheet and measures those instruments at fair value. The changes in fair value of the derivative transactions are presented currently in earnings, unless specific hedge accounting criteria are met. The fair value of exchange-traded derivative transactions reflects amounts that would be received from or paid to the Partnership’s brokers upon liquidation of these contracts. The fair value of these exchange-traded derivative transactions are presented on a net basis, offset by the cash balances on deposit with the Partnership’s brokers, presented as brokerage margin deposits in the consolidated balance sheets. The fair value of OTC derivative transactions reflects amounts that would be received from or paid to a third party upon liquidation of these contracts under current market conditions. The fair value of these OTC derivative transactions is presented on a gross basis as derivative assets or derivative liabilities in the consolidated balance sheets, unless a legal right of offset exists. The presentation of the change in fair value of the Partnership’s exchange-traded derivatives and OTC derivative transactions depends on the intended use of the derivative and the resulting designation. The following table summarizes the notional values related to the Partnership’s derivative instruments outstanding at March 31, 2016 : Units (1) Unit of Measure Exchange-Traded Derivatives Long Thousands of barrels Short Thousands of barrels OTC Derivatives (Petroleum/Ethanol) Long Thousands of barrels Short Thousands of barrels OTC Derivatives (Natural Gas) Long Thousands of decatherms Short Thousands of decatherms Interest Rate Swaps $ Millions of U.S. dollars Interest Rate Cap $ Millions of U.S. dollars Foreign Currency Derivatives Open Forward Exchange Contracts (2) $ Millions of Canadian dollars $ Millions of U.S. dollars (1) Number of open positions and gross notional values do not measure the Partnership’s risk of loss, quantify risk or represent assets or liabilities of the Partnership, but rather indicate the relative size of the derivative instruments and are used in the calculation of the amounts to be exchanged between counterparties upon settlements. (2) All-in forward rate Canadian dollars $1.2973 to USD $1.00. Derivatives Accounted for as Hedges The Partnership utilizes fair value hedges and cash flow hedges to hedge commodity price risk and interest rate risk. Fair Value Hedges Derivatives designated as fair value hedges are used to hedge price risk in commodity inventories and principally include exchange-traded futures contracts that are entered into in the ordinary course of business. For a derivative instrument designated as a fair value hedge, the gain or loss is recognized in earnings in the period of change together with the offsetting change in fair value on the hedged item of the risk being hedged. Gains and losses related to fair value hedges are recognized in the consolidated statement of operations through cost of sales. These futures contracts are settled on a daily basis by the Partnership through brokerage margin accounts. The Partnership’s fair value hedges include exchange-traded futures contracts and OTC derivative contracts that are hedges against inventory with specific futures contracts matched to specific barrels. The change in fair value of these futures contracts and the change in fair value of the underlying inventory generally provide an offset to each other in the consolidated statement of operations. The following table presents the gains and losses from the Partnership’s derivative instruments involved in fair value hedging relationships recognized in the consolidated statements of operations for the three months ended March 31, 2016 and 2015 (in thousands): Statement of Gain (Loss) Three Months Ended Recognized in Income on March 31, Derivatives 2016 2015 Derivatives in fair value hedging relationship Exchange-traded futures contracts and OTC derivative contracts for petroleum commodity products Cost of sales $ $ Hedged items in fair value hedge relationship Physical inventory Cost of sales $ $ Cash Flow Hedges Derivatives designated as cash flow hedges are used to hedge interest rate risk from fluctuations in interest rates and may include various interest rate derivative instruments entered into with major financial institutions. For a derivative instrument being designated as a cash flow hedge, the effective portion of the derivative gain or loss is initially reported as a component of other comprehensive income (loss) and subsequently reclassified into the consolidated statement of operations through interest expense in the same period that the hedged exposure affects earnings. The ineffective portion is recognized in the consolidated statement of operations immediately. The Partnership’s cash flow hedges currently include interest rate swaps and an interest rate cap that are hedges of variability in forecasted interest payments due to changes in the interest rate on LIBOR-based borrowings, a summary of which includes the following designations: · In October 2009, the Partnership executed an interest rate swap with a major financial institution. The swap, which became effective on May 16, 2011 and expires on May 16, 2016, is used to hedge the variability in interest payments due to changes in the one month LIBOR swap curve with respect to $100.0 million of one-month LIBOR -based borrowings on the credit facility at a fixed rate of 3.93% . · In April 2011, the Partnership executed an interest rate cap with a major financial institution. The rate cap, which became effective on April 13, 2011 and expired on April 13, 2016, was used to hedge the variability in interest payments due to changes in the one-month LIBOR rate above 5.5% with respect to $100.0 million of one-month LIBOR-based borrowings on the credit facility. · In September 2013, the Partnership executed an interest rate swap with a major financial institution. The swap, which became effective on October 2, 2013 and expires on October 2, 2018, is used to hedge the variability in cash flows in monthly interest payments due to changes in the one month LIBOR swap curve with respect to $100.0 million of one-month LIBOR -based borrowings on the credit facility at a fixed rate of 1.819% . In the aggregate, these hedging instruments have historically been effective in hedging the variability in interest payments due to changes in the one month LIBOR swap curve or rate with respect to $300.0 million of one month LIBOR based borrowings on the credit facility. In June 2014 and as a result of the issuance of the Partnership’s $375.0 million aggregate principal amount of its 6.25% senior notes due 2022 (see Note 6), the Partnership determined that maintaining an excess of $300.0 million in principal of outstanding floating-rate debt was no longer probable. Therefore, the Partnership elected to de-designate its interest rate cap and discontinued the related hedge accounting for this instrument. Accordingly, at March 31, 2016 , the Partnership had in place two interest rate swap agreements which are hedging $200.0 million of variable rate debt, both of which continue to be accounted for as cash flow hedges. The interest rate cap, which expired on April 13, 2016, was not in a hedging relationship for the three months ended March 31, 2016 and 2015. Accordingly, all changes in fair value of this instrument subsequent to the date of de-designation were recorded in the consolidated statement of operations through interest expense. The following table presents the amount of gains and losses from the Partnership’s derivative instruments designated in cash flow hedging relationships recognized in the consolidated statements of operations and partners’ equity for the three months ended March 31, 2016 and 2015 (in thousands): Amount of Gain (Loss) Location of Gain (Loss) Amount of Gain (Loss) Recognized in Reclassified from Reclassified from Other Comprehensive Accumulated Other Other Comprehensive Income on Derivatives Comprehensive Income into Income into Income (Effective Portion) Income (Effective Portion) (Effective Portion) Three Months Ended Three Months Ended Derivatives Designated in March 31, March 31, Cash Flow Hedging Relationship 2016 2015 2016 2015 Interest rate swaps $ $ Interest expense $ — $ — The amount of gain (loss) recognized in income as ineffectiveness for derivatives designated in cash flow hedging relationships was $0 for the three months ended March 31, 2016 and 2015 . Derivatives Not Accounted for as Hedges The Partnership utilizes petroleum and ethanol commodity contracts, natural gas commodity contracts and foreign currency derivatives to hedge price and currency risk in certain commodity inventories and physical forward contracts. Petroleum and Ethanol Commodity Contracts The Partnership uses exchange-traded derivative contracts to hedge price risk in certain commodity inventories which do not qualify for fair value hedge accounting or are not designated by the Partnership as fair value hedges. Additionally, the Partnership uses exchange-traded derivative contracts, and occasionally financial forward and OTC swap agreements, to hedge commodity price exposure associated with its physical forward contracts which are not designated by the Partnership as cash flow hedges. These physical forward contracts, to the extent they meet the definition of a derivative, are considered OTC physical forwards and are reflected as derivative assets or derivative liabilities in the consolidated balance sheet. The related exchange-traded derivative contracts (and financial forward and OTC swaps, if applicable) are also reflected as brokerage margin deposits (and derivative assets or derivative liabilities, if applicable) in the consolidated balance sheet, thereby creating an economic hedge. Changes in fair value of these derivative instruments are recognized in the consolidated statement of operations through cost of sales. These exchange-traded derivatives are settled on a daily basis by the Partnership through brokerage margin accounts. While the Partnership seeks to maintain a position that is substantially balanced within its commodity product purchase and sale activities, it 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 the business, such as weather conditions. In connection with managing these positions, the Partnership is aided by maintaining a constant presence in the marketplace. The Partnership also engages 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 fair value of these derivative instruments are recognized in the consolidated statement of operations through cost of sales. Natural Gas Commodity Contracts The Partnership uses physical forward purchase contracts to hedge price risk associated with the marketing and selling of natural gas to third-party users. These physical forward purchase commitments for natural gas are typically executed when the Partnership enters into physical forward sale commitments of product for physical delivery. These physical forward contracts, to the extent they meet the definition of a derivative, are reflected as derivative assets and derivative liabilities in the consolidated balance sheet. Changes in fair value of the forward purchase and sale commitments are recognized in the consolidated statement of operations through cost of sales. Foreign Currency Contracts The Partnership uses forward foreign currency contracts to hedge certain foreign denominated (Canadian) commodity product purchases. These forward foreign currency contracts are not designated by the Partnership as hedges and are reflected as prepaid expenses and other current assets or accrued expenses and other current liabilities in the consolidated balance sheets. Changes in fair values of these forward foreign currency contracts are reflected in cost of sales. The following table presents the gains and losses from the Partnership’s derivative instruments not involved in a hedging relationship recognized in the consolidated statements of operations for the three months ended March 31, 2016 and 2015 (in thousands): Statement of Gain (Loss) Three Months Ended Derivatives not designated as Recognized in March 31, hedging instruments Income on Derivatives 2016 2015 Commodity contracts Cost of sales $ $ Forward foreign currency contracts Cost of sales Total $ $ Margin Deposits All of the Partnership’s exchange-traded derivative contracts (designated and not designated) are transacted through clearing brokers. The Partnership deposits initial margin with the clearing brokers, along with variation margin, which is paid or received on a daily basis, based upon the changes in fair value of open futures contracts and settlement of closed futures contracts. Cash balances on deposit with clearing brokers and open equity are presented on a net basis within brokerage margin deposits in the consolidated balance sheets. Commodity Contracts and Other Derivative Activity The Partnership’s commodity contract derivatives and other derivative activity include: (i) exchange-traded derivative contracts that are hedges against inventory and either do not qualify for hedge accounting or are not designated in a hedge accounting relationship, (ii) exchange-traded derivative contracts used to economically hedge physical forward contracts, (iii) financial forward and OTC swap agreements used to economically hedge physical forward contracts and (iv) the derivative instruments under the Partnership’s controlled trading program. The Partnership does not take the normal purchase and sale exemption available under ASC 815 for its physical forward contracts. The following table presents the fair value of each classification of the Partnership’s derivative instruments and its location in the consolidated balance sheets at March 31, 2016 and December 31, 2015 (in thousands): March 31, 2016 Derivatives Derivatives Not Designated as Designated as Hedging Hedging Balance Sheet Location Instruments Instruments Total Asset Derivatives: Exchange-traded derivative contracts Broker margin deposits $ $ $ Forward derivative contracts (1) Derivative assets — Total asset derivatives $ $ $ Liability Derivatives: Exchange-traded derivative contracts Broker margin deposits $ $ $ Forward derivative contracts (1) Derivative liabilities Forward foreign currency contracts Accrued expenses and other current liabilities — Interest rate swap contracts Other long-term liabilities — Total liability derivatives $ $ $ December 31, 2015 Derivatives Derivatives Not Designated as Designated as Hedging Hedging Balance Sheet Location Instruments Instruments Total Asset Derivatives: Exchange-traded derivative contracts Broker margin deposits $ $ $ Forward derivative contracts (1) Derivative assets — Forward foreign currency contracts Other assets — Total asset derivatives $ $ $ Liability Derivatives: Forward derivative contracts (1) Derivative liabilities $ — $ $ Interest rate swap contracts Other long-term liabilities — Total liability derivatives $ — $ $ (1) Forward derivative contracts include the Partnership’s petroleum and ethanol physical and financial forwards and OTC swaps. Credit Risk The Partnership’s derivative financial instruments do not contain credit risk related to other contingent features that could cause accelerated payments when these financial instruments are in net liability positions. The Partnership is exposed to credit loss in the event of nonperformance by counterparties to the Partnership’s exchange-traded and OTC derivative contracts, but the Partnership has no current reason to expect any material nonperformance by any of these counterparties. Exchange-traded derivative contracts, the primary derivative instrument utilized by the Partnership, are traded on regulated exchanges, greatly reducing potential credit risks. The Partnership utilizes primarily three clearing brokers, all major financial institutions, for all New York Mercantile Exchange (“NYMEX”), Chicago Mercantile Exchange (“CME”) and Intercontinental Exchange (“ICE”) derivative transactions and the right of offset exists with these financial institutions under master netting agreements. Accordingly, the fair value of the Partnership’s exchange-traded derivative instruments is presented on a net basis in the consolidated balance sheets. Exposure on OTC derivatives is limited to the amount of the recorded fair value as of the balance sheet dates.

Debt

Debt	3 Months Ended
	Mar. 31, 2016
Debt
Debt	Note 6. Debt Credit Agreement Certain subsidiaries of the Partnership, as borrowers, and the Partnership and certain of its subsidiaries, as guarantors, have a senior secured credit facility (the “Credit Agreement”). On February 24, 2016, the Partnership entered into the fifth amendment to the Credit Agreement (the “Fifth Amendment”) which reflects, among other things, the Partnership’s voluntary election to reduce its working capital revolving credit facility from $1.0 billion to $900.0 million and its revolving credit facility from $775.0 million to $575.0 million, for a total available commitment of $1.475 billion. The Credit Agreement will mature on April 30, 2018. As of March 31, 2016 , the two facilities under the Credit Agreement included: · 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 $900.0 million; and · a $575.0 million revolving credit facility to be used for acquisitions, joint ventures, capital expenditures, letters of credit and general corporate purposes. In addition, the Credit Agreement has an accordion feature whereby the Partnership may request on the same terms and conditions of its then-existing credit agreement, provided no Event of Default (as defined in the Credit Agreement) then exists, an increase to the working capital revolving credit facility , the revolving credit facility , or both, by up to another $300.0 million, in the aggregate, for a total credit facility of up to $1.775 billion. The Partnership cannot provide assurance, however, that its lending group will agree to fund any request by the Partnership for additional amounts in excess of the total available commitments of $1.475 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) $50.0 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 $1.475 billion. Pursuant to the Credit Agreement, and in connection with any agreement by and between a Loan Party and a Lender (as such terms are defined in the Credit Agreement) or affiliate thereof (an “AR Buyer”), a Loan Party may sell certain of its accounts receivables to an AR Buyer. The Loan Parties are permitted to sell or transfer any account receivable to an AR Buyer only pursuant to the provisions provided in the Credit Agreement. To date, the level of receivables sold has not been significant, and the Partnership has accounted for such transfers as sales pursuant to ASC 860, “Transfers and Servicing.” Due to the short term nature of the receivables sold to date, no servicing obligation has been recorded because it would have been de minimis. Availability under the working capital revolving credit facility is subject to a borrowing base which is redetermined from time to time based on specific advance rates on eligible current assets. Under the Credit Agreement, borrowings under the working capital revolving credit facility cannot exceed the then current borrowing base. Availability under the borrowing base may be affected by events beyond the Partnership’s control, such as changes in petroleum product prices, collection cycles, counterparty performance, advance rates and limits and general economic conditions. These and other events could require the Partnership to seek waivers or amendments of covenants or alternative sources of financing or to reduce expenditures. The Partnership can provide no assurance that such waivers, amendments or alternative financing could be obtained or, if obtained, would be on terms acceptable to the Partnership. Borrowings under the working capital revolving credit facility bear interest at (1) the Eurocurrency rate plus 2.00% to 2.50% , (2) the cost of funds rate plus 2.00% to 2.50% , or (3) the base rate plus 1.00% to 1.50% , each depending on the Utilization Amount (as defined in the Credit Agreement). Pursuant to the Fifth Amendment, borrowings under the revolving credit facility bear interest at (1) the Eurocurrency rate plus 2.25% to 3.50% , (2) the cost of funds rate plus 2.25% to 3.50% , or (3) the base rate plus 1.25% to 2.50% , each depending on the Combined Total Leverage Ratio (as defined in the Credit Agreement). The average interest rates for the Credit Agreement were 3.8% and 3.4% for the three months ended March 31, 2016 and 2015 , respectively. As of March 31, 2016 , the Partnership had two interest rate swaps, both of which were used to hedge the variability in interest payments under the Credit Agreement due to changes in LIBOR rates. See Note 5 for additional information on these cash flow hedges. Additionally, the Partnership had an interest rate cap that was hedging variable interest. The cap was not designated for accounting purposes. The Credit Agreement provides for a letter of credit fee equal to the then applicable working capital rate or then applicable revolver rate (each such rate as defined in the Credit Agreement) per annum for each letter of credit issued. In addition, the Partnership incurs a commitment fee on the unused portion of each facility under the Credit Agreement, ranging from 0.375% to 0.50% per annum. The Partnership classifies a portion of its working capital revolving credit facility as a current liability and a portion as a long-term liability. The portion classified as a long-term liability represents the amounts expected to be outstanding during the entire year based on an analysis of historical borrowings under the working capital revolving credit facility, the seasonality of borrowings, forecasted future working capital requirements and forward product curves , and because the Partnership has a multi-year, long-term commitment from its bank group. Accordingly, at March 31, 2016 , the Partnership estimated working capital revolving credit facility borrowings will equal or exceed $150.0 million over the next twelve months and, therefore, classified $185.2 million as the current portion at March 31, 2016 , representing the amount the Partnership expects to pay down over the next twelve months. The long-term portion of the working capital revolving credit facility was $150.0 million and $150.0 million at March 31, 2016 and December 31, 2015 , respectively, and the current portion was $185.2 million and $98.1 million, at March 31, 2016 and December 31, 2015 , respectively. The increase in total borrowings under the working capital revolving credit facility of $87.1 million from December 31, 2015 was primarily due to cash used in operating assets and liabilities during the year. Inventory increased due to higher prices, and accounts payable decreased as the Partnership exited the heating season. Lower crude oil volume also contributed to the decline in accounts payable. As of March 31, 2016 , the Partnership had total borrowings outstanding under the Credit Agreement of $610.3 million, including $275.1 million outstanding on the revolving credit facility. In addition, the Partnership had outstanding letters of credit of $57.9 million. Subject to borrowing base limitations, the total remaining availability for borrowings and letters of credit was $806.8 million and $1.2 billion at March 31, 2016 and December 31, 2015 , respectively. The Credit Agreement is secured by substantially all of the assets of the Partnership and the Partnership’s wholly owned subsidiaries and is guaranteed by the Partnership and its subsidiaries with the exception of Basin Transload. The Credit Agreement imposes certain requirements on the borrowers including, for example, a prohibition against distributions if any potential default or Event of Default (as defined in the Credit Agreement) would occur as a result thereof, and certain limitations on the Partnership’s ability to grant liens, make certain loans or investments, incur additional indebtedness or guarantee other indebtedness, make any material change to the nature of the Partnership’s business or undergo a fundamental change, make any material dispositions, acquire another company, enter into a merger, consolidation, sale leaseback transaction or purchase of assets or make capital expenditures in excess of specified levels. The Credit Agreement imposes financial covenants that require the Partnership 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. The Fifth Amendment amended the definition of “Total Combined Leverage Ratio” to permit for an increased maximum ratio of 5.50:1 .00 through the first quarter of 2017 and 5. 00:1.00 thereafter. The Partnership was in compliance with the foregoing covenants at March 31, 2016 . The Credit Agreement also contains a representation whereby there can be no event or circumstance, either individually or in the aggregate, that has had or could reasonably be expected to have a Material Adverse Effect (as defined in the Credit Agreement). In addition, the Credit Agreement limits distributions by the Partnership to its unitholders to the amount of Available Cash (as defined in the Partnership’s partnership agreement). 6.25% Senior Notes On June 19, 2014, the Partnership and GLP Finance Corp. (“GLP Finance” and, together with the Partnership, the “Issuers”) entered into a Purchase Agreement (the “Purchase Agreement”) with the Initial Purchasers (as defined therein) (the “Initial Purchasers”) pursuant to which the Issuers agreed to sell $375.0 million aggregate principal amount of the Issuers’ 6.25% senior notes due 2022 (the “6.25% Notes”) to the Initial Purchasers in a private placement exempt from the registration requirements under the Securities Act of 1933, as amended (the “Securities Act”). The 6.25% Notes were resold by the Initial Purchasers to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to persons outside the United States pursuant to Regulation S under the Securities Act. The Purchase Agreement contained customary representations and warranties of the parties and indemnification and contribution provisions under which the Issuers and the subsidiary guarantors, on one hand, and the Initial Purchasers, on the other, agreed to indemnify each other against certain liabilities, including liabilities under the Securities Act. In addition, the Purchase Agreement required the execution of a registration rights agreement, described below, relating to the 6.25% Notes. Closing of the offering occurred on June 24, 2014. Indenture In connection with the private placement of the 6.25% Notes on June 24, 2014, the Issuers and the subsidiary guarantors and Deutsche Bank Trust Company Americas, as trustee, entered into an indenture (the “Indenture”). The 6.25% Notes mature on July 15, 2022 with interest accruing at a rate of 6.25% per annum and payable semi-annually in arrears on January 15 and July 15 of each year, commencing January 15, 2015. The 6.25% 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 Indenture. Upon a continuing event of default, the trustee or the holders of at least 25% in principal amount of the 6.25% Notes may declare the 6.25% Notes immediately due and payable, except that an event of default resulting from entry into a bankruptcy, insolvency or reorganization with respect to the Partnership, any restricted subsidiary of the Partnership that is a significant subsidiary or any group of its restricted subsidiaries that, taken together, would constitute a significant subsidiary of the Partnership, will automatically cause the 6.25% Notes to become due and payable. The Issuers have the option to redeem up to 35% of the 6.25% Notes prior to July 15, 2017 at a redemption price (expressed as a percentage of principal amount) of 106.25% plus accrued and unpaid interest, if any. The Issuers have the option to redeem the 6.25% Notes, in whole or in part, at any time on or after July 15, 2017, at the redemption prices of 104.688% for the twelve-month period beginning on July 15, 2017, 103.125% for the twelve-month period beginning July 15, 2018, 101.563% for the twelve-month period beginning July 15, 2019, and 100.0% beginning on July 15, 2020 and at any time thereafter, together with any accrued and unpaid interest to the date of redemption. In addition, before July 15, 2017, the Issuers may redeem all or any part of the 6.25% Notes at a redemption price equal to the sum of the principal amount thereof, plus a make whole premium at the redemption date, plus accrued and unpaid interest, if any, to the redemption date. The holders of the notes may require the Issuers to repurchase the 6.25% Notes following certain asset sales or a Change of Control (as defined in the Indenture) at the prices and on the terms specified in the Indenture. The Indenture contains covenants that will limit the Partnership’s 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 its subsidiaries, create liens, enter into sale-leaseback transactions, sell assets or merge with other entities. Events of default under the Indenture include (i) a default in payment of principal of, or interest or premium, if any, on, the 6.25% Notes, (ii) breach of the Partnership’s covenants under the Indenture, (iii) certain events of bankruptcy and insolvency, (iv) any payment default or acceleration of indebtedness of the Partnership or certain subsidiaries if the total amount of such indebtedness unpaid or accelerated exceeds $15.0 million and (v) failure to pay within 60 days uninsured final judgments exceeding $15.0 million. Registration Rights Agreement On June 24, 2014, the Issuers and the subsidiary guarantors entered into a registration rights agreement (the “Registration Rights Agreement”) with the Initial Purchasers in connection with the Issuers’ private placement of the 6.25% Notes. Under the Registration Rights Agreement, the Issuers and the subsidiary guarantors agreed to file and use commercially reasonable efforts to cause to become effective a registration statement relating to an offer to exchange the 6.25% Notes for an issue of SEC-registered notes with terms identical to the 6.25% Notes (except that the exchange notes are not subject to restrictions on transfer or to any increase in annual interest rate for failure to comply with the Registration Rights Agreement) that are registered under the Securities Act so as to permit the exchange offer to be consummated by the 360th day after June 24, 2014. The exchange offer was completed on April 21, 2015, and 100% of the 6.25% Notes were exchanged for SEC-registered notes. 7.00% Senior Notes On June 1, 2015, the Issuers entered into a Purchase Agreement (the “7.00% Notes Purchase Agreement”) with the Initial Purchasers (as defined therein) (the “7.00% Notes Initial Purchasers”) pursuant to which the Issuers agreed to sell $300.0 million aggregate principal amount of the Issuers’ 7.00% senior notes due 2023 (the “7.00% Notes”) to the 7.00% Notes Initial Purchasers in a private placement exempt from the registration requirements under the Securities Act. The 7.00% Notes were resold by the 7.00% Notes Initial Purchasers to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to persons outside the United States pursuant to Regulation S under the Securities Act. The 7.00% Notes Purchase Agreement contained customary representations and warranties of the parties and indemnification and contribution provisions under which the Issuers and the subsidiary guarantors, on one hand, and the 7.00% Notes Initial Purchasers, on the other, agreed to indemnify each other against certain liabilities, including liabilities under the Securities Act. In addition, the 7.00% Notes Purchase Agreement required the execution of a registration rights agreement, described below, relating to the 7.00% Notes. Closing of the offering occurred on June 4, 2015. Indenture In connection with the private placement of the 7.00% Notes on June 4, 2015 the Issuers and the subsidiary guarantors and Deutsche Bank Trust Company Americas, as trustee, entered into an indenture (the “7.00% Notes Indenture”). The 7.00% Notes will mature on June 15, 2023 with interest accruing at a rate of 7.00% per annum and payable semi-annually in arrears on June 15 and December 15 of each year, commencing December 15, 2015. The 7.00% 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 7.00% Notes Indenture. Upon a continuing event of default, the trustee or the holders of at least 25% in principal amount of the 7.00% Notes may declare the 7.00% Notes immediately due and payable, except that an event of default resulting from entry into a bankruptcy, insolvency or reorganization with respect to the Partnership, any restricted subsidiary of the Partnership that is a significant subsidiary or any group of its restricted subsidiaries that, taken together, would constitute a significant subsidiary of the Partnership, will automatically cause the 7.00% Notes to become due and payable. The Issuers will have the option to redeem up to 35% of the 7.00% Notes prior to June 15, 2018 at a redemption price (expressed as a percentage of principal amount) of 107.00% plus accrued and unpaid interest, if any. The Issuers have the option to redeem the 7.00% Notes, in whole or in part, at any time on or after June 15, 2018, at the redemption prices of 105.250% for the twelve-month period beginning June 15, 2018, 103.500% for the twelve-month period beginning June 15, 2019, 101.750% for the twelve-month period beginning June 15, 2020, and 100.0% beginning June 15, 2021 and at any time thereafter, together with any accrued and unpaid interest to the date of redemption. In addition, before June 15, 2018, the Issuers may redeem all or any part of the 7.00% 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 7.00% Notes may require the Issuers to repurchase the 7.00% Notes following certain asset sales or a Change of Control (as defined in the 7.00% Notes Indenture) at the prices and on the terms specified in the 7.00% Notes Indenture. The 7.00% Notes Indenture contains covenants that will limit the Partnership’s 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 its subsidiaries, create liens, enter into sale-leaseback transactions, sell assets or merge with other entities. Events of default under the 7.00% Notes Indenture include (i) a default in payment of principal of, or interest or premium, if any, on, the 7.00% Notes, (ii) breach of the Partnership’s covenants under the 7.00% Notes Indenture, (iii) certain events of bankruptcy and insolvency, (iv) any payment default or acceleration of indebtedness of the Partnership 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. Registration Rights Agreement On June 4, 2015, the Issuers and the subsidiary guarantors entered into a registration rights agreement (the “7.00% Notes Registration Rights Agreement”) with the 7.00% Notes Initial Purchasers in connection with the Issuers’ private placement of the 7.00% Notes. Under the 7.00% Notes Registration Rights Agreement, the Issuers and the subsidiary guarantors agreed to file and use commercially reasonable efforts to cause to become effective a registration statement relating to an offer to exchange the 7.00% Notes for an issue of SEC-registered notes with terms identical to the 7.00% Notes (except that the exchange notes are not subject to restrictions on transfer or to any increase in annual interest rate for failure to comply with the 7.00% Notes Registration Rights Agreement) that are registered under the Securities Act so as to permit the exchange offer to be consummated by the 420 th day after June 4, 2015. The exchange offer was completed on October 22, 2015, and 100% of the 7.00% Notes were exchanged for SEC-registered notes. Deferred Financing Fees The Partnership incurs bank fees related to its Credit Agreement and other financing arrangements. These deferred financing fees are amortized over the life of the Credit Agreement or other financing arrangements. The Partnership capitalized deferred financing fees of $17.8 million and $19.0 million at March 31, 2016 and December 31, 2015, respectively. Unamortized fees related to the Credit Agreement are included in other current assets and other long-term assets and amounted to $10.3 million and $11.2 million at March 31, 2016 and December 31, 2015, respectively. Unamortized fees related to the senior notes are presented as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts, and amounted to $7.5 million and $7.8 million at March 31, 2016 and December 31, 2015, respectively. On February 24, 2016, the Partnership voluntarily elected to reduce its working capital revolving credit facility from $1.0 billion at December 31, 2015 to $900.0 million at March 31, 2016 and its revolving credit facility from $775.0 million at December 31, 2015 to $575.0 million at March 31, 2016. As a result, the Partnership incurred expenses of approximately $1.8 million associated with the write-off of a portion of its deferred financing fees. These expenses are included in interest expense in the accompanying statement of operations for the three months ended March 31, 2016. Amortization expense of approximately $1.4 million and $1.5 million for the three months ended March 31, 2016 and 2015 , respectively, is included in interest expense in the accompanying consolidated statements of operations. Financing Obligation In connection with the Capitol acquisition on June 1, 2015 (see Note 2), the Partnership assumed a financing obligation of $89.6 million associated with two sale-leaseback transactions by Capitol for 53 leased sites that did not meet the criteria for sale accounting. During the term of these leases, which expire in May 2028 and September 2029, in lieu of recognizing lease expense for the lease rental payments, the Partnership incurs interest expense associated with the financing obligation. Interest expense of approximately $2.4 million was recorded for the three months ended March 31, 2016 and is included in interest expense in the accompanying statement of operations. The financing obligation will amortize through expiration of the lease based upon the lease rental payments which were $2.3 million for the three months ended March 31, 2016. The financing obligation balance outstanding at March 31, 2016 was $89.8 million.

Related Party Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2016
Related Party Transactions
Related Party Transactions	Note 7. Related Party Transactions The Partnership was a party to an exclusive Second Amended and Restated Terminal Storage Rental and Throughput Agreement, as amended (the “Terminal Storage Rental and Throughput Agreement”), with GPC, an affiliate of the Partnership that is 100% owned by members of the Slifka family, with respect to the Revere Terminal in Revere, Massachusetts. On January 14, 2015, the Partnership acquired the Revere Terminal from GPC and related entities, and the Terminal Storage Rental and Throughput Agreement was terminated. Prior to the acquisition, the agreement was accounted for as an operating lease. The expenses under this agreement totaled $0 and $0.8 million for the three months ended March 31, 2016 and 2015 , respectively. The Partnership was a party to an Amended and Restated Services Agreement with GPC, whereby GPC provided certain terminal operating management services to the Partnership and used certain administrative, accounting and information processing services of the Partnership. The expenses from these services totaled approximately $0 and $8,000 for the three months ended March 31, 2016 and 2015 , respectively. These charges were recorded in selling, general and administrative expenses in the accompanying consolidated statements of operations. On March 11, 2015, the Partnership entered into the following amendments and restatements to its shared services agreements: (i) Global Companies entered into an Amended and Restated Services Agreement with AE Holdings Corp. (the “AE Holdings Amended and Restated Services Agreement”), and (ii) certain of the Partnership’s subsidiaries entered into a Second Amended and Restated Services Agreement with GPC (the “GPC Second Amended and Restated Services Agreement,” and together with the AE Holdings Amended and Restated Services Agreement, the “Amended and Restated Services Agreements”). Under the AE Holdings Amended and Restated Services Agreement, the Partnership provided AE Holdings with certain tax, accounting, treasury and legal support services for which AE Holdings paid the Partnership an aggregate of $15,000 per year in equal monthly installments until it was voluntarily dissolved effective on July 10, 2015. Under the GPC Second Amended and Restated Services Agreement, GPC no longer provides the Partnership with terminal, environmental and operational support services, but the Partnership continues to provide GPC with certain tax, accounting, treasury, legal, information technology, human resources and financial operations support services for which GPC pays the Partnership a monthly services fee at an agreed amount subject to the approval by the Conflicts Committee of the board of directors of the General Partner. The GPC Second Amended and Restated Services Agreement is for an indefinite term and any party may terminate some or all of the services upon ninety (90) days’ advanced written notice. As of March 31, 2016 , no such notice of termination was given by GPC. The General Partner employs substantially all of the Partnership’s employees, except for most of its gasoline station and convenience store employees, who are employed by GMG. The Partnership reimburses the General Partner for expenses incurred in connection with these employees. These expenses, including payroll, payroll taxes and bonus accruals, were $25.6 million and $29.4 million for the three months ended March 31, 2016 and 2015 , respectively. The Partnership also reimburses the General Partner for its contributions under the General Partner’s 401(k) Savings and Profit Sharing Plan and the General Partner’s qualified and non-qualified pension plans. The table below presents trade receivables with GPC and the Partnership and receivables from the General Partner (in thousands): March 31, December 31, 2016 2015 Receivables from GPC $ $ — Receivables from the General Partner (1) Total $ $ (1) Receivables from the General Partner reflect the Partnership’s prepayment of payroll taxes and payroll accruals to the General Partner.

Partners' Equity and Cash Distr

Partners' Equity and Cash Distributions	3 Months Ended
	Mar. 31, 2016
Partners' Equity and Cash Distribution
Partners' Equity and Cash Distributions	Note 8. Partners’ Equity and Cash Distributions Partners’ Equity Partners’ equity at March 31, 2016 consisted of 33,995,563 common units issued, including 7,434,775 common units held by affiliates of the General Partner, including directors and executive officers, collectively representing a 99.33% limited partner interest in the Partnership, and 230,303 general partner units representing a 0.67% general partner interest in the Partnership. There have been no changes to partners’ equity during the three months ended March 31, 2016. Cash Distributions The Partnership intends to make cash distributions to unitholders on a quarterly basis, although there is no assurance as to the future cash distributions since they are dependent upon future earnings, capital requirements, financial condition and other factors. The Credit Agreement prohibits the Partnership 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 the Partnership’s outstanding senior notes also limit the Partnership’s ability to make distributions to its unitholders in certain circumstances. Within 45 days after the end of each quarter, the Partnership will distribute all of its Available Cash (as defined in its partnership agreement) to unitholders of record on the applicable record date. The amount of Available Cash is all cash on hand on the date of determination of Available Cash for the quarter, less the amount of cash reserves established by the General Partner to provide for the proper conduct of the Partnership’s business, to comply with applicable law, any of the Partnership’s debt instruments, or other agreements or to provide funds for distributions to unitholders and the General Partner for any one or more of the next four quarters. The Partnership 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 the Partnership distributes for each outstanding common unit an amount equal to the minimum quarterly distribution for that quarter; and thereafter, cash in excess of the minimum quarterly distribution is distributed to the unitholders and the General Partner based on the percentages as provided below. As holder of the IDRs, the General Partner is entitled to incentive distributions if the amount that the Partnership distributes 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 % % Second Target Distribution above $0.4625 up to $0.5375 % % Third Target Distribution above $0.5375 up to $0.6625 % % Thereafter above $0.6625 % % The Partnership paid the following cash distribution during 2016 (in thousands, except per unit data): Earned for the Per Unit Cash Distribution Quarter Cash Common General Incentive Total Cash Payment Date Ended Distribution Units Partner Distribution Distribution 2/16/2016 12/31/15 $ $ $ $ — $ In addition, on April 26, 2016, the board of directors of the General Partner declared a quarterly cash distribution of $0 .4625 per unit ( $1.85 per unit on an annualized basis) on all of its outstanding common units for the period from January 1, 2016 through March 31, 2016 to the Partnership’s unitholders of record as of the close of business on May 6, 2015.

Unitholders' Equity

Unitholders' Equity	3 Months Ended
	Mar. 31, 2016
Unitholders' Equity
Unitholders' Equity	Note 9. Unitholders’ Equity At-the-Market Offering Program On May 19, 2015, the Partnership entered into an equity distribution agreement pursuant to which the Partnership may sell from time to time through its sales agents, following a standard due diligence effort, the Partnership’s common units having an aggregate offering price of up to $50.0 million. Sales of the common units, if any, will be made by any method permitted by law deemed to be an “at-the-market” offering, including ordinary brokers’ transactions through the facilities of the New York Stock Exchange, to or through a market maker, or directly on or through an electronic communication network, a “dark pool” or any similar market venue, at market prices, in block transactions, or as otherwise agreed upon by the Partnership and one or more of its sales agents. The Partnership may also sell common units to one or more of its sales agents as principal for its own account at a price to be agreed upon at the time of sale. Any sale of common units to a sales agent as principal would be pursuant to the terms of a separate agreement between the Partnership and such sales agent. The Partnership intends to use the net proceeds from any sales pursuant to the at-the-market offering program, after deducting the sales agents’ commissions and the Partnership’s offering expenses, for general partnership purposes, which may include, among other things, repayment of indebtedness, acquisitions and capital expenditures. The sales agents and/or affiliates of each of the sales agents have, from time to time, performed, and may in the future perform, various financial advisory and commercial and investment banking services for the Partnership and its affiliates, for which they have received and in the future will receive customary compensation and expense reimbursement. Affiliates of the sales agents are lenders under the Partnership’s credit facility and, accordingly, may receive a portion of the net proceeds from this offering if and to the extent any proceeds are used to reduce outstanding borrowings under the Partnership’s credit facility. As of March 31, 2016 , no common units were sold by the Partnership pursuant to the at-the-market offering program.

Segment Reporting

Segment Reporting	3 Months Ended
	Mar. 31, 2016
Segment Reporting
Segment Reporting	Note 10. Segment Reporting The Partnership engages in the purchasing, selling, storing and logistics of transporting petroleum and related products, including domestic and Canadian crude oil, gasoline and gasoline blendstocks (such as ethanol), distillates (such as home heating oil, diesel and kerosene), residual oil, renewable fuels, natural gas and propane. The Partnership also receives revenue from convenience store sales and gasoline station rental income. The Partnership’s operating segments are based upon the revenue sources for which discrete financial information is reviewed by the chief operating decision maker (the “CODM”) and include Wholesale, GDSO and Commercial. Each of these operating segments generates revenues and incurs expenses and is evaluated for operating performance on a regular basis. These operating segments are also the Partnership’s reporting segments based on the way the CODM manages the business and on the similarity of customers and expected long-term financial performance of each segment. For the three months ended March 31, 2016 and 2015 , the Commercial operating segment did not meet the quantitative metrics for disclosure as a reportable segment on a stand-alone basis as defined in accounting guidance related to segment reporting. However, the Partnership has elected to present segment disclosures for the Commercial operating segment as management believes such disclosures are meaningful to the user of the Partnership’s financial information. The accounting policies of the segments are the same as those described in Note 2, “Summary of Significant Accounting Policies,” in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2015 . In the Wholesale reporting segment, the Partnership sells branded and unbranded gasoline and gasoline blendstocks and diesel to wholesale distributors. The Partnership transports these products by railcars, barges and/or pipelines pursuant to spot or long ‑term contracts. The Partnership aggregates crude oil by truck or pipeline in the mid-continent region of the United States and Canada, transports it by train and ships it by barge to refiners on the East and West Coasts. The Partnership sells home heating oil, diesel, kerosene, residual oil and propane 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 and distillates at bulk terminals and inland storage facilities that the Partnership owns or controls or with which it has throughput or exchange arrangements. Additionally, ethanol is shipped primarily by rail and by barge. In the GDSO reporting segment, gasoline distribution includes sales of branded and unbranded gasoline to gasoline station operators and sub jobbers. Station operations include (i) convenience stores, (ii) rental income from gasoline stations leased to dealers, from commissioned agents and from cobranding arrangements and (iii) sundries (such as car wash sales, lottery and ATM commissions). In the Commercial segment, the Partnership includes sales and deliveries to end user customers in the public sector and to large commercial and industrial end users of unbranded gasoline, home heating oil, diesel, kerosene, residual oil, bunker fuel and natural gas. In the case of public sector commercial and industrial end user customers, the Partnership sells products primarily either through a competitive bidding process or through contracts of various terms. The Partnership generally arranges for the delivery of the product to the customer’s designated location, and the Partnership responds to publicly-issued requests for product proposals and quotes. The Commercial segment also includes sales of custom blended fuels delivered by barges or from a terminal dock to ships through bunkering activity. The Partnership evaluates segment performance based on product margins before allocations of corporate and indirect operating costs, depreciation, amortization (including non-cash charges) and interest. Based on the way the CODM manages the business, it is not reasonably possible for the Partnership to allocate the components of operating costs and expenses among the reportable segments. Summarized financial information for the Partnership’s reportable segments is presented in the table below (in thousands): Three Months Ended March 31, 2016 2015 Wholesale Segment: Sales Gasoline and gasoline blendstocks $ $ Crude oil (1) Other oils and related products (2) Total $ $ Product margin Gasoline and gasoline blendstocks $ $ Crude oil (1) Other oils and related products (2) Total $ $ Gasoline Distribution and Station Operations Segment: Sales Gasoline $ $ Station operations (3) Total $ $ Product margin Gasoline $ $ Station operations (3) Total $ $ Commercial Segment: Sales $ $ Product margin $ $ Combined sales and Product margin: Sales $ $ Product margin (4) $ $ Depreciation allocated to cost of sales Combined gross profit $ $ (1) Crude oil consists of the Partnership’s crude oil sales and revenue from its logistics activities. (2) Other oils and related products primarily consist of distillates, residual oil and propane. (3) Station operations primarily consist of convenience store sales and rental income. (4) Product margin is a non-GAAP financial measure used by management and external users of the Partnership’s consolidated financial statements to assess its business. The table above includes a reconciliation of product margin on a combined basis to gross profit, a directly comparable GAAP measure. Approximately 111 million gallons and 110 million gallons of the GDSO segment’s sales for the three months ended March 31, 2016 and 2015, respectively, were supplied from petroleum products and renewable fuels sourced by the Wholesale segment. Except for natural gas, predominantly all of the Commercial segment’s sales are sourced by the Wholesale segment. These intra-segment sales are not reflected as sales in the Wholesale segment as they are eliminated. A reconciliation of the totals reported for the reportable segments to the applicable line items in the consolidated financial statements is as follows (in thousands): Three Months Ended March 31, 2016 2015 Combined gross profit $ $ Operating costs and expenses not allocated to operating segments: Selling, general and administrative expenses Operating expenses Amortization expense Loss on sale and disposition of assets and impairment charges Total operating costs and expenses Operating income Interest expense Income tax benefit (expense) Net (loss) income Net loss attributable to noncontrolling interest Net income attributable to Global Partners LP $ $ The Partnership’s foreign assets and foreign sales were immaterial as of and for the three months ended March 31, 2016 and 2015 . Segment Assets The Partnership’s terminal assets are allocated to the Wholesale and Commercial segments, and its acquired retail gasoline stations are allocated to the GDSO segment. Due to the commingled nature and uses of the remainder of the Partnership’s assets, it is not reasonably possible for the Partnership to allocate these assets among its reportable segments. The table below presents total assets by reportable segment at March 31, 2016 and December 31, 2015 (in thousands): Wholesale Commercial GDSO Unallocated Total March 31, 2016 $ $ $ $ $ December 31, 2015 $ $ $ $ $

Property and Equipment

Property and Equipment	3 Months Ended
	Mar. 31, 2016
Property and Equipment
Property and Equipment	Note 11. Property and Equipment Property and equipment consisted of the following (in thousands): March 31, December 31, 2016 2015 Buildings and improvements $ $ Land Fixtures and equipment Construction in process Capitalized internal use software Total property and equipment Less accumulated depreciation Total $ $ At March 31, 2016 and December 31, 2015 , construction in process included $30.5 million related to the Partnership’s ethanol plant acquired from Cascade Kelly Holdings LLC (“Cascade Kelly”) in 2013. The Partnership has begun to take steps to utilize this location by shifting the terminalling facility to ethanol transloading. This measure is substantially related to cleaning of tanks and modifications to associated infrastructure, which commenced during the quarter ended March 31, 2016 and is expected to be completed in the third quarter of 2016. Therefore, as of March 31, 2016 and December 31, 2015 , the recorded value of the ethanol plant was included in construction in process. After the plant has been successfully placed into service, depreciation will commence. As part of continuing operations in the GDSO segment, the Partnership may periodically divest certain gasoline stations. The loss on the sale, representing cash proceeds less net book value of assets at disposition, is recorded in loss on sale and disposition of assets and impairment charges in the accompanying consolidated statements of operations and amounted to $0.6 million and $0.4 million for the three months ended March 31, 2016 and 2015 , respectively. Additionally, in conjunction with the periodic divestiture of gasoline stations, as well as the non-strategic owned or leasehold assets of the GDSO segment identified by the Partnership (see Note 19), the Partnership may classify certain gasoline station assets as held-for-sale. Accordingly, the Partnership has classified 28 sites and 15 sites as held-for-sale at March 31, 2016 and December 31, 2015, respectively. Assets held-for-sale of $12.8 million and $7.4 million at March 31, 2016 and December 31, 2015, respectively, are included in property and equipment in the accompanying balance sheets. The Partnership recorded impairment charges related to its assets held-for-sale in the amount of $5.5 million and $0 for the three months ended March 31, 2016 and 2015, respectively, which are included in loss on sale and disposition of assets and impairment charges in the accompanying consolidated statements of operations. Assets held-for-sale are expected to be sold within the next 12 months. The Partnership evaluates its assets for impairment on a quarterly basis. No other impairment charges were r equired for the three months ended March 31, 2016 and 2015 . However, at March 31, 2016 , the Partnership had a $36.6 million remaining net book value of long ‑lived assets used at its crude oil transloading terminals in North Dakota. The long ‑term recoverability of these assets might be adversely impacted by a prolonged decline in crude oil prices or crude oil differentials. Over the long ‑term, if these market conditions remain, this may become an indicator of the potential impairment of these North Dakota assets in the future. The Partnership will monitor the pricing environment and the related impact this may have on the North Dakota operating and cash flows and whether this would constitute an impairment indicator.

Environmental Liabilities, Asse

Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers	3 Months Ended
	Mar. 31, 2016
Environmental Liabilities and Renewable Identification Numbers (RINs)
Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers (RINs)	Note 12. Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers Environmental Liabilities The Partnership owns or leases properties where refined petroleum products, renewable fuels and crude oil are being or may have been handled. These properties and the refined petroleum products, renewable fuels and crude oil handled thereon may be subject to federal and state environmental laws and regulations. Under such laws and regulations, the Partnership could be required to remove or remediate containerized hazardous liquids or associated generated wastes (including wastes disposed of or abandoned by prior owners or operators), to clean up contaminated property arising from the release of liquids or wastes into the environment, including contaminated groundwater, or to implement best management practices to prevent future contamination. The Partnership maintains insurance of various types with varying levels of coverage that it considers adequate under the circumstances to cover its operations and properties. The insurance policies are subject to deductibles that the Partnership considers reasonable and not excessive. In addition, the Partnership has entered into indemnification agreements with various sellers in conjunction with several of its acquisitions. Allocation of environmental liability is an issue negotiated in connection with each of the Partnership’s acquisition transactions. In each case, the Partnership makes an assessment of potential environmental liability exposure based on available information. Based on that assessment and relevant economic and risk factors, the Partnership determines whether to, and the extent to which it will, assume liability for existing environmental conditions. In connection with the June 2015 acquisition of retail gasoline stations from Capitol, the Partnership assumed certain environmental liabilities, including future remediation activities required by applicable federal, state or local law or regulation at certain of the retail gasoline stations owned by Capitol. Certain environmental remediation obligations at most of the acquired retail gasoline station assets from Capitol are being funded by third parties who assumed certain liabilities in connection with Capitol’s acquisition of these assets from ExxonMobil Corporation (“ExxonMobil”) in 2009 and 2010 and, therefore, cost estimates for such obligations at these stations are not included in this estimate. As a result, the Partnership initially recorded, on an undiscounted basis, a total environmental liability of approximately $0.3 million for those locations not covered by third parties. In connection with the January 2015 acquisition of the Revere Terminal, the Partnership assumed certain environmental liabilities, including certain ongoing environmental remediation efforts. As a result, the Partnership initially recorded, on an undiscounted basis, a total environmental liability of approximately $3.1 million. In connection with the January 2015 acquisition of Warren, the Partnership assumed certain environmental liabilities, including certain ongoing environmental remediation efforts at certain of the retail gasoline stations owned or leased by Warren and future remediation activities required by applicable federal, state or local law or regulation. As a result, the Partnership initially recorded, on an undiscounted basis, a total environmental liability of approximately $36.5 million. In connection with the December 2012 acquisition of six New England retail gasoline stations from Mutual Oil Company, the Partnership assumed certain environmental liabilities , including certain ongoing remediation efforts. As a result, the Partnership initially recorded, on an undiscounted basis, a total environmental liability of approximately $0.6 million. In connection with the March 2012 acquisition of Alliance , the Partnership assumed Alliance’s environmental liabilities, including ongoing environmental remediation at certain of the retail gasoline stations owned by Alliance and future remediation activities required by applicable federal, state or local law or regulation. Remedial action plans are in place, as may be applicable with the state agencies regulating such ongoing remediation. Based on reports from environmental engineers, the Partnership’s estimated cost of the ongoing environmental remediation for which Alliance was responsible and future remediation activities required by applicable federal, state or local law or regulation is estimated to be approximately $16.1 million to be expended over an extended period of time. Certain environmental remediation obligations at the retail stations acquired by Alliance from ExxonMobil in 2011 are being funded by a third party who assumed the liability in connection with the Alliance/ExxonMobil transaction in 2011 and, therefore, cost estimates for such obligations at these stations are not included in this estimate. As a result, the Partnership initially recorded, on an undiscounted basis, total environmental liabilities of approximately $ 16.1 million. In connection with the September 2010 acquisition of retail gasoline stations from ExxonMobil, the Partnership assumed certain environmental liabilities, including ongoing environmental remediation at and monitoring activities at certain of the acquired sites and future remediation activities required by applicable federal, state or local law or regulation. Remedial action plans are in place with the applicable state regulatory agencies for the majority of these locations, including plans for soil and groundwater treatment systems at certain sites. Based on consultations with environmental engineers, the Partnership’s estimated cost of the remediation is expected to be approximately $30.0 million to be expended over an extended period of time. As a result, the Partnership initially recorded, on an undiscounted basis, total environmental liabilities of approximately $ 30.0 million. In connection with the June 2010 acquisition of three refined petroleum products terminals in Newburgh, New York, the Partnership assumed certain environmental liabilities, including certain ongoing remediation efforts. As a result, the Partnership initially recorded, on an undiscounted basis, a total environmental liability of approximately $1.5 million. In addition to the above-mentioned environmental liabilities related to the Partnership's retail gasoline stations, the Partnership retains some of the environmental obligations associated with certain gasoline stations that the Partnership has sold. The following table presents a summary roll forward of the Partnership’s environmental liabilities at March 31, 2016 (in thousands): Balance at Other Balance at December 31, Payments in Dispositions Adjustments March 31, Environmental Liability Related to: 2015 2016 2016 2016 2016 Retail gasoline stations $ $ $ $ $ Terminals — — Total environmental liabilities $ $ $ $ $ Current portion $ $ Long-term portion Total environmental liabilities $ $ The Partnership’s estimates used in these environmental liabilities are based on all known facts at the time and its assessment of the ultimate remedial action outcomes. Among the many uncertainties that impact the Partnership’s estimates are the necessary regulatory approvals for, and potential modification of, its remediation plans, the amount of data available upon initial assessment of the impact of soil or water contamination, changes in costs associated with environmental remediation services and equipment, relief of obligations through divestures of sites and the possibility of existing legal claims giving rise to additional claims. Dispositions generally represent relief of legal obligations through the sale of the related property with no retained obligation. Other adjustments generally represent changes in estimates for existing obligations or obligations associated with new sites. Therefore, although the Partnership believes that these environmental liabilities are adequate, no assurances can be made that any costs incurred in excess of these environmental liabilities or outside of indemnifications or not otherwise covered by insurance would not have a material adverse effect on the Partnership’s financial condition, results of operations or cash flows. Asset Retirement Obligations The Partnership is required to account for the legal obligations associated with the long-lived assets that result from the acquisition, construction, development or operation of long-lived assets. Such asset retirement obligations specifically pertain to the treatment of underground gasoline storage tanks (“USTs”) that exist in those states which statutorily require removal of the USTs at a certain point in time. Specifically, the Partnership’s retirement obligations consist of the estimated costs of removal and disposals of USTs. The liability for an asset retirement obligation is recognized on a discounted basis in the year in which it is incurred. The associated asset retirement costs are capitalized as part of the carrying cost of the asset. The Partnership had approximately $7.9 million and $7.8 million in total asset retirement obligations at March 31, 2016 and December 31, 2015 , respectively, which are included in other long-term liabilities in the accompanying balance sheets. Renewable Identification Numbers (RINs) A RIN is a serial number assigned to a batch of renewable fuel for the purpose of tracking its production, use and trading as required by the U.S. Environmental Protection Agency’s (“EPA”) Renewable Fuel Standard that originated with the Energy Policy Act of 2005 and modified by the Energy Independence and Security Act of 2007. To evidence that the required volume of renewable fuel is blended with gasoline and diesel motor vehicle fuels, obligated parties must retire sufficient RINs to cover their Renewable Volume Obligation (“RVO”). The Partnership’s EPA obligations relative to renewable fuel reporting are largely limited to the foreign gasoline that the Partnership may choose to import and a small amount of blending operations at certain facilities. As a wholesaler of transportation fuels through its terminals, the Partnership separates RINs from renewable fuel through blending with gasoline and can use those separated RINs to settle its 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. The Partnership’s Wholesale segment’s operating results are sensitive to the timing associated with its RIN position relative to its RVO at a point in time, and the Partnership may recognize a mark-to-market liability for a shortfall in RINs at the end of each reporting period. To the extent that the Partnership does not have a sufficient number of RINs to satisfy the RVO as of the balance sheet date, the Partnership charges cost of sales for such deficiency based on the market price of the RINs as of the balance sheet date and records a liability representing the Partnership’s obligation to purchase RINs. The Partnership’s RVO deficiency was $0.1 million and $0.4 million at March 31, 2016 and December 31, 2015 , respectively. The Partnership may enter into RIN forward purchase and sales commitments. Total losses from firm non-cancellable commitments were immaterial at March 31, 2016 and December 31, 2015 .

Long-Term Incentive Plan

Long-Term Incentive Plan	3 Months Ended
	Mar. 31, 2016
Long-Term Incentive Plan
Long-Term Incentive Plan	Note 13. Long-Term Incentive Plan The Partnership has a Long Term Incentive Plan, as amended (the “LTIP”), whereby a total of 4,300,000 common units were authorized for delivery with respect to awards under the LTIP. The LTIP provides for awards to employees, consultants and directors of the General Partner and employees and consultants of affiliates of the Partnership who perform services for the Partnership. The LTIP allows for the award of options, unit appreciation rights, restricted units, phantom units, distribution equivalent rights, unit awards and substitute awards. Awards granted under the LTIP are authorized by the Compensation Committee of the board of directors of the General Partner (the “Committee”) from time to time. Additionally and in accordance with the LTIP, the Committee established a “CEO Authorized LTIP” program pursuant to which the Chief Executive Officer (“CEO”) may grant awards of phantom units without distribution equivalent rights to employees of the General Partner and the Partnership’s subsidiaries, other than named executive officers. The CEO Authorized LTIP program was approved for three consecutive calendar years commencing January 1, 2014, subject to modification or earlier termination by the Committee. During each calendar year of the program, the CEO is authorized to grant awards of up to an aggregate amount of $2.0 million of phantom units payable in common units upon vesting, with unused dollar amounts carrying over in the next year, and no individual grant may be made for an award valued at the time of grant of more than $550,000 , unless otherwise previously approved by the Committee. Awards granted pursuant to the CEO Authorized LTIP generally would be for a term of six years and vest in equal tranches at the end of each of the fourth, fifth and sixth anniversary dates of the particular award. Phantom Unit Awards In 2013, the Committee granted a total of 498,112 phantom units under the LTIP to certain employees and non-employee directors of the General Partner. In 2014, a total of 44,902 phantom units were granted to certain employees. In 2015, a total of 76,893 phantom units were granted to certain employees and the non-employee directors. No awards were granted during the three months ended March 31, 2016. The phantom units for these awards vest pursuant to the terms of the grant agreements. The Partnership currently intends and reasonably expects to issue and deliver the common units upon vesting. The Partnership recorded total compensation expense related to the above awards of $1.1 million and $1.0 million for the three months ended March 31, 2016 and 2015 , respectively, which is included in selling, general and administrative expenses in the accompanying consolidated statements of operations. The total compensation cost related to the non-vested awards not yet recognized at March 31, 2016 was approximately $13.3 million and is expected to be recognized ratably over the remaining requisite service periods. The following table presents a summary of the status of the non-vested phantom units: Weighted Number of Average Non-vested Grant Date Units Fair Value Outstanding non—vested units at December 31, 2015 Vested Outstanding non—vested units at March 31, 2016 $ Repurchase Program In May 2009, the board of directors of the General Partner authorized the repurchase of the Partnership’s common units (the “Repurchase Program”) for the purpose of meeting the General Partner’s anticipated obligations to deliver common units under the LTIP and meeting the General Partner’s obligations under existing employment agreements and other employment related obligations of the General Partner (collectively, the “General Partner’s Obligations”). The General Partner is authorized to acquire up to 1,242,427 of its common units in the aggregate over an extended period of time, consistent with the General Partner’s Obligations. 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 and economic and market conditions, applicable legal requirements and available liquidity. Since the Repurchase Program was implemented, the General Partner has repurchased 838,505 common units pursuant to the Repurchase Program for approximately $24.8 million. No units were purchased during the quarter ended March 31, 2016 .

Fair Value Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2016
Fair Value Measurements
Fair Value Measurements	Note 14. Fair Value Measurements Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). The Partnership utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable. The Partnership primarily applies the market approach for recurring fair value measurements and endeavors to utilize the best available information. Accordingly, the Partnership utilizes valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. The Partnership is able to classify fair value balances based on the observability of those inputs. The fair value hierarchy that prioritizes the inputs used to measure fair value, giving the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). At each balance sheet reporting date, the Partnership categorizes its financial assets and liabilities using the three levels of the fair value hierarchy defined as follows: Level 1 — Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of financial instruments such as the Partnership’s exchange-traded derivative instruments and pension plan assets. Level 2 — Quoted prices in active markets are not available; however, pricing inputs are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Level 2 primarily consists of non-exchange-traded derivatives such as OTC derivatives. Level 3 — Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value. Level 3 includes certain OTC forward derivative instruments related to crude oil and propane. Recurring Fair Value Measures Assets and liabilities are classified in the entirety based on the lowest level of input that is significant to the fair value measurement. The Partnership’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of the fair value assets and liabilities and their placement within the fair value hierarchy levels. The following tables present, by level within the fair value hierarchy, the Partnership’s financial assets and liabilities that were measured at fair value on a recurring basis as of March 31, 2016 and December 31, 2015 (in thousands): Fair Value at March 31, 2016 Cash Collateral Level 1 Level 2 Level 3 Netting Total Assets: Forward derivative contracts (1) $ — $ $ $ — $ Exchange-traded/cleared derivative instruments (2) — — Pension plan — — — Total assets $ $ $ $ $ Liabilities: Forward derivative contracts (1) $ — $ $ $ — $ Foreign currency derivatives — — — Interest rate swaps — — — Total liabilities $ — $ $ $ — $ Fair Value at December 31, 2015 Cash Collateral Level 1 Level 2 Level 3 Netting Total Assets: Forward derivative contracts (1) $ — $ $ $ — $ Foreign currency derivatives — — — Exchange-traded/cleared derivative instruments (2) — — Pension plan — — — Total assets $ $ $ $ $ Liabilities: Forward derivative contracts (1) $ — $ $ $ — $ Swap agreements and options — — — Interest rate swaps — — — Total liabilities $ — $ $ $ — $ (1) Forward derivative contracts include the Partnership’s petroleum and ethanol physical and financial forwards and OTC swaps. (2) Amount includes the effect of cash balances on deposit with clearing brokers. This table excludes cash on hand and assets and liabilities that are measured at historical cost or any basis other than fair value. The carrying amounts of certain of the Partnership’s financial instruments, including cash equivalents, accounts receivable, accounts payable and other accrued liabilities approximate fair value due to their short maturities. The carrying value of the credit facility approximates fair value due to the variable rate nature of these financial instruments. The carrying value of the inventory qualifying for fair value hedge accounting approximates fair value due to adjustments for changes in fair value of the hedged item. The fair values of the derivatives used by the Partnership are disclosed in Note 5. The determination of the fair values above incorporates factors including not only the credit standing of the counterparties involved, but also the impact of the Partnership’s nonperformance risks on its liabilities. The values of the Level 1 exchange-traded/cleared derivative instruments and pension plan assets were determined using quoted prices in active markets for identical assets. Specifically, the fair values of the Level 1 exchange-traded/cleared derivative instruments were based on quoted process obtained from the NYMEX, CME and ICE. The fair values of the Level 1 pension plan assets were based on quoted prices for identical assets which primarily consisted of fixed income securities, equity securities and cash and cash equivalents. The values of the Level 2 derivative contracts were calculated using expected cash flow models and market approaches based on observable market inputs, including published and quoted commodity pricing data, which is verified against other available market data. Specifically, the fair values of the Level 2 derivative commodity contracts were derived from published and quoted NYMEX, CME, ICE, New York Harbor and third-party pricing information for the underlying instruments using market approaches. The fair value of the Level 2 interest rate instruments were derived from the implied forward LIBOR yield curve for the sale period as the future interest rate swap and interest rate cap settlements using expected cash flow models. The fair value of the Level 2 foreign currency derivatives were derived from the implied forward currency curve for the Canadian and U.S. Dollar. The Partnership has not changed its valuation techniques or Level 2 inputs during the three months ended March 31, 2016 . The carrying values and fair values of the 6.25% Notes and 7.00% Notes, estimated by observing market trading prices of the 6.25% Notes and 7.00% Notes, respectively, were as follows (in thousands): March 31, 2016 December 31, 2015 Face Fair Face Fair Value Value Value Value 6.25% Notes $ $ $ $ 7.00% Notes $ $ $ $ Level 3 Information The values of the Level 3 derivative contracts were calculated using market approaches based on a combination of observable and unobservable market inputs, including published and quoted NYMEX, CME, ICE, New York Harbor and third-party pricing information for a component of the underlying instruments as well as internally developed assumptions where there is little, if any, published or quoted prices or market activity. The unobservable inputs used in the measurement of the Level 3 derivative contracts include estimates for location basis, transportation and throughput costs net of an estimated margin for current market participants. The estimates for these inputs for crude oil were $1.35 to $13.25 per barrel and $7.45 to $10.75 per barrel for the three months ended March 31, 2016 and 2015, respectively . The estimates for these inputs for propane were $0.84 to $8.40 per barrel for the three months ended March 31, 2016. For the three months ended March 31, 2015, propane was included in Level 2. Gains and losses recognized in earnings (or changes in net assets) are disclosed in Note 5. Sensitivity of the fair value measurement to changes in the significant unobservable inputs is as follows: Significant Impact on Fair Value Unobservable Input Position Change to Input Measurement Location basis Long Increase (decrease) Gain (loss) Location basis Short Increase (decrease) Loss (gain) Transportation Long Increase (decrease) Gain (loss) Transportation Short Increase (decrease) Loss (gain) Throughput costs Long Increase (decrease) Gain (loss) Throughput costs Short Increase (decrease) Loss (gain) The following table presents a reconciliation of changes in fair value of the Partnership’s derivative contracts classified as Level 3 in the fair value hierarchy at March 31, 2016 (in thousands): Fair value at December 31, 2015 $ Realized and unrealized gains (losses) recorded in cost of sales Fair value at March 31, 2016 $ Non-Recurring Fair Value Measures Certain nonfinancial assets and liabilities are measured at fair value on a non-recurring basis and are subject to fair value adjustments in certain circumstances, such as acquired assets and liabilities or losses related to firm non-cancellable purchase commitments. For assets and liabilities measured on a non-recurring basis during the period, accounting guidance requires quantitative disclosures about the fair value measurements separately for each major category. See Note 11 for a discussion of the Partnership’s assets held-for-sale.

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2016
Income Taxes
Income Taxes	Note 15. Income Taxes Section 7704 of the Internal Revenue Code provides that publicly-traded partnerships are, as a general rule, taxed as corporations. However, an exception, referred to as the “Qualifying Income Exception,” exists under Section 7704(c) with respect to publicly-traded partnerships of which 90% or more of the gross income for every taxable year consists of “qualifying income.” Qualifying income includes income and gains derived from the transportation, storage and marketing of refined petroleum products, crude oil and ethanol to resellers and refiners. Other types of qualifying income include interest (other than from a financial business), dividends, gains from the sale of real property and gains from the sale or other disposition of capital assets held for the production of income that otherwise constitutes qualifying income. Substantially all of the Partnership’s income is “qualifying income” for federal income tax purposes and, therefore, is not subject to federal income taxes at the partnership level. Accordingly, no provision has been made for income taxes on the qualifying income in the Partnership’s financial statements. Net income for financial statement purposes may differ significantly from taxable income reportable to unitholders as a result of differences between the tax basis and financial reporting basis of assets and liabilities and the taxable income allocation requirements under the Partnership’s agreement of limited partnership. Individual unitholders have different investment basis depending upon the timing and price at which they acquired their common units. Further, each unitholder’s tax accounting, which is partially dependent upon the unitholder’s tax position, differs from the accounting followed in the Partnership’s consolidated financial statements. Accordingly, the aggregate difference in the basis of the Partnership’s net assets for financial and tax reporting purposes cannot be readily determined because information regarding each unitholder’s tax attributes in the Partnership is not available to the Partnership. One of the Partnership’s wholly owned subsidiaries, GMG, is a taxable entity for federal and state income tax purposes. Current and deferred income taxes are recognized on the separate earnings of GMG. The after-tax earnings of GMG are included in the earnings of the Partnership. Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes for GMG. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. The Partnership calculates its current and deferred tax provision based on estimates and assumptions that could differ from actual results reflected in income tax returns filed in subsequent years. Adjustments based on filed returns are recorded when identified. On July 1, 2015 the Partnership commenced business in Canada through its wholly owned Canadian subsidiary, Global Partners Energy Canada ULC (“GPEC”). GPEC predominantly consists of sourcing crude oil and other petroleum based products for sale to the Partnership and customers in Canada. GPEC is a taxable entity for Canadian corporate income and branch taxes. In its first year of operations, GPEC realized a pre-tax loss generating a net operating loss that might be used to offset future taxable income when GPEC operates at a profit. The Partnership recognizes deferred tax assets to the extent that the recoverability of these assets satisfies the “more likely than not” recognition criteria in accordance with the accounting guidance regarding income taxes. Based upon projections of future taxable income, limited capital assets and market conditions, the Partnership has provided a full valuation allowance against the GPEC deferred tax asset. The Partnership recognizes deferred tax assets to the extent that the recoverability of these assets satisfies the “more likely than not” recognition criteria in accordance with the accounting guidance regarding income taxes. Based upon projections of future taxable income, the Partnership believes that the recorded deferred tax assets will be realized.

Legal Proceedings

Legal Proceedings	3 Months Ended
	Mar. 31, 2016
Legal Proceedings
Legal Proceedings	Note 16. Legal Proceedings General Although the Partnership may, from time to time, be involved in litigation and claims arising out of its operations in the normal course of business, the Partnership does not believe that it is a party to any litigation that will have a material adverse impact on its financial condition or results of operations. Except as described below and in Note 12 included herein, the Partnership is not aware of any significant legal or governmental proceedings against it, or contemplated to be brought against it. The Partnership maintains insurance policies with insurers in amounts and with coverage and deductibles as its general partner believes are reasonable and prudent. However, the Partnership can provide no assurance that this insurance will be adequate to protect it from all material expenses related to potential future claims or that these levels of insurance will be available in the future at economically acceptable prices. Other In February 2016, the Partnership received a request for information from the EPA seeking certain information regarding its Albany terminal in order to assess its compliance with the Clean Air Act (the “CAA”). The information requested generally relates to crude oil received by, stored at and shipped from the Partnership’s petroleum product transloading facility in Albany, New York (the “Albany Terminal”), including its composition, control devices for emissions and various permitting-related considerations. The Albany Terminal is a 63 -acre licensed, permitted and operational stationary bulk petroleum storage and transfer terminal that currently consists of petroleum product storage tanks, along with truck, rail and marine loading facilities, for the storage, blending and distribution of various petroleum and related products, including gasoline, ethanol, distillates, heating and crude oils. No violations were alleged in the request for information. The Partnership submitted responses and documentation, in March and April 2016, to the EPA in accordance with the EPA request. The Partnership has cooperated fully with the agency and believes responsive information will demonstrate that the Partnership’s operations at the Albany Terminal are in compliance with all pertinent requirements. By letter dated October 5, 2015, the Partnership received a notice of intent to sue (the “October NOI”), which supersedes and replaces a prior notice of intent to sue that the Partnership received on September 1, 2015 (the “September NOI”) from Earthjustice, an environmental advocacy organization on behalf of the County of Albany, New York, a public housing development owned and operated by the Albany Housing Authority and certain environmental organizations, related to alleged violations of the CAA at the Albany Terminal, particularly with respect to crude oil operations at the Albany Terminal. The October NOI revises the superseded and replaced September NOI to add two additional environmental advocacy organizations and to revise the relief sought and the description of the alleged CAA violations. On February 3, 2016, Earthjustice and the other entities identified in the October NOI filed suit against the Partnership in federal court in Albany under the citizen suit provisions of the CAA. In summary, this lawsuit alleges that the Partnership’s operations at the Albany Terminal are in violation of the CAA. The plaintiffs seek, among other things, relief that would compel the Partnership both to apply for what they contend is the applicable permit under the CAA, and to install additional pollution controls. In addition, the plaintiffs seek to prohibit the Albany Terminal from receiving, storing, handling, and marine loading certain types of Bakken crude oil and to require payment of a civil penalty of $37,500 for each day the Partnership as operated the Albany Terminal in violation of the CAA. The Partnership believes that it has meritorious defenses against all allegations. On February 26, 2016, the Partnership filed a motion to dismiss the CAA action and a decision from the Court is expected during the summer of 2016. At this time, all discovery and other litigation activity is stayed pending a decision by the Court on the motion to dismiss. On May 29, 2015 and in connection with a commercial dispute with Tethys Trading Company LLC (“Tethys”), the Partnership received a notice from Tethys alleging a default under, and purporting to terminate, the Partnership’s contract with Tethys for crude oil services at the Partnership’s Oregon facility. However, the Partnership does not believe Tethys had the right to terminate the contract, and the Partnership will continue to investigate and determine the appropriate action to take to enforce its rights under the agreement. The Partnership had expected to receive fees from this contract of approximately $13.2 million for the period July 1, 2015 through December 31, 2015 and approximately $105.2 million in the aggregate for the remaining four years of the contract. On March 26, 2015, the Partnership received a Notice of Non-Compliance (“NON”) from the Massachusetts Department of Environmental Protection (“DEP”) with respect to the Revere Terminal, alleging certain violations of the National Pollutant Discharge Elimination System Permit (“NPDES Permit”) related to storm water discharges. The NON requires the Partnership to submit a plan to remedy the reported violations of the NPDES Permit. The Partnership has responded to the NON with a plan and is implementing modifications to the storm water management system at the Revere Terminal. The Partnership has determined that compliance with the NON and implementation of the plan will have no material impact on its operations. The Partnership has a dispute with Lansing Ethanol Services, LLC (“Lansing”) for damages in excess of $12.0 million. The dispute involves Lansing’s failure to transfer Renewable Fuel Identification Numbers to the Partnership in connection with certain agreements for the purchase and sale of ethanol. The parties had agreed to arbitrate under the rules of the American Arbitration Association. The Partnership filed for arbitration on March 24, 2015 and the hearing was conducted in March 2016 . A decision is anticipated either in the latter part of the second quarter or during the third quarter of this calendar year. Each party has reserved the right to appeal the decision pursuant to the rules of the American Arbitration Association. On May 16, 2014, the Partnership received a subpoena from the SEC requesting information for relevant time periods primarily relating to the Partnership’s accounting for RINs and the restatements of its consolidated financial statements as of and for the quarters ended March 31, 2013, June 30, 2013 and September 30, 2013. The Partnership has cooperated fully with the SEC and believes it has provided the SEC with all requested materials. The Partnership received letters from the EPA dated November 2, 2011 and March 29, 2012, containing requirements and testing orders (collectively, the “Requests for Information”) for information under the CAA. The Requests for Information were part of an EPA investigation to determine whether the Partnership has violated sections of the CAA at certain of its terminal locations in New England with respect to residual oil and asphalt. On June 6, 2014, a Notice of Violation (“NOV”) was received from the EPA, alleging certain violations of its Air Emissions License issued by the Maine Department of Environmental Protection, based upon the test results at the South Portland, Maine terminal. The Partnership met with and provided additional information to the EPA with respect to the alleged violations. On April 7, 2015, the EPA issued a Supplemental Notice of Violation (the “Supplemental NOV”) modifying the allegations of violations of the terminal’s Air Emissions License. The Partnership has responded to the Supplemental NOV and is engaged in further negotiations with the EPA. A tolling agreement was executed with the United States on December 1, 2015. The Partnership does not believe that a material violation has occurred, and it contests the allegations presented in the NOV and Supplemental NOV. The Partnership does not believe any adverse determination in connection with the NOV would have a material impact on its operations.

Changes in Accumulated Other Co

Changes in Accumulated Other Comprehensive Loss	3 Months Ended
	Mar. 31, 2016
Changes in Accumulated Other Comprehensive Loss
Changes in Accumulated Other Comprehensive Loss	Note 17. Changes in Accumulated Other Comprehensive Loss The following table presents the changes in accumulated other comprehensive loss by component for the three months ended March 31, 2016 (in thousands): Pension Three Months Ended March 31, 2016 Plan Derivatives Total Balance at December 31, 2015 $ $ $ Other comprehensive income before reclassifications of gain (loss) Amount of gain (loss) reclassified from accumulated other comprehensive income — Total comprehensive income Balance at March 31, 2016 $ $ $ Amounts are presented prior to the income tax effect on other comprehensive income. Given the Partnership’s partnership status for federal income tax purposes, the effective tax rate is immaterial.

New Accounting Standards

New Accounting Standards	3 Months Ended
	Mar. 31, 2016
New Accounting Standards
New Accounting Standards	Note 18. New Accounting Standards Accounting Standards or Updates Recently Adopted In September 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2015-16, “Business Combinations: Simplifying the Accounting for Measurement-Period Adjustments.” This standard eliminates the requirement that an acquirer in a business combination account for measurement-period adjustments retrospectively. Instead, acquirers must recognize measurement-period adjustments during the period in which they determine the amounts, including the effect on earnings of any amounts they would have recorded in previous periods if the accounting had been completed at the acquisition date. The acquirer still must disclose the amounts and reasons for adjustments to the provisional amounts. The acquirer also must disclose, by line item, the amount of the adjustment reflected in the current-period income statement that would have been recognized in previous periods if the adjustment to provisional amounts had been recognized as of the acquisition date. Alternatively, an acquirer may present those amounts separately on the face of the income statement. The Partnership adopted this standard on January 1, 2016. The adoption of this standard did not have a material impact on the Partnership’s consolidated financial statements. Accounting Standards or Updates Not Yet Effective In March 2016, the FASB issued ASU 2016-09, “Compensation-Stock Compensation: Improvements to Employee Share-Based Payment Accounting.” This standard simplifies several aspects of the accounting for share-based payment award transactions, including accounting for income taxes and classification of excess tax benefits on the statement of cash flows, forfeitures and minimum statutory tax withholding requirements. This standard is effective for annual periods beginning after December 15, 2016 and interim periods within those annual periods. Early adoption is permitted for any interim or annual period. The Partnership is assessing the impact this standard will have on its consolidated financial statements. In March 2016, the FASB issued ASU 2016-05, “Derivatives and Hedging: Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships.” This standard clarifies that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge accounting criteria continue to be met. This standard is effective for fiscal years beginning after December 15, 2016 and interim periods within those fiscal years. Early adoption is permitted, including adoption in an interim period. The adoption of this standard is not expected to have a material impact on the Partnership’s consolidated financial statements In February 2016, the FASB issued ASU 2016-02, “Leases.” This standard amends the existing accounting standards for lease accounting, including requiring lessees to recognize most leases on their balance sheets and making targeted changes to lessor accounting. This standard is effective beginning in the first quarter of 2019. Early adoption of this standard is permitted. The standard requires a modified retrospective transition approach for all leases existing at, or entered into after, the date of initial application, with an option to use certain transition relief. The Partnership is assessing the impact this standard will have on its consolidated financial statements. In January 2016, the FASB issued ASU 2016-01, “ Financial Instruments - Recognition and Measurement of Financial Assets and Financial Liabilities.” This standard revises the classification and measurement of investments in certain equity investments and the presentation of certain fair value changes for certain financial liabilities measured at fair value. This standard also requires the change in fair value of many equity investments to be recognized in net income. This standard is effective for interim and annual periods beginning after December 15, 2017, with early adoption permitted. The adoption of this standard is not expected to have a material impact on the Partnership’s consolidated financial statements. In July 2015, the FASB issued ASU 2015-11, “Simplifying the Measurement of Inventory,” which requires an entity to measure inventory within the scope of the amendment at the lower of cost and net realizable value. Net realizable value is the estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. The new standard is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. The Partnership is assessing the impact this standard will have on its consolidated financial statements. In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers,” that introduces a new five-step revenue recognition model in which an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This standard also requires disclosures sufficient to enable users to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers, including qualitative and quantitative disclosures about contracts with customers, significant judgments and changes in judgments, and assets recognized from the costs to obtain or fulfill a contract. In July 2015, the FASB approved a one-year deferral of the effective date of the standard to fiscal periods beginning after December 15, 2017. The Partnership is evaluating the guidance to determine the impact it will have on its consolidated financial statements.

Subsequent Events

Subsequent Events	3 Months Ended
	Mar. 31, 2016
Subsequent Event Abstract
Subsequent Events	Note 19. Subsequent Events The Partnership has identified certain non-strategic owned or leasehold assets of the GDSO segment which could result in the sale of more than 100 sites. These assets did not meet the criteria to be presented as held for sale as of March 31, 2016. In April of 2016, the Partnership retained a real estate firm to coordinate the sale of 86 of these sites. On April 26, 2016, the board of directors of the General Partner declared a quarterly cash distribution of $0.4625 per unit ($1.85 per unit on an annualized basis) for the period from January 1, 2016 through March 31, 2016. On May 16, 2016, the Partnership will pay this cash distribution to its unitholders of record as of the close of business on May 6, 2016.

Supplemental Guarantor Condense

Supplemental Guarantor Condensed Consolidating Financial Statements	3 Months Ended
	Mar. 31, 2016
Supplemental Guarantor Condensed Consolidating Financial Statements
Supplemental Guarantor Condensed Consolidating Financial Statements	Note 20. Supplemental Guarantor Condensed Consolidating Financial Statements The Partnership’s wholly owned subsidiaries, other than GLP Finance, are guarantors of senior notes issued by the Partnership and GLP Finance. As such, the Partnership is subject to the requirements of Rule 3-10 of Regulation S-X of the SEC regarding financial statements of guarantors and issuers of registered guaranteed securities. The Partnership presents condensed consolidating financial information for its subsidiaries within the notes to consolidated financial statements in accordance with the criteria established for parent companies in the SEC’s Regulation S-X, Rule 3-10(d). The following condensed consolidating financial information presents the Condensed Consolidating Balance Sheets as of March 31, 2016 and December 31, 2015 , the Condensed Consolidating Statements of Operations for the three months ended March 31, 2016 and 2015 and the Condensed Consolidating Statements of Cash Flows for three months ended March 31, 2016 and 2015 of the Partnership’s 100% owned guarantor subsidiaries, the non-guarantor subsidiary and the eliminations necessary to arrive at the information for the Partnership on a consolidated basis. The principal elimination entries eliminate investments in subsidiaries and intercompany balances and transactions. Condensed Consolidating Balance Sheet March 31, 2016 (In thousands) Issuer Non- Guarantor Guarantor Subsidiaries Subsidiary Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ $ $ — $ Accounts receivable, net — Accounts receivable - affiliates Inventories — — Brokerage margin deposits — — Derivative assets — — Prepaid expenses and other current assets — Total current assets Property and equipment, net — — Intangible assets, net — Goodwill — Other assets — — Total assets $ $ $ $ Liabilities and partners' equity Current liabilities: Accounts payable $ $ $ — $ Accounts payable - affiliates — Working capital revolving credit facility - current portion — — Environmental liabilities - current portion — — Trustee taxes payable — — Accrued expenses and other current liabilities — Derivative liabilities — — Total current liabilities Working capital revolving credit facility - less current portion — — Revolving credit facility — — Senior notes — — Environmental liabilities - less current portion — — Financing obligation — — Deferred tax liabilities — — Other long-term liabilities — — Total liabilities Partners' equity Global Partners LP equity — Noncontrolling interest — — Total partners' equity — Total liabilities and partners' equity $ $ $ $ Condensed Consolidating Balance Sheet December 31, 2015 (In thousands) Issuer Non- Guarantor Guarantor Subsidiaries Subsidiary Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ — $ $ $ Accounts receivable, net — Accounts receivable - affiliates Inventories — — Brokerage margin deposits — — Derivative assets — — Prepaid expenses and other current assets — Total current assets Property and equipment, net — Intangible assets, net — — Goodwill — Other assets — — Total assets $ $ $ $ Liabilities and partners' equity Current liabilities: Cash overdraft $ $ — $ $ — Accounts payable — Accounts payable - affiliates — Working capital revolving credit facility - current portion — — Environmental liabilities - current portion — — Trustee taxes payable — — Accrued expenses and other current liabilities — Derivative liabilities — — Total current liabilities Working capital revolving credit facility - less current portion — — Revolving credit facility — — Senior notes — — Environmental liabilities - less current portion — — Financing obligation — — Deferred tax liabilities — — Other long-term liabilities — — Total liabilities Partners' equity Global Partners LP equity — Noncontrolling interest — — Total partners' equity — Total liabilities and partners' equity $ $ $ $ Condensed Consolidating Statement of Operations Three Months Ended March 31, 2016 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Eliminations Consolidated Sales $ $ $ $ Cost of sales Gross profit — Costs and operating expenses: Selling, general and administrative expenses — Operating expenses — Amortization expense — — Loss on sale and disposition of assets and impairment charges — — Total costs and operating expenses — Operating income (loss) — Interest expense — — Loss before income tax benefit — Income tax benefit — — Net loss — Net loss attributable to noncontrolling interest — — Net loss attributable to Global Partners LP — Less: General partner's interest in net loss, including incentive distribution rights — — Limited partners' interest in net loss $ $ $ — $ Condensed Consolidating Statement of Operations Three Months Ended March 31, 2015 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Eliminations Consolidated Sales $ $ $ $ Cost of sales Gross profit — Costs and operating expenses: Selling, general and administrative expenses — Operating expenses — Amortization expense — Loss on sale and disposition of assets and impairment charges — — Total costs and operating expenses — Operating income (loss) — Interest expense — Income (loss) before income tax expense — Income tax expense — — Net income (loss) — Net loss attributable to noncontrolling interest — — Net income (loss) attributable to Global Partners LP — Less: General partner's interest in net income, including incentive distribution rights — — Limited partners' interest (loss) in net income $ $ $ — $ Condensed Consolidating Statement Cash Flows Three Months Ended March 31, 2016 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Consolidated Cash flows from operating activities Net cash used in operating activities $ $ $ Cash flows from investing activities Capital expenditures — Proceeds from sale of property and equipment — Net cash used in investing activities — Cash flows from financing activities Net borrowings from working capital revolving credit facility — Net borrowings from revolving credit facility — Noncontrolling interest capital contribution Distribution to noncontrolling interest — Distributions to partners — Net cash provided by (used in) financing activities Cash and cash equivalents Increase (decrease) in cash and cash equivalents Cash and cash equivalents at beginning of period Cash and cash equivalents at end of period $ $ $ Condensed Consolidating Statement Cash Flows Three Months Ended March 31, 2015 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Consolidated Cash flows from operating activities Net cash (used in) provided by operating activities $ $ $ Cash flows from investing activities Acquisitions — Capital expenditures Proceeds from sale of property and equipment — Net cash used in investing activities Cash flows from financing activities Net borrowings from working capital revolving credit facility — Net borrowings from revolving credit facility — Payments on line of credit — Repurchase of common units — Noncontrolling interest capital contribution — Distribution to noncontrolling interest — Distributions to partners — Net cash provided by (used in) financing activities Cash and cash equivalents (Decrease) increase in cash and cash equivalents Cash and cash equivalents at beginning of period Cash and cash equivalents at end of period $ $ $ Placeholder-please do not delete

Organization and Basis of Prese

Organization and Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 2016
Summary of Significant Accounting Policies
Basis of Presentation	Basis of Presentation On January 7, 2015, the Partnership acquired, through one of its wholly owned subsidiaries, Global Montello Group Corp. (“GMG”), 100% of the equity interests in Warren Equities, Inc. (“Warren”) from The Warren Alpert Foundation. On January 14, 2015, the Partnership acquired the Revere terminal (the “Revere Terminal”) located in Boston Harbor in Revere, Massachusetts from Global Petroleum Corp. (“GPC”) and related entities. On June 1, 2015, the Partnership acquired, through one of its wholly owned subsidiaries, Alliance Energy LLC (“Alliance”), retail gasoline stations and dealer supply contracts from Capitol Petroleum Group (“Capitol”). See Note 2. The financial results of Warren and the Revere Terminal for the three months ended March 31, 2015 are included in the accompanying statement of operations for the three months ended March 31, 2015 . The accompanying consolidated financial statements as of March 31, 2016 and December 31, 2015 and for the three months ended March 31, 2016 and 2015 reflect the accounts of the Partnership. Upon consolidation, all intercompany balances and transactions have been eliminated. The accompanying unaudited consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) and reflect all adjustments (consisting of normal recurring adjustments) which are, in the opinion of management, necessary for a fair presentation of the financial condition and operating results for the interim periods. The interim financial information, which has been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”), should be read in conjunction with the consolidated financial statements for the year ended December 31, 2015 and notes thereto contained in the Partnership’s Annual Report on Form 10-K. The significant accounting policies described in Note 2, “Summary of Significant Accounting Policies,” of such Annual Report on Form 10-K are the same used in preparing the accompanying consolidated financial statements. The results of operations for the three months ended March 31, 2016 are not necessarily indicative of the results of operations that will be realized for the entire year ending December 31, 2016 . The consolidated balance sheet at December 31, 2015 has been derived from the audited consolidated financial statements included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2015 . Due to the nature of the Partnership’s business and its reliance, in part, on consumer travel and spending patterns, the Partnership may experience more demand for gasoline during the late spring and summer months than during the fall and winter. Travel and recreational activities are typically higher in these months in the geographic areas in which the Partnership operates, increasing the demand for gasoline that the Partnership distributes. Therefore, the Partnership’s volumes in gasoline are typically higher in the second and third quarters of the calendar year. As demand for some of the Partnership’s 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 the Partnership’s quarterly operating results.
Noncontrolling Interest	Noncontrolling Interest These financial statements reflect the application of ASC 810, “Consolidations” (“ASC 810”) which establishes accounting and reporting standards that require: (i) the ownership interest in subsidiaries held by parties other than the parent to be clearly identified and presented in the consolidated balance sheet within shareholder’s equity, but separate from the parent’s equity; (ii) the amount of consolidated net income attributable to the parent and the noncontrolling interest to be clearly identified and presented on the face of the consolidated statements of operations; and (iii) changes in a parent’s ownership interest while the parent retains its controlling financial interest in its subsidiary to be accounted for consistently. The Partnership acquired a 60% interest in Basin Transload, LLC (“Basin Transload”) on February 1, 2013. After evaluating ASC 810, the Partnership concluded it is appropriate to consolidate the balance sheet and statements of operations of Basin Transload based on an evaluation of the outstanding voting interests. Amounts pertaining to the noncontrolling ownership interest held by third parties in the financial position and operating results of the Partnership are reported as a noncontrolling interest in the accompanying consolidated balance sheets and statements of operations.
Concentration of Risk	Concentration of Risk The following table presents the Partnership’s product sales and other revenues as a percentage of the consolidated sales for the periods presented: Three Months Ended March 31, 2016 2015 Gasoline sales: gasoline and gasoline blendstocks (such as ethanol) % % Crude oil sales and crude oil logistics revenue % % Distillates (home heating oil, diesel and kerosene), residual oil, natural gas and propane sales % % Convenience store sales, rental income and sundry sales % % Total % % The following table presents the Partnership’s product margin by segment as a percentage of the consolidated product margin for the periods presented: Three Months Ended March 31, 2016 2015 Wholesale segment % % GDSO segment % % Commercial segment % % Total % % See Note 10, “Segment Reporting” for additional information on the Partnership’s operating segments. None of the Partnership’s customers accounted for greater than 10% of total sales for the three months ended March 31, 2016 and 2015 .
Goodwill	Goodwill Goodwill represents the future economic benefits arising from assets acquired in a business combination that are not individually identified and separately recognized. The Partnership has concluded that its operating segments are also its reporting units. At March 31, 2016 and December 31, 2015, goodwill recorded in the accompanying consolidated balance sheets aggregated $435.4 million, of which $121.7 million relates to the Wholesale segment and $313.7 million relates to the Gasoline Distribution and Station Operations (“GDSO”) segment. Goodwill is tested for impairment annually as of October 1 or when events or changes in circumstances indicate that the carrying amount of goodwill may not be recoverable. The process of testing goodwill for impairment involves numerous judgments, assumptions and estimates made by management which inherently reflect a high degree of uncertainty. The impairment test first includes a qualitative assessment in order to conclude if it is more likely than not that the reporting unit’s fair value exceeds its carrying value. Factors considered in the qualitative analysis include changes in the business and industry, as well as macro-economic conditions, that would influence the fair value of the reporting unit as well as changes in the carrying values of the reporting unit. If necessary, the Partnership will then complete a two-step quantitative assessment. In the quantitative assessment, the fair value of each reporting unit is determined and compared to the book value of the reporting unit. If the fair value of the reporting unit is less than the book value, including goodwill, then the recorded goodwill is impaired to its implied fair value with a charge to operations. The Partnership calculates the fair value of each reporting unit using a combination of discounted cash flows and market comparables. Key assumptions included in the development of the discounted cash flow value for each reporting unit include: Future commodity volumes and margins. The discounted cash flows are based on a five-year forecast with an estimate of terminal value. In general, the reporting units’ fair values are most sensitive to volume and gross margin assumptions. In particular, the Wholesale segment’s cash flows are impacted by the crude oil market, given the Partnership’s 2013 investment in transloading terminals in North Dakota and Oregon. The significant decline in the price of crude oil and tight crude oil differentials negatively impacted the Partnership’s fiscal 2015 results. The Partnership expects low crude oil prices and tight differentials to continue for a period of time, which will negatively impact the Partnership’s 2016 performance with recovery expected in 2017. As a result of these market conditions, there is increased uncertainty and sensitivity relating to the Partnership’s future cash flow projections within its crude oil business on which the Wholesale reporting unit’s goodwill impairment analysis relies. If market conditions, and therefore the Partnership’s performance, are worse than its projections, the Partnership may record impairment charges in the future. Actual results may not be consistent with these judgments, assumptions and estimates, and goodwill impairment charges may be required in future periods. This could have an adverse impact on the Partnership’s financial position and results of operations. Discount rate commensurate with the risks involved. The Partnership applies a discount rate to its expected cash flows based on a variety of factors, including market and economic conditions, operational risk, regulatory risk and political risk. A higher discount rate decreases the net present value of cash flows. Future capital requirements. The Partnership’s estimates of future capital requirements are based upon a combination of authorized spending and internal forecasts. On October 1, 2015, the Partnership completed its quantitative assessments for both the Wholesale and GDSO reporting units, and no impairment indicator was identified for either reporting unit. The declining crude oil prices, changes in certain market conditions, and decline in the Partnership’s common unit price, collectively caused the Partnership to reassess its goodwill for impairment as of December 31, 2015 for the Wholesale reporting unit. Based on the results of this assessment, the Partnership concluded that step-two of the quantitative assessment was not necessary and no impairment was required. As of March 31, 2016, the Partnership considered whether there were any change of circumstances or events during the first quarter which would more likely than not reduce the fair value of the Wholesale segment’s reporting unit below its carrying amount. The Partnership concluded that such events and circumstances have not occurred. The fair values of the Partnership’s reporting units are based on underlying assumptions that represent the Partnership’s best estimates. Many of the factors used in assessing fair value are outside of the control of management. A further sustained decline in commodity prices may cause the Partnership to reassess its long-lived assets and goodwill for impairment, and could result in future non-cash impairment charges as a result of such impairment assessments. If the Partnership is required to perform step-two in the future for the Wholesale reporting unit, up to $121.7 million of goodwill assigned to this reporting unit could be written off in the period of such impairment assessment.

Organization and Basis of Pre28

Organization and Basis of Presentation (Tables)	3 Months Ended
	Mar. 31, 2016
Product Margin [Member]
Schedule of product sales, other revenues and product margin as a percentage of the consolidated total	Three Months Ended March 31, 2016 2015 Wholesale segment % % GDSO segment % % Commercial segment % % Total % %
Sales Revenue, Product Line [Member]
Schedule of product sales, other revenues and product margin as a percentage of the consolidated total	Three Months Ended March 31, 2016 2015 Gasoline sales: gasoline and gasoline blendstocks (such as ethanol) % % Crude oil sales and crude oil logistics revenue % % Distillates (home heating oil, diesel and kerosene), residual oil, natural gas and propane sales % % Convenience store sales, rental income and sundry sales % % Total % %

Business Combinations (Tables)

Business Combinations (Tables)	3 Months Ended
	Mar. 31, 2016
Capitol Petroleum Group
Acquisitions
Schedule of pro-forma information (in thousands, except per unit data)	Three Months Ended March 31, 2015 Sales $ Net income attributable to Global Partners LP $ Net income per limited partner unit, basic and diluted $

Net (Loss) Income Per Limited30

Net (Loss) Income Per Limited Partner Unit (Tables)	3 Months Ended
	Mar. 31, 2016
Net (Loss) Income Per Limited Partner Unit
Schedule of reconciliation of net income and the assumed allocation of net income to the limited partners' interest for purposes of computing net income per limited partner unit (in thousands, except per unit data)	The following table provides a reconciliation of net (loss) income and the assumed allocation of net (loss) income to the limited partners’ interest for purposes of computing net (loss) income per limited partner unit for the three months ended March 31, 2016 and 2015 (in thousands, except per unit data): Three Months Ended March 31, 2016 Three Months Ended March 31, 2015 Limited General Limited General Partner Partner Partner Partner Numerator: Total Interest Interest IDRs Total Interest Interest IDRs Net (loss) income attributable to Global Partners LP (1) $ $ $ $ — $ $ $ $ — Declared distribution $ $ $ $ — $ $ $ $ Assumed allocation of undistributed net (loss) income — — Assumed allocation of net (loss) income $ $ $ $ — $ $ $ $ Denominator: Basic weighted average limited partner units outstanding Dilutive effect of phantom units — Diluted weighted average limited partner units outstanding Basic net (loss) income per limited partner unit $ $ Diluted net (loss) income per limited partner unit (2) $ $ (1) As a result of the June 2015 issuance of 3,000,000 common units, the general partner interest was reduced to 0.67% for three months ended March 31, 2016 from 0.74% for the three months ended March 31, 2015 . (2) Basic units were used to calculate diluted net income per limited partner unit for the three months ended March 31, 2016, as using the effects of phantom units would have an anti-dilutive effect on net income per limited partner unit.
Schedule of quarterly cash distributions made to general partners	Per Unit Cash Distribution Declared for the Cash Distribution Declaration Date Distribution Declared Quarterly Period Ended April 26, 2016 $ March 31, 2016

Inventories (Tables)

Inventories (Tables)	3 Months Ended
	Mar. 31, 2016
Inventories
Schedule of inventories (in thousands)	Inventories consisted of the following (in thousands): March 31, December 31, 2016 2015 Distillates: home heating oil, diesel and kerosene $ $ Gasoline Gasoline blendstocks Crude oil Residual oil Propane and other Renewable identification numbers (RINs) Convenience store inventory Total $ $

Derivative Financial Instrume32

Derivative Financial Instruments (Tables)	3 Months Ended
	Mar. 31, 2016
Derivative Financial Instruments
Schedule of notional values of derivative instruments	Units (1) Unit of Measure Exchange-Traded Derivatives Long Thousands of barrels Short Thousands of barrels OTC Derivatives (Petroleum/Ethanol) Long Thousands of barrels Short Thousands of barrels OTC Derivatives (Natural Gas) Long Thousands of decatherms Short Thousands of decatherms Interest Rate Swaps $ Millions of U.S. dollars Interest Rate Cap $ Millions of U.S. dollars Foreign Currency Derivatives Open Forward Exchange Contracts (2) $ Millions of Canadian dollars $ Millions of U.S. dollars (1) Number of open positions and gross notional values do not measure the Partnership’s risk of loss, quantify risk or represent assets or liabilities of the Partnership, but rather indicate the relative size of the derivative instruments and are used in the calculation of the amounts to be exchanged between counterparties upon settlements. (2) All-in forward rate Canadian dollars $1.2973 to USD $1.00.
Schedule of the amount of gains and losses from derivatives not involved in a fair value hedging relationship or in a hedging relationship recognized in the consolidated statements of income (in thousands)	Statement of Gain (Loss) Three Months Ended Derivatives not designated as Recognized in March 31, hedging instruments Income on Derivatives 2016 2015 Commodity contracts Cost of sales $ $ Forward foreign currency contracts Cost of sales Total $ $
Schedule of fair values of derivative instruments and location in consolidated balance sheets (in thousands)	March 31, 2016 Derivatives Derivatives Not Designated as Designated as Hedging Hedging Balance Sheet Location Instruments Instruments Total Asset Derivatives: Exchange-traded derivative contracts Broker margin deposits $ $ $ Forward derivative contracts (1) Derivative assets — Total asset derivatives $ $ $ Liability Derivatives: Exchange-traded derivative contracts Broker margin deposits $ $ $ Forward derivative contracts (1) Derivative liabilities Forward foreign currency contracts Accrued expenses and other current liabilities — Interest rate swap contracts Other long-term liabilities — Total liability derivatives $ $ $ December 31, 2015 Derivatives Derivatives Not Designated as Designated as Hedging Hedging Balance Sheet Location Instruments Instruments Total Asset Derivatives: Exchange-traded derivative contracts Broker margin deposits $ $ $ Forward derivative contracts (1) Derivative assets — Forward foreign currency contracts Other assets — Total asset derivatives $ $ $ Liability Derivatives: Forward derivative contracts (1) Derivative liabilities $ — $ $ Interest rate swap contracts Other long-term liabilities — Total liability derivatives $ — $ $ (1) Forward derivative contracts include the Partnership’s petroleum and ethanol physical and financial forwards and OTC swaps.
Fair Value Hedge
Derivative Financial Instruments
Schedule of net gains and losses from derivatives recognized in consolidated statements of operations (in thousands)	Statement of Gain (Loss) Three Months Ended Recognized in Income on March 31, Derivatives 2016 2015 Derivatives in fair value hedging relationship Exchange-traded futures contracts and OTC derivative contracts for petroleum commodity products Cost of sales $ $ Hedged items in fair value hedge relationship Physical inventory Cost of sales $ $
Cash Flow Hedges
Derivative Financial Instruments
Schedule of net gains and losses from derivatives recognized in consolidated statements of operations (in thousands)	Amount of Gain (Loss) Location of Gain (Loss) Amount of Gain (Loss) Recognized in Reclassified from Reclassified from Other Comprehensive Accumulated Other Other Comprehensive Income on Derivatives Comprehensive Income into Income into Income (Effective Portion) Income (Effective Portion) (Effective Portion) Three Months Ended Three Months Ended Derivatives Designated in March 31, March 31, Cash Flow Hedging Relationship 2016 2015 2016 2015 Interest rate swaps $ $ Interest expense $ — $ —

Related Party Transactions (Tab

Related Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2016
Related Party Transactions
Schedule of receivables from related parties (in thousands)	March 31, December 31, 2016 2015 Receivables from GPC $ $ — Receivables from the General Partner (1) Total $ $ (1) Receivables from the General Partner reflect the Partnership’s prepayment of payroll taxes and payroll accruals to the General Partner.

Partners' Equity and Cash Dis34

Partners' Equity and Cash Distributions (Tables)	3 Months Ended
	Mar. 31, 2016
Partners' Equity and Cash Distribution
Schedule of quarterly cash distributions to the unitholders and the General Partner based on target levels	Marginal Percentage Total Quarterly Distribution Interest in Distributions Target Amount Unitholders General Partner First Target Distribution up to $0.4625 % % Second Target Distribution above $0.4625 up to $0.5375 % % Third Target Distribution above $0.5375 up to $0.6625 % % Thereafter above $0.6625 % %
Schedule of cash distributions made by the Partnership (in thousands, except per unit data)	Earned for the Per Unit Cash Distribution Quarter Cash Common General Incentive Total Cash Payment Date Ended Distribution Units Partner Distribution Distribution 2/16/2016 12/31/15 $ $ $ $ — $

Segment Reporting (Tables)

Segment Reporting (Tables)	3 Months Ended
	Mar. 31, 2016
Segment Reporting
Summary of financial information for the reportable segments (in thousands)	Summarized financial information for the Partnership’s reportable segments is presented in the table below (in thousands): Three Months Ended March 31, 2016 2015 Wholesale Segment: Sales Gasoline and gasoline blendstocks $ $ Crude oil (1) Other oils and related products (2) Total $ $ Product margin Gasoline and gasoline blendstocks $ $ Crude oil (1) Other oils and related products (2) Total $ $ Gasoline Distribution and Station Operations Segment: Sales Gasoline $ $ Station operations (3) Total $ $ Product margin Gasoline $ $ Station operations (3) Total $ $ Commercial Segment: Sales $ $ Product margin $ $ Combined sales and Product margin: Sales $ $ Product margin (4) $ $ Depreciation allocated to cost of sales Combined gross profit $ $ (1) Crude oil consists of the Partnership’s crude oil sales and revenue from its logistics activities. (2) Other oils and related products primarily consist of distillates, residual oil and propane. (3) Station operations primarily consist of convenience store sales and rental income. (4) Product margin is a non-GAAP financial measure used by management and external users of the Partnership’s consolidated financial statements to assess its business. The table above includes a reconciliation of product margin on a combined basis to gross profit, a directly comparable GAAP measure.
Schedule of reconciliation of the totals reported for the reportable segments to the applicable line items in the consolidated financial statements (in thousands)	Three Months Ended March 31, 2016 2015 Combined gross profit $ $ Operating costs and expenses not allocated to operating segments: Selling, general and administrative expenses Operating expenses Amortization expense Loss on sale and disposition of assets and impairment charges Total operating costs and expenses Operating income Interest expense Income tax benefit (expense) Net (loss) income Net loss attributable to noncontrolling interest Net income attributable to Global Partners LP $ $
Schedule of total assets by reportable segment (in thousands)	Wholesale Commercial GDSO Unallocated Total March 31, 2016 $ $ $ $ $ December 31, 2015 $ $ $ $ $

Property and Equipment (Tables)

Property and Equipment (Tables)	3 Months Ended
	Mar. 31, 2016
Property and Equipment
Schedule of components of property and equipment (in thousands)	March 31, December 31, 2016 2015 Buildings and improvements $ $ Land Fixtures and equipment Construction in process Capitalized internal use software Total property and equipment Less accumulated depreciation Total $ $

Environmental Liabilities, ARO

Environmental Liabilities, ARO and RINs (Tables)	3 Months Ended
	Mar. 31, 2016
Environmental Liabilities and Renewable Identification Numbers (RINs)
Summary roll forward of the environmental liabilities (in thousands)	Balance at Other Balance at December 31, Payments in Dispositions Adjustments March 31, Environmental Liability Related to: 2015 2016 2016 2016 2016 Retail gasoline stations $ $ $ $ $ Terminals — — Total environmental liabilities $ $ $ $ $ Current portion $ $ Long-term portion Total environmental liabilities $ $

Long-Term Incentive Plan (Table

Long-Term Incentive Plan (Tables)	3 Months Ended
	Mar. 31, 2016
Long-Term Incentive Plan
Summary of the status of the non-vested phantom units	Weighted Number of Average Non-vested Grant Date Units Fair Value Outstanding non—vested units at December 31, 2015 Vested Outstanding non—vested units at March 31, 2016 $

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2016
Fair Value Measurements
Schedule of financial assets and financial liabilities measured at fair value on a recurring basis (in thousands)	Fair Value at March 31, 2016 Cash Collateral Level 1 Level 2 Level 3 Netting Total Assets: Forward derivative contracts (1) $ — $ $ $ — $ Exchange-traded/cleared derivative instruments (2) — — Pension plan — — — Total assets $ $ $ $ $ Liabilities: Forward derivative contracts (1) $ — $ $ $ — $ Foreign currency derivatives — — — Interest rate swaps — — — Total liabilities $ — $ $ $ — $ Fair Value at December 31, 2015 Cash Collateral Level 1 Level 2 Level 3 Netting Total Assets: Forward derivative contracts (1) $ — $ $ $ — $ Foreign currency derivatives — — — Exchange-traded/cleared derivative instruments (2) — — Pension plan — — — Total assets $ $ $ $ $ Liabilities: Forward derivative contracts (1) $ — $ $ $ — $ Swap agreements and options — — — Interest rate swaps — — — Total liabilities $ — $ $ $ — $ (1) Forward derivative contracts include the Partnership’s petroleum and ethanol physical and financial forwards and OTC swaps. (2) Amount includes the effect of cash balances on deposit with clearing brokers.
Carrying value and fair value of the Partnership’s senior notes (in thousands)	March 31, 2016 December 31, 2015 Face Fair Face Fair Value Value Value Value 6.25% Notes $ $ $ $ 7.00% Notes $ $ $ $
Schedule of sensitivity of fair value measurement to changes in significant unobservable inputs	Significant Impact on Fair Value Unobservable Input Position Change to Input Measurement Location basis Long Increase (decrease) Gain (loss) Location basis Short Increase (decrease) Loss (gain) Transportation Long Increase (decrease) Gain (loss) Transportation Short Increase (decrease) Loss (gain) Throughput costs Long Increase (decrease) Gain (loss) Throughput costs Short Increase (decrease) Loss (gain)
Summary of the changes in fair value of Level 3 financial assets and liabilities (in thousands)	Fair value at December 31, 2015 $ Realized and unrealized gains (losses) recorded in cost of sales Fair value at March 31, 2016 $

Changes in Accumulated Other 40

Changes in Accumulated Other Comprehensive Loss (Tables)	3 Months Ended
	Mar. 31, 2016
Changes in Accumulated Other Comprehensive Loss
Schedule of changes in accumulated other comprehensive loss (in thousands)	Pension Three Months Ended March 31, 2016 Plan Derivatives Total Balance at December 31, 2015 $ $ $ Other comprehensive income before reclassifications of gain (loss) Amount of gain (loss) reclassified from accumulated other comprehensive income — Total comprehensive income Balance at March 31, 2016 $ $ $

Supplemental Guarantor Conden41

Supplemental Guarantor Condensed Consolidating Financial Information (Tables)	3 Months Ended
	Mar. 31, 2016
Supplemental Guarantor Condensed Consolidating Financial Statements
Schedule of condensed consolidating balance sheets	Condensed Consolidating Balance Sheet March 31, 2016 (In thousands) Issuer Non- Guarantor Guarantor Subsidiaries Subsidiary Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ $ $ — $ Accounts receivable, net — Accounts receivable - affiliates Inventories — — Brokerage margin deposits — — Derivative assets — — Prepaid expenses and other current assets — Total current assets Property and equipment, net — — Intangible assets, net — Goodwill — Other assets — — Total assets $ $ $ $ Liabilities and partners' equity Current liabilities: Accounts payable $ $ $ — $ Accounts payable - affiliates — Working capital revolving credit facility - current portion — — Environmental liabilities - current portion — — Trustee taxes payable — — Accrued expenses and other current liabilities — Derivative liabilities — — Total current liabilities Working capital revolving credit facility - less current portion — — Revolving credit facility — — Senior notes — — Environmental liabilities - less current portion — — Financing obligation — — Deferred tax liabilities — — Other long-term liabilities — — Total liabilities Partners' equity Global Partners LP equity — Noncontrolling interest — — Total partners' equity — Total liabilities and partners' equity $ $ $ $ Condensed Consolidating Balance Sheet December 31, 2015 (In thousands) Issuer Non- Guarantor Guarantor Subsidiaries Subsidiary Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ — $ $ $ Accounts receivable, net — Accounts receivable - affiliates Inventories — — Brokerage margin deposits — — Derivative assets — — Prepaid expenses and other current assets — Total current assets Property and equipment, net — Intangible assets, net — — Goodwill — Other assets — — Total assets $ $ $ $ Liabilities and partners' equity Current liabilities: Cash overdraft $ $ — $ $ — Accounts payable — Accounts payable - affiliates — Working capital revolving credit facility - current portion — — Environmental liabilities - current portion — — Trustee taxes payable — — Accrued expenses and other current liabilities — Derivative liabilities — — Total current liabilities Working capital revolving credit facility - less current portion — — Revolving credit facility — — Senior notes — — Environmental liabilities - less current portion — — Financing obligation — — Deferred tax liabilities — — Other long-term liabilities — — Total liabilities Partners' equity Global Partners LP equity — Noncontrolling interest — — Total partners' equity — Total liabilities and partners' equity $ $ $ $
Schedule of condensed consolidating statements of income	Condensed Consolidating Statement of Operations Three Months Ended March 31, 2016 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Eliminations Consolidated Sales $ $ $ $ Cost of sales Gross profit — Costs and operating expenses: Selling, general and administrative expenses — Operating expenses — Amortization expense — — Loss on sale and disposition of assets and impairment charges — — Total costs and operating expenses — Operating income (loss) — Interest expense — — Loss before income tax benefit — Income tax benefit — — Net loss — Net loss attributable to noncontrolling interest — — Net loss attributable to Global Partners LP — Less: General partner's interest in net loss, including incentive distribution rights — — Limited partners' interest in net loss $ $ $ — $ Condensed Consolidating Statement of Operations Three Months Ended March 31, 2015 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Eliminations Consolidated Sales $ $ $ $ Cost of sales Gross profit — Costs and operating expenses: Selling, general and administrative expenses — Operating expenses — Amortization expense — Loss on sale and disposition of assets and impairment charges — — Total costs and operating expenses — Operating income (loss) — Interest expense — Income (loss) before income tax expense — Income tax expense — — Net income (loss) — Net loss attributable to noncontrolling interest — — Net income (loss) attributable to Global Partners LP — Less: General partner's interest in net income, including incentive distribution rights — — Limited partners' interest (loss) in net income $ $ $ — $
Schedule of condensed consolidating statements of cash flows	Condensed Consolidating Statement Cash Flows Three Months Ended March 31, 2016 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Consolidated Cash flows from operating activities Net cash used in operating activities $ $ $ Cash flows from investing activities Capital expenditures — Proceeds from sale of property and equipment — Net cash used in investing activities — Cash flows from financing activities Net borrowings from working capital revolving credit facility — Net borrowings from revolving credit facility — Noncontrolling interest capital contribution Distribution to noncontrolling interest — Distributions to partners — Net cash provided by (used in) financing activities Cash and cash equivalents Increase (decrease) in cash and cash equivalents Cash and cash equivalents at beginning of period Cash and cash equivalents at end of period $ $ $ Condensed Consolidating Statement Cash Flows Three Months Ended March 31, 2015 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Consolidated Cash flows from operating activities Net cash (used in) provided by operating activities $ $ $ Cash flows from investing activities Acquisitions — Capital expenditures Proceeds from sale of property and equipment — Net cash used in investing activities Cash flows from financing activities Net borrowings from working capital revolving credit facility — Net borrowings from revolving credit facility — Payments on line of credit — Repurchase of common units — Noncontrolling interest capital contribution — Distribution to noncontrolling interest — Distributions to partners — Net cash provided by (used in) financing activities Cash and cash equivalents (Decrease) increase in cash and cash equivalents Cash and cash equivalents at beginning of period Cash and cash equivalents at end of period $ $ $

Organization and Basis of Pre42

Organization and Basis of Presentation (Details)	Jan. 07, 2015store	Jun. 30, 2015shares	Dec. 31, 2014shares	Mar. 31, 2016itemshares	Mar. 31, 2015	Dec. 31, 2015shares	Feb. 01, 2013
Organization
Number of owned, leased and/or supplied gasoline stations | item				1,498
Number of convenience stores | item				274
General partner interest (as a percent)				0.67%	0.74%
Number of common units held				33,517,503		33,506,844
Number of common units sold		3,000,000
Affiliates of general partner
Organization
General partner interest (as a percent)				21.90%
Number of common units held				7,434,775
Warren Equities Inc
Organization
Number of convenience stores | store	147
Percentage of outstanding membership interests acquired	100.00%
Number of common units sold			3,565,000
Basin Transload LLC
Organization
Percentage of outstanding membership interests acquired							60.00%
Members of Slifka family
Organization
General partner interest (as a percent)						0.67%

Organization and Basis of Pre43

Organization and Basis of Presentation - Risk (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Concentration of Risk
Goodwill	$ 435,369		$ 435,369
Wholesale Segment
Concentration of Risk
Goodwill	121,700		121,700
Goodwill Impairment Maximum Future Amount	121,700
GDSO
Concentration of Risk
Goodwill	$ 313,700		$ 313,700
Sales Revenue, Product Line [Member] | Product
Concentration of Risk
Percentage of consolidated total	100.00%	100.00%
Sales Revenue, Product Line [Member] | Product | Gasoline sales: gasoline and gasoline blendstocks (such as ethanol)
Concentration of Risk
Percentage of consolidated total	57.00%	50.00%
Sales Revenue, Product Line [Member] | Product | Crude oil sales and crude oil logistics revenue
Concentration of Risk
Percentage of consolidated total	8.00%	9.00%
Sales Revenue, Product Line [Member] | Product | Distillates (home heating oil, diesel and kerosene), residual oil, natural gas and propane sales
Concentration of Risk
Percentage of consolidated total	30.00%	38.00%
Sales Revenue, Product Line [Member] | Product | Convenience store sales, rental income and sundry sales
Concentration of Risk
Percentage of consolidated total	5.00%	3.00%
Product Margin [Member] | Customer
Concentration of Risk
Percentage of consolidated total	100.00%	100.00%
Product Margin [Member] | Customer | Wholesale Segment
Concentration of Risk
Percentage of consolidated total	25.00%	42.00%
Product Margin [Member] | Customer | GDSO
Concentration of Risk
Percentage of consolidated total	70.00%	52.00%
Product Margin [Member] | Customer | Commercial Segment
Concentration of Risk
Percentage of consolidated total	5.00%	6.00%

Business Combinations (Details)

Business Combinations (Details) $ / shares in Units, $ in Thousands	Jun. 01, 2015USD ($)item	Jan. 14, 2015USD ($)	Jan. 07, 2015USD ($)storeitemlocation	Jun. 30, 2015shares	Dec. 31, 2014shares	Mar. 31, 2016USD ($)item	Mar. 31, 2015USD ($)$ / shares	Dec. 31, 2015USD ($)	Mar. 31, 2016USD ($)
Acquisitions
Number of convenience stores | item						274
Number of owned, leased and/or supplied gasoline stations | item						1,498
Number of common units sold | shares				3,000,000
Liabilities assumed:
Goodwill						$ 435,369		$ 435,369	$ 435,369
Goodwill [Roll Forward]
Goodwill, Beginning Balance						435,369
Sale Leaseback Transaction, Net Book Value [Abstract]
Financing obligation								89,790	89,845
GDSO
Liabilities assumed:
Goodwill						313,700		313,700	313,700
Goodwill [Roll Forward]
Goodwill, Beginning Balance						313,700
Wholesale Segment
Liabilities assumed:
Goodwill						121,700		121,700	121,700
Goodwill [Roll Forward]
Goodwill, Beginning Balance						121,700
Warren Equities Inc
Acquisitions
Percentage of outstanding membership interests acquired			100.00%
Number of convenience stores | store			147
Number of commission agent locations acquired | location			53
Number of dealers with fuel supply rights acquired | item			330
Purchase price			$ 381,800
Number of common units sold | shares					3,565,000
Acquisition related costs
Restructuring charge paid							$ 500	$ 1,800
Warren Equities Inc | Selling, general and administrative expenses
Acquisition related costs
Acquisition related costs incurred						4,400
Restructuring Charges							2,300
Revere terminal
Acquisitions
Purchase price		$ 23,700
Liabilities assumed:
Liability for contingent consideration		$ 0
Contingent consideration period		8 years
Capitol Petroleum Group
Acquisitions
Number of dealers with fuel supply rights acquired | item	7
Number of owned, leased and/or supplied gasoline stations | item	97
Purchase price	$ 155,700
Sale Leaseback Transaction, Net Book Value [Abstract]
Number of Agreements | item	2
Interest expense for sale-leaseback properties						2,400
Lease rental payments						$ 2,300
Financing obligation	$ 89,600								$ 89,800
Acquisition related costs
Acquisition related costs incurred							0
Business Acquisition, Pro Forma Information [Abstract]
Sales							3,114,370
Net income attributable to Global Partners LP							$ 32,810
Net income per limited partner unit, basic and diluted | $ / shares							$ 1

Net (Loss) Income Per Limited45

Net (Loss) Income Per Limited Partner Unit (Details) - USD ($) $ / shares in Units, $ in Thousands	Apr. 26, 2016	Jun. 30, 2015	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Net Income Per Limited Partner Unit
Repurchased units not deemed outstanding			478,060		488,719
Net (loss) income attributable to Global Partners LP			$ (7,024)	$ 30,415
Declared distribution			15,829	23,260
Assumed allocation of undistributed net (loss) income			(22,853)	7,155
Assumed allocation of net (loss) income			$ (7,024)	$ 30,415
Denominator:
Basic weighted average limited partner units outstanding			33,517,000	30,599,000
Diluted weighted average limited partner units outstanding			33,517,000	30,712,000
Basic net (loss) income per limited partner unit			$ (0.21)	$ 0.92
Diluted net (loss) income per limited partner unit			$ (0.21)	$ 0.92
Number of common units sold		3,000,000
General partner interest (as a percent)			0.67%	0.74%
Quarterly cash distribution declared (in dollars per unit)	$ 0.4625
Subsequent event
Denominator:
Quarterly cash distribution declared (in dollars per unit)	$ 0.4625
Common Unitholders
Net Income Per Limited Partner Unit
Net (loss) income attributable to Global Partners LP			$ (6,977)	$ 28,236
Declared distribution			15,723	21,076
Assumed allocation of undistributed net (loss) income			(22,700)	7,160
Assumed allocation of net (loss) income			$ (6,977)	$ 28,236
Denominator:
Basic weighted average limited partner units outstanding			33,517,000	30,599,000
Dilutive effect of phantom units				113,000
Diluted weighted average limited partner units outstanding			33,517,000	30,712,000
Basic net (loss) income per limited partner unit			$ (0.21)	$ 0.92
Diluted net (loss) income per limited partner unit			$ (0.21)	$ 0.92
General Partner
Net Income Per Limited Partner Unit
Net (loss) income attributable to Global Partners LP			$ (47)	$ 2,179
Declared distribution			106	157
Assumed allocation of undistributed net (loss) income			(153)	(5)
Assumed allocation of net (loss) income			$ (47)	152
Denominator:
General partner interest (as a percent)			0.67%
IDRs
Net Income Per Limited Partner Unit
Declared distribution				2,027
Assumed allocation of net (loss) income				$ 2,027

Inventories (Details)

Inventories (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Inventories
Inventories	$ 402,872	$ 388,952
Positive exchange balances on inventory exchange agreements accounted for as accounts receivable	9,300	3,400
Negative exchange balances on inventory exchange agreements accounted for as accounts payable	4,100	12,100
Distillates: home heating oil, diesel and kerosene
Inventories
Inventories	143,206	156,411
Gasoline
Inventories
Inventories	63,468	62,467
Gasoline blendstocks
Inventories
Inventories	41,897	32,542
Crude Oil
Inventories
Inventories	116,366	102,253
Residual Oil
Inventories
Inventories	17,236	12,895
Propane and other
Inventories
Inventories	1,639	1,469
Renewable identification numbers (RINs)
Inventories
Inventories	664	803
Convenience store inventory
Inventories
Inventories	$ 18,396	$ 20,112

Derivative Financial Instrume47

Derivative Financial Instruments (Details) - Mar. 31, 2016 CAD in Millions, $ in Millions	CADitem	USD ($)item
Exchange-Traded Derivatives | Long [Member]
Volume of activity related to derivative financial instruments
Nonmonetary units	56,203	56,203
Exchange-Traded Derivatives | Short [Member]
Volume of activity related to derivative financial instruments
Nonmonetary units	63,591	63,591
OTC Derivatives (Petroleum/Ethanol) | Long [Member]
Volume of activity related to derivative financial instruments
Nonmonetary units	8,006	8,006
OTC Derivatives (Petroleum/Ethanol) | Short [Member]
Volume of activity related to derivative financial instruments
Nonmonetary units	6,149	6,149
OTC Derivatives (Natural Gas) | Long [Member]
Volume of activity related to derivative financial instruments
Nonmonetary units	11,677	11,677
OTC Derivatives (Natural Gas) | Short [Member]
Volume of activity related to derivative financial instruments
Nonmonetary units	11,530	11,530
Interest rate swaps
Volume of activity related to derivative financial instruments
Monetary units | $		$ 200
Interest rate cap
Volume of activity related to derivative financial instruments
Monetary units | $		100
Forward foreign currency contracts
Volume of activity related to derivative financial instruments
Monetary units	CAD 1.1	$ 0.8
Forward rate of CAD to USD	1.2973	1.2973

Derivative Financial Instrume48

Derivative Financial Instruments - FV Hedges (Details) - Fair Value Hedge - Cost of sales - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Futures contracts
Fair values of derivative financial instruments
Amount of Gain (Loss) Recognized in Income on Derivatives	$ 27,839	$ 26,176
Inventories
Fair values of derivative financial instruments
Amount of Gain (Loss) Recognized in Income on Hedged Items	$ (24,175)	$ (23,621)

Derivative Financial Instrume49

Derivative Financial Instruments - CF Hedges (Details)	Mar. 31, 2016USD ($)item	Dec. 31, 2015USD ($)	Jun. 19, 2014USD ($)	Sep. 30, 2013USD ($)	Apr. 30, 2011USD ($)	Oct. 31, 2009USD ($)
Senior Notes 6.25 Percent Due 2022
Fair values of derivative financial instruments
Aggregate principal amount	$ 375,000,000	$ 375,000,000	$ 375,000,000
Cash Flow Hedges
Fair values of derivative financial instruments
Hedged borrowings	200,000,000
Cash Flow Hedges | Working Capital Facility [Member] | London Interbank Offered Rate (LIBOR) [Member]
Fair values of derivative financial instruments
Hedged borrowings	$ 300,000,000
Cash Flow Hedges | Interest rate swaps
Fair values of derivative financial instruments
Number of agreements in place | item	2
Cash Flow Hedges | Interest rate swaps | Credit Agreement Maturing 2018 [Member] | London Interbank Offered Rate (LIBOR) [Member]
Fair values of derivative financial instruments
Hedged borrowings				$ 100,000,000		$ 100,000,000
Fixed rate (as a percent)				1.819%		3.93%
Cash Flow Hedges | Interest rate cap | Credit Agreement Maturing 2018 [Member] | London Interbank Offered Rate (LIBOR) [Member]
Fair values of derivative financial instruments
Hedged borrowings					$ 100,000,000
Maximum cap rate (as a percent)					5.50%

Derivative Financial Instrume50

Derivative Financial Instruments - CF Hedges Gain, Loss (Details) - Cash Flow Hedges - Derivatives designated as hedging instruments - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Gains and losses from derivatives
Gain (Loss) on Interest Rate Cash Flow Hedge Ineffectiveness	$ 0	$ 0
Interest rate swaps
Gains and losses from derivatives
Amount of Gain (Loss) Recognized in Other Comprehensive Income on Derivatives	$ 28	$ 47

Derivative Financial Instrume51

Derivative Financial Instruments - Not Designated (Details) - Derivatives not designated as hedging instruments $ in Thousands	3 Months Ended
	Mar. 31, 2016USD ($)item	Mar. 31, 2015USD ($)
Derivative Financial Instruments
Amount of Gain (Loss) Recognized in Income on Derivatives	$ (376)	$ 3,669
Commodity product | Cost of sales
Derivative Financial Instruments
Amount of Gain (Loss) Recognized in Income on Derivatives	$ (415)	3,651
Commodity product | Maximum
Derivative Financial Instruments
Aggregate units of products in a controlled trading program | item	250,000
Foreign currency derivatives | Cost of sales
Derivative Financial Instruments
Amount of Gain (Loss) Recognized in Income on Derivatives	$ 39	$ 18

Derivative Financial Instrume52

Derivative Financial Instruments - Fair Value (Details) $ in Thousands	Mar. 31, 2016USD ($)item	Dec. 31, 2015USD ($)
Fair values of derivative financial instruments
Asset Derivatives	$ 85,855	$ 161,476
Liability Derivatives	$ 70,786	35,254
Credit Risk
Number of clearing brokers, primarily utilized | item	3
Exchange-Traded Derivatives | Broker margin deposits
Fair values of derivative financial instruments
Asset Derivatives	$ 42,458	95,367
Liability Derivatives	41,535
Forward derivative contracts | Derivative assets
Fair values of derivative financial instruments
Asset Derivatives	43,397	66,099
Forward derivative contracts | Derivative liabilities
Fair values of derivative financial instruments
Liability Derivatives	25,923	31,911
Forward foreign currency contracts | Other assets
Fair values of derivative financial instruments
Asset Derivatives		10
Forward foreign currency contracts | Accrued Expenses And Other Current Liabilities Caption [Member]
Fair values of derivative financial instruments
Liability Derivatives	13
Interest rate cap | Other long-term liabilities
Fair values of derivative financial instruments
Liability Derivatives	3,315
Interest rate swaps | Other long-term liabilities
Fair values of derivative financial instruments
Liability Derivatives		3,343
Derivatives designated as hedging instruments
Fair values of derivative financial instruments
Asset Derivatives	2,305	83,645
Liability Derivatives	22,276
Derivatives designated as hedging instruments | Exchange-Traded Derivatives | Broker margin deposits
Fair values of derivative financial instruments
Asset Derivatives	2,305	83,645
Liability Derivatives	22,276
Derivatives not designated as hedging instruments
Fair values of derivative financial instruments
Asset Derivatives	83,550	77,831
Liability Derivatives	48,510	35,254
Derivatives not designated as hedging instruments | Exchange-Traded Derivatives | Broker margin deposits
Fair values of derivative financial instruments
Asset Derivatives	40,153	11,722
Liability Derivatives	19,259
Derivatives not designated as hedging instruments | Forward derivative contracts | Derivative assets
Fair values of derivative financial instruments
Asset Derivatives	43,397	66,099
Derivatives not designated as hedging instruments | Forward derivative contracts | Derivative liabilities
Fair values of derivative financial instruments
Liability Derivatives	25,923	31,911
Derivatives not designated as hedging instruments | Forward foreign currency contracts | Other assets
Fair values of derivative financial instruments
Asset Derivatives		10
Derivatives not designated as hedging instruments | Forward foreign currency contracts | Accrued Expenses And Other Current Liabilities Caption [Member]
Fair values of derivative financial instruments
Liability Derivatives	13
Derivatives not designated as hedging instruments | Interest rate cap | Other long-term liabilities
Fair values of derivative financial instruments
Liability Derivatives	$ 3,315
Derivatives not designated as hedging instruments | Interest rate swaps | Other long-term liabilities
Fair values of derivative financial instruments
Liability Derivatives		$ 3,343

Debt (Details)

Debt (Details)	Oct. 22, 2015	Jun. 04, 2015USD ($)	Jun. 01, 2015USD ($)item	Apr. 21, 2015	Jun. 24, 2014USD ($)	Mar. 31, 2016USD ($)item	Mar. 31, 2015USD ($)	Dec. 31, 2015USD ($)	Feb. 24, 2016USD ($)	Feb. 23, 2016USD ($)	Jun. 19, 2014USD ($)
Debt
Working Capital Revolving Credit Facility, Current						$ 185,200,000		$ 98,100,000
Working Capital Revolving Credit Facility, Noncurrent						150,000,000		150,000,000
Financing obligation						89,845,000		89,790,000
Deferred financing fees capitalized						17,800,000		19,000,000
Write-off of a portion of the original issue discount and deferred financing fees						1,828,000
Amortization expenses						1,429,000	$ 1,459,000
Capitol Petroleum Group
Debt
Financing obligation			$ 89,600,000			89,800,000
Number of sale-leaseback transactions | item			2
Number of locations acquired | item			53
Sale Leaseback Transaction, Rent Expense						2,300,000
Interest Expense, Lessee, Assets under Capital Lease						2,400,000
Long-Term Debt Caption [Member]
Debt
Unamortized financing fees						7,500,000		7,800,000
Interest Expense [Member]
Debt
Amortization expenses						1,400,000	$ 1,500,000
Credit Agreement Maturing 2018 [Member]
Debt
Total available commitments						$ 1,775,000,000
Number of line of credit facilities | item						2
Servicing obligation						$ 0
Average interest rates (as a percent)						3.80%	3.40%
Number of interest rate swaps | item						2
Total borrowings outstanding						$ 610,300,000
Total remaining availability for borrowings and letters of credit						806,800,000		1,200,000,000
Credit Agreement Maturing 2018 [Member] | Other Assets, Current and Noncurrent [Member]
Debt
Unamortized financing fees						10,300,000		11,200,000
All Revolving credit facilities
Debt
Total available commitments									$ 1,475,000,000
Working Capital Facility [Member]
Debt
Total available commitments						900,000,000,000		1,000,000		$ 1,000,000,000
Line of Credit Facility Estimated Borrowings in Next Year						150,000,000
Long-term portion						150,000,000		150,000,000
Working Capital Revolving Credit Facility, Current						185,200,000		98,100,000
Increased credit facility						87,100,000
Working Capital Facility [Member] | Interest Expense [Member]
Debt
Write-off of a portion of the original issue discount and deferred financing fees						1,800,000
Credit Facility Swingline Feature [Member]
Debt
Total available commitments						50,000,000
Revolving Credit Facility [Member]
Debt
Total available commitments						575,000,000		775,000,000		$ 775,000,000
Total borrowings outstanding						275,100,000
Credit Facility Accordion Feature [Member]
Debt
Total available commitments						300,000,000
Letter of credit
Debt
Outstanding letters of credit						57,900,000
Senior Notes 6.25 Percent Due 2022
Debt
Aggregate principal amount						375,000,000		375,000,000			$ 375,000,000
Stated interest rate (as a percent)					6.25%						6.25%
Minimum percentage of principal amount held by trustee or the holders to declare notes due and payable					0.25%
Indebtedness unpaid or accelerated debt triggering debt default					$ 15,000,000
Period for payment of default					60 days
Percentage Of Senior Notes Exchanged To SEC Registered Notes				100.00%
Senior Notes 7.00 Percent Due 2023 [Member]
Debt
Aggregate principal amount			$ 300,000,000			$ 300,000,000		$ 300,000,000
Stated interest rate (as a percent)			7.00%
Minimum percentage of principal amount held by trustee or the holders to declare notes due and payable		25.00%
Percentage of principal amount that the Partnership may redeem		35.00%
Indebtedness unpaid or accelerated debt triggering debt default		$ 50,000,000
Period for payment of default		60 days
Percentage Of Senior Notes Exchanged To SEC Registered Notes	100.00%
Maximum | Credit Agreement Maturing 2018 [Member]
Debt
Commitment fee on the unused portion (as a percent)						0.50%
Total Combined Leverage Ration, 1st period						5.50
Total Combined Leverage Ratio, thereafter						5
Minimum | Credit Agreement Maturing 2018 [Member]
Debt
Commitment fee on the unused portion (as a percent)						0.375%
Eurocurrency/Eurodollar rate | Maximum | Working Capital Facility [Member]
Debt
Interest rate margin (as a percent)						2.50%
Eurocurrency/Eurodollar rate | Maximum | Revolving Credit Facility [Member]
Debt
Interest rate margin (as a percent)						3.50%
Eurocurrency/Eurodollar rate | Minimum | Working Capital Facility [Member]
Debt
Interest rate margin (as a percent)						2.00%
Eurocurrency/Eurodollar rate | Minimum | Revolving Credit Facility [Member]
Debt
Interest rate margin (as a percent)						2.25%
Cost of funds rate | Maximum | Working Capital Facility [Member]
Debt
Interest rate margin (as a percent)						2.50%
Cost of funds rate | Maximum | Revolving Credit Facility [Member]
Debt
Interest rate margin (as a percent)						3.50%
Cost of funds rate | Minimum | Working Capital Facility [Member]
Debt
Interest rate margin (as a percent)						2.00%
Cost of funds rate | Minimum | Revolving Credit Facility [Member]
Debt
Interest rate margin (as a percent)						2.25%
Base rate | Maximum | Working Capital Facility [Member]
Debt
Interest rate margin (as a percent)						1.50%
Base rate | Maximum | Revolving Credit Facility [Member]
Debt
Interest rate margin (as a percent)						2.50%
Base rate | Minimum | Working Capital Facility [Member]
Debt
Interest rate margin (as a percent)						1.00%
Base rate | Minimum | Revolving Credit Facility [Member]
Debt
Interest rate margin (as a percent)						1.25%
Debt Instrument, Redemption, Period One [Member] | Senior Notes 6.25 Percent Due 2022
Debt
Percentage of principal amount that the Partnership may redeem					35.00%
Redemption price as a percentage of principal amount					106.25%
Debt Instrument, Redemption, Period One [Member] | Senior Notes 7.00 Percent Due 2023 [Member]
Debt
Redemption price as a percentage of principal amount		107.00%
Debt Instrument, Redemption, Period Two [Member] | Senior Notes 6.25 Percent Due 2022
Debt
Redemption price as a percentage of principal amount					104.688%
Debt Instrument, Redemption, Period Two [Member] | Senior Notes 7.00 Percent Due 2023 [Member]
Debt
Redemption price as a percentage of principal amount		105.25%
Debt Instrument, Redemption, Period Three [Member] | Senior Notes 6.25 Percent Due 2022
Debt
Redemption price as a percentage of principal amount					103.125%
Debt Instrument, Redemption, Period Three [Member] | Senior Notes 7.00 Percent Due 2023 [Member]
Debt
Redemption price as a percentage of principal amount		103.50%
Debt Instrument, Redemption, Period Four [Member] | Senior Notes 6.25 Percent Due 2022
Debt
Redemption price as a percentage of principal amount					101.563%
Debt Instrument, Redemption, Period Four [Member] | Senior Notes 7.00 Percent Due 2023 [Member]
Debt
Redemption price as a percentage of principal amount		101.75%
Debt Instrument, Redemption, Period Five [Member] | Senior Notes 6.25 Percent Due 2022
Debt
Redemption price as a percentage of principal amount					100.00%
Debt Instrument, Redemption, Period Five [Member] | Senior Notes 7.00 Percent Due 2023 [Member]
Debt
Redemption price as a percentage of principal amount		100.00%

Related-Party Transactions (Det

Related-Party Transactions (Details) - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Information on related party transaction
Receivables from related parties	$ 3,482,000		$ 2,578,000
GPC
Information on related party transaction
Receivables from related parties	7,000
GPC | Terminal Storage Rental and Throughput Agreement [Member]
Information on related party transaction
Expenses incurred from transactions with related parties	$ 0	$ 800,000
GPC | Terminal Storage Rental and Throughput Agreement [Member] | Members of Slifka family
Related Party Transactions
Equity Method Investment, Ownership Percentage	100.00%
GPC | GPC Amended and Restated Services Agreement [Member]
Information on related party transaction
Related party amounts recorded as selling, general and administrative expenses	$ 0	8,000
Notice period to terminate the receipt of services under the agreement	90 days
AE Holdings | AEH Amended and Restated Services Agreement [Member]
Information on related party transaction
Amount to be received per year	$ 15,000
General Partner
Information on related party transaction
Expenses incurred from transactions with related parties	25,600,000	$ 29,400,000
Receivables from related parties	$ 3,475,000		$ 2,578,000

Partners' Equity and Cash Dis55

Partners' Equity and Cash Distributions (Details) $ / shares in Units, $ in Thousands	Apr. 26, 2016$ / shares	Feb. 16, 2016USD ($)$ / shares	Mar. 31, 2016item$ / sharesshares	Mar. 31, 2015	Dec. 31, 2015shares
Partners' Equity and Cash Distributions
General partner interest (as a percent)			0.67%	0.74%
Repurchased units not deemed outstanding | shares			478,060		488,719
Period of distribution of available cash after end of each quarter			45 days
Number of quarters of cash reserves to provide funds for distributions to unitholders and General Partner | item			4
Cash Distribution Payment
Per Unit Cash Distribution (in dollars per unit)		$ 0.4625
Cash distribution | $		$ 15,829
Distribution declared
Quarterly cash distribution declared (in dollars per unit)	$ 0.4625
Affiliates of general partner
Partners' Equity and Cash Distributions
General partner interest (as a percent)			21.90%
Subsequent event
Distribution declared
Quarterly cash distribution declared (in dollars per unit)	0.4625
Subsequent event | Annualized basis
Distribution declared
Quarterly cash distribution declared (in dollars per unit)	1.85
Common Unitholders
Partners' Equity and Cash Distributions
Units issued | shares			33,995,563
Distribution declared
Quarterly cash distribution declared (in dollars per unit)	0.4625
Common Unitholders | Annualized basis
Distribution declared
Quarterly cash distribution declared (in dollars per unit)	$ 1.85
Common Unitholders | Affiliates of general partner
Partners' Equity and Cash Distributions
Units issued | shares			7,434,775
General Partner Interest
Partners' Equity and Cash Distributions
Units issued | shares			230,303
Common Unitholders
Partners' Equity and Cash Distributions
Limited partner ownership interest (as a percent)			99.33%
Cash Distribution Payment
Cash distribution | $		15,723
General Partner
Partners' Equity and Cash Distributions
General partner interest (as a percent)			0.67%
Cash Distribution Payment
Cash distribution | $		$ 106
First Target Distribution | Maximum
Partners' Equity and Cash Distributions
Total Quarterly Distribution Target Amount (in dollars per unit)			$ 0.4625
First Target Distribution | Common Unitholders | Common Unitholders
Partners' Equity and Cash Distributions
Marginal Percentage Interest in Distributions			99.33%
First Target Distribution | General Partner | General Partner Interest
Partners' Equity and Cash Distributions
Marginal Percentage Interest in Distributions			0.67%
Second Target Distribution | Minimum
Partners' Equity and Cash Distributions
Total Quarterly Distribution Target Amount (in dollars per unit)			$ 0.4625
Second Target Distribution | Maximum
Partners' Equity and Cash Distributions
Total Quarterly Distribution Target Amount (in dollars per unit)			$ 0.5375
Second Target Distribution | Common Unitholders | Common Unitholders
Partners' Equity and Cash Distributions
Marginal Percentage Interest in Distributions			86.33%
Second Target Distribution | General Partner | General Partner Interest
Partners' Equity and Cash Distributions
Marginal Percentage Interest in Distributions			13.67%
Third Target Distribution | Minimum
Partners' Equity and Cash Distributions
Total Quarterly Distribution Target Amount (in dollars per unit)			$ 0.5375
Third Target Distribution | Maximum
Partners' Equity and Cash Distributions
Total Quarterly Distribution Target Amount (in dollars per unit)			$ 0.6625
Third Target Distribution | Common Unitholders | Common Unitholders
Partners' Equity and Cash Distributions
Marginal Percentage Interest in Distributions			76.33%
Third Target Distribution | General Partner | General Partner Interest
Partners' Equity and Cash Distributions
Marginal Percentage Interest in Distributions			23.67%
Thereafter | Minimum
Partners' Equity and Cash Distributions
Total Quarterly Distribution Target Amount (in dollars per unit)			$ 0.6625
Thereafter | Common Unitholders | Common Unitholders
Partners' Equity and Cash Distributions
Marginal Percentage Interest in Distributions			51.33%
Thereafter | General Partner | General Partner Interest
Partners' Equity and Cash Distributions
Marginal Percentage Interest in Distributions			48.67%

Unitholders' Equity (Details)

Unitholders' Equity (Details) - USD ($) $ in Millions	May. 19, 2015	Jun. 30, 2015	Mar. 31, 2016
Number of common units sold		3,000,000
Common Unitholders | At The Market Offering Program
Aggregate offering price	$ 50
Number of common units sold			0

Segment Reporting (Details)

Segment Reporting (Details) $ in Thousands, gal in Millions	3 Months Ended
	Mar. 31, 2016USD ($)gal	Mar. 31, 2015USD ($)gal
Summarized financial information for the Partnership's reportable segments
Sales	$ 1,750,812	$ 2,979,116
Product margin	154,460	190,073
Depreciation allocated to cost of sales	(24,401)	(21,515)
Gross profit	130,059	168,558
Wholesale Segment
Summarized financial information for the Partnership's reportable segments
Sales	910,240	1,971,946
Product margin	39,238	80,093
Gasoline sales: gasoline and gasoline blendstocks (such as ethanol)
Summarized financial information for the Partnership's reportable segments
Sales	342,729	776,143
Product margin	16,362	29,829
Crude Oil
Summarized financial information for the Partnership's reportable segments
Sales	148,502	252,110
Product margin	(2,373)	15,257
Other oils and related products
Summarized financial information for the Partnership's reportable segments
Sales	419,009	943,693
Product margin	25,249	35,007
GDSO
Summarized financial information for the Partnership's reportable segments
Sales	701,288	780,409
Product margin	108,312	98,422
Gasoline
Summarized financial information for the Partnership's reportable segments
Sales	616,103	697,334
Product margin	65,387	61,699
Station operations
Summarized financial information for the Partnership's reportable segments
Sales	85,185	83,075
Product margin	42,925	36,723
Commercial Segment
Summarized financial information for the Partnership's reportable segments
Sales	139,284	226,761
Product margin	$ 6,910	$ 11,558
Intersegment transaction | GDSO
Summarized financial information for the Partnership's reportable segments
Sales volume supplied by Wholesale to GDSO (in gallons) | gal	111	110

Segment Reporting - Reconciliat

Segment Reporting - Reconciliation (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Reconciliation of the totals reported for the reportable segments to the applicable line items in the consolidated financial statements
Combined gross profit	$ 130,059	$ 168,558
Operating costs and expenses
Selling, general and administrative expenses	34,984	48,786
Operating expenses	72,236	68,656
Amortization expense	2,509	5,341
Loss on sale and disposition of assets and impairment charges	6,105	437
Total costs and operating expenses	115,834	123,220
Operating income	14,225	45,338
Interest expense	(22,980)	(13,963)
Income tax benefit (expense)	920	(966)
Net (loss) income	(7,835)	30,409
Net income attributable to noncontrolling interest	811	6
Net (loss) income attributable to Global Partners LP	(7,024)	30,415
Operating costs and expenses not allocated to operating segments
Operating costs and expenses
Selling, general and administrative expenses	34,984	48,786
Operating expenses	72,236	68,656
Amortization expense	2,509	5,341
Loss on sale and disposition of assets and impairment charges	6,105	437
Total costs and operating expenses	$ 115,834	$ 123,220

Segment Reporting - Assets (Det

Segment Reporting - Assets (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Segment assets
Total	$ 2,655,438	$ 2,663,675
Wholesale Segment
Segment assets
Total	791,417	774,352
Commercial Segment
Segment assets
Total	3,059	3,224
GDSO
Segment assets
Total	1,361,094	1,392,397
Unallocated
Segment assets
Total	$ 499,868	$ 493,702

Property and Equipment (Details

Property and Equipment (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2016USD ($)location	Mar. 31, 2015USD ($)	Dec. 31, 2015USD ($)location
Property and Equipment
Total property and equipment	$ 1,566,410		$ 1,569,840
Less accumulated depreciation	348,751		327,157
Total	1,217,659		1,242,683
Loss on sale and disposition of assets and impairment charges	6,105	$ 437
Other impairment charges	$ 0	0
Sites held for sale, expected period	12 months
Long-lived assets subject to impairment	$ 36,600
Property and Equipment [Member]
Property and Equipment
Assets held for sale	12,800		$ 7,400
Gain Loss on Sale of Property Plant Equipment [Member]
Property and Equipment
Impairment charges related to assets held-for-sale	$ 5,500	0
GDSO | Gas Stations [ Member ]
Property and Equipment
Number of sites classified as held for sale | location	28		15
GDSO | Gain Loss on Sale of Property Plant Equipment [Member]
Property and Equipment
Loss on sale and disposition of assets and impairment charges	$ 600	$ 400
Buildings, docks, terminal facilities and improvements
Property and Equipment
Total property and equipment	995,143		$ 992,917
Land
Property and Equipment
Total property and equipment	441,799		450,045
Fixtures and equipment
Property and Equipment
Total property and equipment	41,213		40,946
Construction in process
Property and Equipment
Total property and equipment	69,403		67,080
Construction in process | Cascade Kelly | Ethanol plants
Property and Equipment
Total	30,500		30,500
Capitalized internal use software
Property and Equipment
Total property and equipment	$ 18,852		$ 18,852

Environmental Liabilities, As61

Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers (Details) $ in Thousands	1 Months Ended		3 Months Ended
	Dec. 31, 2012USD ($)item	Jun. 30, 2010USD ($)item	Mar. 31, 2016USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Jun. 30, 2015USD ($)	Jan. 31, 2015USD ($)	Mar. 31, 2012USD ($)
Changes in environmental liabilities during the period
Balance at the beginning of the period			$ 73,233
Payments			(928)
Dispositions			(525)
Other Adjustments			360
Balance at the end of the period			72,140
Environmental liabilities
Current portion				$ 5,345	$ 5,350
Long-term portion				66,795	67,883
Total environmental liabilities			$ 73,233	72,140	73,233
Renewable Identification Numbers (RINs)
Settlement period of RVO			1 year
RIN Deficiency				100	400
Other long-term liabilities
Asset Retirement Obligations
Asset Retirement Obligations, Noncurrent				7,900	7,800
Retail Gasoline Stations
Changes in environmental liabilities during the period
Balance at the beginning of the period			$ 68,451
Payments			(922)
Dispositions			(525)
Other Adjustments			360
Balance at the end of the period			67,364
Environmental liabilities
Total environmental liabilities			68,451	67,364	68,451
Mutual Oil Gasoline Stations
Environmental Liabilities
Assumed environmental liabilities, recorded on an undiscounted basis	$ 600
Number of gasoline stations acquired | item	6
Alliance Gasoline Stations
Environmental Liabilities
Assumed environmental liabilities, recorded on an undiscounted basis								$ 16,100
ExxonMobil Gasoline Stations
Environmental Liabilities
Assumed environmental liabilities, recorded on an undiscounted basis				30,000
Terminals
Changes in environmental liabilities during the period
Balance at the beginning of the period			4,782
Payments			(6)
Balance at the end of the period			4,776
Environmental liabilities
Total environmental liabilities			$ 4,782	$ 4,776	$ 4,782
Terminals in Newburgh New York
Environmental Liabilities
Assumed environmental liabilities, recorded on an undiscounted basis		$ 1,500
Number of refined petroleum products terminals acquired | item		3
Capitol Petroleum Group | Retail Gasoline Stations
Environmental Liabilities
Assumed environmental liabilities, recorded on an undiscounted basis						$ 300
Revere terminal
Environmental Liabilities
Assumed environmental liabilities, recorded on an undiscounted basis							$ 3,100
Warren Equities Inc | Retail Gasoline Stations
Environmental Liabilities
Assumed environmental liabilities, recorded on an undiscounted basis							$ 36,500

Long-Term Incentive Plan (Detai

Long-Term Incentive Plan (Details) - USD ($)	3 Months Ended		12 Months Ended			80 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2015
Long-Term Incentive Plan
Number of common units initially authorized for issuance under LTIP (in shares)	4,300,000
Vested (in shares)	(10,659)
Number of Non-vested Units
Outstanding non-vested units at the beginning of the period (in shares)	595,720
Vested (in shares)	(10,659)
Outstanding non-vested units at the end of the period (in shares)	585,061		595,720			595,720
Weighted Average Grant Date Fair Value
Outstanding non-vested units at the beginning of the period (in dollars per share)	$ 38.85
Vested (in dollars per share)	35.94
Outstanding non-vested units at the end of the period (in dollars per share)	$ 38.91		$ 38.85			$ 38.85
Repurchase Program
Aggregate common units authorized to be acquired (in shares)	1,242,427
Common units repurchased by General Partner (in shares)	0					838,505
Common units repurchased by General Partner						$ 24,800,000
Repurchased units not deemed outstanding	478,060		488,719			488,719
CEO Authorized LTIP
Long-Term Incentive Plan
Number of years for which Plan was approved	3 years
Aggregate amount of CEO authorized shares to grant in each calendar year				$ 2,000,000
Maximum value of grant	$ 550,000
CEO Authorized LTIP expiration period	6 years
Phantom Unit Awards [Member]
Long-Term Incentive Plan
Phantom units granted (in shares)	0		76,893	44,902	498,112
Compensation cost related to the non-vested awards not yet recognized	$ 13,300,000
Number of Non-vested Units
Granted (in shares)	0		76,893	44,902	498,112
Phantom Unit Awards [Member] | Selling, general and administrative expenses
Long-Term Incentive Plan
Compensation expenses for phantom unit awards	$ 1,100,000	$ 1,000,000

Fair Value Measurements (Detail

Fair Value Measurements (Details)	3 Months Ended
	Mar. 31, 2016USD ($)$ / item	Mar. 31, 2015$ / item	Dec. 31, 2015USD ($)	Jun. 01, 2015USD ($)	Jun. 24, 2014	Jun. 19, 2014USD ($)
Senior Notes 6.25 Percent Due 2022
Liabilities:
Stated interest rate (as a percent)					6.25%	6.25%
Face value of debt instrument	$ 375,000,000		$ 375,000,000			$ 375,000,000
Fair value of debt instrument	277,500,000		307,500,000
Senior Notes 7.00 Percent Due 2023 [Member]
Liabilities:
Stated interest rate (as a percent)				7.00%
Face value of debt instrument	300,000,000		300,000,000	$ 300,000,000
Fair value of debt instrument	222,000,000		249,000,000
Level 3
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, beginning of period	64,000
Realized and unrealized gains (losses) recorded in cost of sales	(109,000)
Fair Value, end of period	$ (45,000)
Minimum | Level 3
Liabilities:
Estimated margin, crude oil (in dollars per barrel) | $ / item	1.35	7.45
Estimated margin, propane (in dollars per barrel) | $ / item	0.84
Maximum | Level 3
Liabilities:
Estimated margin, crude oil (in dollars per barrel) | $ / item	13.25	10.75
Estimated margin, propane (in dollars per barrel) | $ / item	8.40
Recurring basis
Assets:
Cash collateral netting	$ 37,932,000		(64,040,000)
Recurring basis | Exchange-Traded Derivatives
Assets:
Cash collateral netting	37,932,000		(64,040,000)
Recurring basis | Total estimated fair value
Assets:
Pension plans	16,612,000		16,886,000
Total assets	98,864,000		114,322,000
Liabilities:
Total liabilities	(29,251,000)		(35,254,000)
Recurring basis | Total estimated fair value | Forward derivative contracts
Assets:
Derivative assets	43,397,000		66,099,000
Liabilities:
Derivative liabilities	(25,923,000)		(31,255,000)
Recurring basis | Total estimated fair value | Swap agreements and option contracts
Liabilities:
Derivative liabilities	(13,000)		(656,000)
Recurring basis | Total estimated fair value | Foreign currency derivatives
Assets:
Derivative assets			10,000
Recurring basis | Total estimated fair value | Interest rate swaps
Liabilities:
Derivative liabilities	(3,315,000)		(3,343,000)
Recurring basis | Total estimated fair value | Exchange-Traded Derivatives
Assets:
Exchange-traded/cleared derivative instruments	38,855,000		31,327,000
Recurring basis | Total estimated fair value | Level 1
Assets:
Pension plans	16,612,000		16,886,000
Total assets	17,535,000		112,253,000
Recurring basis | Total estimated fair value | Level 1 | Exchange-Traded Derivatives
Assets:
Exchange-traded/cleared derivative instruments	923,000		95,367,000
Recurring basis | Total estimated fair value | Level 2
Assets:
Total assets	42,208,000		62,392,000
Liabilities:
Total liabilities	(28,017,000)		(31,601,000)
Recurring basis | Total estimated fair value | Level 2 | Forward derivative contracts
Assets:
Derivative assets	42,208,000		62,382,000
Liabilities:
Derivative liabilities	(24,689,000)		(27,602,000)
Recurring basis | Total estimated fair value | Level 2 | Swap agreements and option contracts
Liabilities:
Derivative liabilities	(13,000)		(656,000)
Recurring basis | Total estimated fair value | Level 2 | Foreign currency derivatives
Assets:
Derivative assets			10,000
Recurring basis | Total estimated fair value | Level 2 | Interest rate swaps
Liabilities:
Derivative liabilities	(3,315,000)		(3,343,000)
Recurring basis | Total estimated fair value | Level 3
Assets:
Total assets	1,189,000		3,717,000
Liabilities:
Total liabilities	(1,234,000)		(3,653,000)
Recurring basis | Total estimated fair value | Level 3 | Forward derivative contracts
Assets:
Derivative assets	1,189,000		3,717,000
Liabilities:
Derivative liabilities	$ (1,234,000)		$ (3,653,000)

Income Taxes (Details)

Income Taxes (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2016USD ($)item	Mar. 31, 2015USD ($)
Income Tax Expense (Benefit)	$ (920)	$ 966
Number of wholly owned subsidiaries which are taxable for federal and state income tax purposes | item	1
Parent Company [Member]
Income Tax Expense (Benefit)	$ 0

Legal Proceedings (Details)

Legal Proceedings (Details)	Feb. 03, 2016USD ($)	Oct. 05, 2015item	Mar. 31, 2016USD ($)a	Dec. 31, 2015USD ($)
Alleged Violations of Clean Air Act at Albany Terminal [Member]
Other legal proceedings
Terminal area (in acres) | a			63
Litigation Number of Plaintiffs Added | item		2
Damages sought	$ 37,500
Contract Dispute with Counterparty [Member]
Other legal proceedings
Estimated contract revenue, remainder of year				$ 13,200,000
Estimated contract revenue, after current year			$ 105,200,000
Contract term			4 years
Compliance with regulatory agencies | Transfer of Renewable Fuel Identification Numbers [Member]
Other legal proceedings
Damages sought			$ 12,000,000

Changes in Accumulated Other 66

Changes in Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Changes in Accumulated Other Comprehensive Loss
Balance, beginning of period	$ 693,984
Total other comprehensive income	329	$ 274
Balance, end of period	671,685
Derivatives
Changes in Accumulated Other Comprehensive Loss
Balance, beginning of period	(3,658)
Other comprehensive (loss) income before reclassifications of gain (loss)	261
Total other comprehensive income	261
Balance, end of period	(3,397)
Pension Plan
Changes in Accumulated Other Comprehensive Loss
Balance, beginning of period	(4,436)
Other comprehensive (loss) income before reclassifications of gain (loss)	77
Amount of gain (loss) reclassified from accumulated other comprehensive (loss) income	(9)
Total other comprehensive income	68
Balance, end of period	(4,368)
Accumulated Other Comprehensive Loss
Changes in Accumulated Other Comprehensive Loss
Balance, beginning of period	(8,094)
Other comprehensive (loss) income before reclassifications of gain (loss)	338
Amount of gain (loss) reclassified from accumulated other comprehensive (loss) income	(9)
Total other comprehensive income	329
Balance, end of period	$ (7,765)

Subsequent Events (Details)

Subsequent Events (Details)	Apr. 26, 2016$ / shares	Apr. 30, 2016location	Mar. 31, 2016location
Subsequent Events
Quarterly cash distribution declared (in dollars per unit)	$ 0.4625
Common Unitholders
Subsequent Events
Quarterly cash distribution declared (in dollars per unit)	0.4625
GDSO
Subsequent Events
Number of non-strategic sites | location			100
Annualized basis | Common Unitholders
Subsequent Events
Quarterly cash distribution declared (in dollars per unit)	1.85
Subsequent event
Subsequent Events
Quarterly cash distribution declared (in dollars per unit)	0.4625
Subsequent event | GDSO
Subsequent Events
Number of sites under sales agreement | location		86
Subsequent event | Annualized basis
Subsequent Events
Quarterly cash distribution declared (in dollars per unit)	$ 1.85

Supp Guarantor Cond Cons Fin St

Supp Guarantor Cond Cons Fin Stmts - B/S (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Dec. 31, 2015	Mar. 31, 2015	Dec. 31, 2014
Ownership interest (as a percent)	100.00%
Current assets:
Cash and cash equivalents	$ 17,069	$ 1,116	$ 6,345	$ 5,238
Accounts receivable, net	308,359	311,354
Accounts receivable-affiliates	3,482	2,578
Inventories	402,872	388,952
Brokerage margin deposits	38,855	31,327
Derivate assets	43,397	66,099
Prepaid expenses and other current assets	73,467	65,609
Total current assets	887,501	867,035
Property and equipment, net	1,217,659	1,242,683
Intangible assets, net	72,871	75,694
Goodwill	435,369	435,369
Other assets	42,038	42,894
Total assets	2,655,438	2,663,675
Current liabilities:
Accounts payable	255,798	303,781
Working capital revolving credit facility-current portion	185,200	98,100
Environmental liabilities-current portion	5,345	5,350
Trustee taxes payable	88,005	95,264
Accrued expenses and other current liabilities	44,584	60,328
Derivative liabilities	25,923	31,911
Total current liabilities	604,855	594,734
Working capital revolving credit facility-less current portion	150,000	150,000
Revolving credit facility	275,100	269,000
Senior notes	657,213	656,564
Environmental liabilities-less current portion	66,795	67,883
Financing obligation	89,845	89,790
Deferred tax liabilities	83,280	84,836
Other long-term liabilities	56,665	56,884
Total liabilities	1,983,753	1,969,691
Partners' equity
Total Global Partners LP equity	626,539	647,789
Noncontrolling interest	45,146	46,195
Total partners' equity	671,685	693,984
Total liabilities and partners' equity	2,655,438	2,663,675
Eliminations
Current assets:
Cash and cash equivalents		(3,574)
Accounts receivable-affiliates	(1,270)	(913)
Total current assets	(1,270)	(4,487)
Total assets	(1,270)	(4,487)
Current liabilities:
Cash overdraft		(3,574)
Accounts payable - affiliates	(1,270)	(913)
Total current liabilities	(1,270)	(4,487)
Total liabilities	(1,270)	(4,487)
Partners' equity
Total liabilities and partners' equity	(1,270)	(4,487)
(Issuer) Guarantor Subsidiaries
Current assets:
Cash and cash equivalents	13,149	(3,574)	2,469	2,560
Accounts receivable, net	308,190	311,079
Accounts receivable-affiliates	3,713	2,745
Inventories	402,872	388,952
Brokerage margin deposits	38,855	31,327
Derivate assets	43,397	66,099
Prepaid expenses and other current assets	72,986	65,376
Total current assets	883,162	865,578
Property and equipment, net	1,217,659	1,203,251
Intangible assets, net	36,273	75,694
Goodwill	349,306	349,306
Other assets	42,038	42,894
Total assets	2,528,438	2,536,723
Current liabilities:
Cash overdraft		3,574
Accounts payable	255,451	303,242
Accounts payable - affiliates	1,039	746
Working capital revolving credit facility-current portion	185,200	98,100
Environmental liabilities-current portion	5,345	5,350
Trustee taxes payable	88,005	95,264
Accrued expenses and other current liabilities	44,418	59,742
Derivative liabilities	25,923	31,911
Total current liabilities	605,381	597,929
Working capital revolving credit facility-less current portion	150,000	150,000
Revolving credit facility	275,100	269,000
Senior notes	657,213	656,564
Environmental liabilities-less current portion	66,795	67,883
Financing obligation	89,845	89,790
Deferred tax liabilities	83,280	84,836
Other long-term liabilities	56,665	56,884
Total liabilities	1,984,279	1,972,886
Partners' equity
Total Global Partners LP equity	544,159	563,837
Total partners' equity	544,159	563,837
Total liabilities and partners' equity	2,528,438	2,536,723
Non-Guarantor Subsidiary
Current assets:
Cash and cash equivalents	3,920	4,690	$ 3,876	$ 2,678
Accounts receivable, net	169	275
Accounts receivable-affiliates	1,039	746
Prepaid expenses and other current assets	481	233
Total current assets	5,609	5,944
Property and equipment, net		39,432
Intangible assets, net	36,598
Goodwill	86,063	86,063
Total assets	128,270	131,439
Current liabilities:
Accounts payable	347	539
Accounts payable - affiliates	231	167
Accrued expenses and other current liabilities	166	586
Total current liabilities	744	1,292
Total liabilities	744	1,292
Partners' equity
Total Global Partners LP equity	82,380	83,952
Noncontrolling interest	45,146	46,195
Total partners' equity	127,526	130,147
Total liabilities and partners' equity	$ 128,270	$ 131,439

Supp Guarantor Cond Cons Fin 69

Supp Guarantor Cond Cons Fin Stmts - I/S (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Sales	$ 1,750,812	$ 2,979,116
Cost of sales	1,620,753	2,810,558
Gross profit	130,059	168,558
Costs and operating expenses:
Selling, general and administrative expenses	34,984	48,786
Operating expenses	72,236	68,656
Amortization expense	2,509	5,341
Loss on sale and disposition of assets and impairment charges	6,105	437
Total costs and operating expenses	115,834	123,220
Operating income	14,225	45,338
Interest expense	(22,980)	(13,963)
(Loss) income before income tax benefit (expense)	(8,755)	31,375
Income tax benefit (expense)	920	(966)
Net (loss) income	(7,835)	30,409
Net income attributable to noncontrolling interest	811	6
Net (loss) income attributable to Global Partners LP	(7,024)	30,415
Less: General partner’s interest in net (loss) income, including incentive distribution rights	(47)	2,179
Limited partners' interest in net (loss) income	(6,977)	28,236
Eliminations
Sales	(2,102)	(4,119)
Cost of sales	(2,102)	(4,119)
(Issuer) Guarantor Subsidiaries
Sales	1,750,281	2,975,185
Cost of sales	1,620,015	2,812,472
Gross profit	130,266	162,713
Costs and operating expenses:
Selling, general and administrative expenses	34,751	48,026
Operating expenses	70,649	66,317
Amortization expense	2,509	2,586
Loss on sale and disposition of assets and impairment charges	6,105	437
Total costs and operating expenses	114,014	117,366
Operating income	16,252	45,347
Interest expense	(22,980)	(13,958)
(Loss) income before income tax benefit (expense)	(6,728)	31,389
Income tax benefit (expense)	920	(966)
Net (loss) income	(5,808)	30,423
Net (loss) income attributable to Global Partners LP	(5,808)	30,423
Less: General partner’s interest in net (loss) income, including incentive distribution rights	(47)	2,179
Limited partners' interest in net (loss) income	(5,761)	28,244
Non-Guarantor Subsidiary
Sales	2,633	8,050
Cost of sales	2,840	2,205
Gross profit	(207)	5,845
Costs and operating expenses:
Selling, general and administrative expenses	233	760
Operating expenses	1,587	2,339
Amortization expense		2,755
Total costs and operating expenses	1,820	5,854
Operating income	(2,027)	(9)
Interest expense		(5)
(Loss) income before income tax benefit (expense)	(2,027)	(14)
Net (loss) income	(2,027)	(14)
Net income attributable to noncontrolling interest	811	6
Net (loss) income attributable to Global Partners LP	(1,216)	(8)
Limited partners' interest in net (loss) income	(1,216)	$ (8)
Parent Company [Member]
Costs and operating expenses:
Income tax benefit (expense)	$ 0

Supp Guarantor Cond Cons Fin 70

Supp Guarantor Cond Cons Fin Stmts - SCF (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Cash flows from operating activities
Net cash used in operating activities	$ (53,516)	$ (113,915)
Cash flows from investing activities
Acquisitions		(405,478)
Capital expenditures	(16,451)	(14,045)
Proceeds from sale of property and equipment	8,588	1,044
Net cash used in investing activities	(7,863)	(418,479)
Cash flows from financing activities
Net borrowings from (payments on) working capital revolving credit facility	87,100	175,400
Net borrowings from revolving credit facility	6,100	383,600
Payments on line of credit		(700)
Repurchase of common units		(2,442)
Noncontrolling interest capital contribution	357	1,880
Distribution to noncontrolling interest	(595)	(1,880)
Distributions to partners	(15,630)	(22,357)
Net cash provided by financing activities	77,332	533,501
Cash and cash equivalents
Net Cash Provided by (Used in) Continuing Operations	15,953	1,107
Cash and cash equivalents at beginning of period	1,116	5,238
Cash and cash equivalents at end of period	17,069	6,345
Eliminations
Cash and cash equivalents
Cash and cash equivalents at beginning of period	(3,574)
(Issuer) Guarantor Subsidiaries
Cash flows from operating activities
Net cash used in operating activities	(53,341)	(117,146)
Cash flows from investing activities
Acquisitions		(405,478)
Capital expenditures	(16,451)	(12,712)
Proceeds from sale of property and equipment	8,588	1,044
Net cash used in investing activities	(7,863)	(417,146)
Cash flows from financing activities
Net borrowings from (payments on) working capital revolving credit facility	87,100	175,400
Net borrowings from revolving credit facility	6,100	383,600
Repurchase of common units		(2,442)
Noncontrolling interest capital contribution	952	1,880
Distribution to noncontrolling interest	(595)	(1,880)
Distributions to partners	(15,630)	(22,357)
Net cash provided by financing activities	77,927	534,201
Cash and cash equivalents
Net Cash Provided by (Used in) Continuing Operations	16,723	(91)
Cash and cash equivalents at beginning of period	(3,574)	2,560
Cash and cash equivalents at end of period	13,149	2,469
Non-Guarantor Subsidiary
Cash flows from operating activities
Net cash used in operating activities	(175)	3,231
Cash flows from investing activities
Capital expenditures		(1,333)
Net cash used in investing activities		(1,333)
Cash flows from financing activities
Payments on line of credit		(700)
Noncontrolling interest capital contribution	(595)
Net cash provided by financing activities	(595)	(700)
Cash and cash equivalents
Net Cash Provided by (Used in) Continuing Operations	(770)	1,198
Cash and cash equivalents at beginning of period	4,690	2,678
Cash and cash equivalents at end of period	$ 3,920	$ 3,876