Global Partners (GLP) 10-Q8 May 152015 Q1 Quarterly reportFinancial data

Company Profile

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
Document and Entity Information	Mar. 31, 2015	5-May-15
Document and Entity Information
Entity Registrant Name	GLOBAL PARTNERS LP
Entity Central Index Key	1323468
Document Type	10-Q
Document Period End Date	31-Mar-15
Amendment Flag	FALSE
Current Fiscal Year End Date	-19
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		30,995,563
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$6,345	$5,238
Accounts receivable, net	410,881	457,730
Accounts receivable-affiliates	3,845	3,903
Inventories	371,627	336,813
Brokerage margin deposits	33,737	17,198
Derivate assets	57,470	83,826
Prepaid expenses and other current assets	74,123	56,515
Total current assets	958,028	961,223
Property and equipment, net	1,174,083	825,051
Intangible assets, net	80,049	48,902
Goodwill	301,987	154,078
Other assets	54,637	50,723
Total assets	2,568,784	2,039,977
Current liabilities:
Accounts payable	307,520	456,619
Working capital revolving credit facility-current portion	125,400	0
Line of credit		700
Environmental liabilities-current portion	3,085	3,101
Trustee taxes payable	90,183	105,744
Accrued expenses and other current liabilities	60,918	82,820
Derivative liabilities	48,272	58,507
Total current liabilities	635,378	707,491
Working capital revolving credit facility-less current portion	150,000	100,000
Revolving credit facility	517,400	133,800
Senior notes	368,316	368,136
Environmental liabilities-less current portion	72,186	34,462
Deferred tax liability	120,708	14,078
Other long-term liabilities	61,811	45,854
Total liabilities	1,925,799	1,403,821
Global Partners LP equity:
Common unitholders (30,995,563 units issued and 30,542,344 outstanding at March 31, 2015 and 30,995,563 units issued and 30,604,961 outstanding at December 31, 2014)	605,533	599,406
General partner interest (0.74% interest with 230,303 equivalent units outstanding at March 31, 2015 and December 31, 2014)	1,222	788
Accumulated other comprehensive loss	-12,978	-13,252
Total Global Partners LP equity	593,777	586,942
Noncontrolling interest	49,208	49,214
Total partners' equity	642,985	636,156
Total liabilities and partners' equity	$2,568,784	$2,039,977

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical)	Mar. 31, 2015	Dec. 31, 2014
CONSOLIDATED BALANCE SHEETS
Common unitholders, units issued	30,995,563	30,995,563
Common unitholders, units outstanding	30,542,344	30,604,961
General partner interest (as a percent)	0.74%	0.74%
General partner interest, equivalent units outstanding	230,303	230,303

CONSOLIDATED_STATEMENTS_OF_INC

CONSOLIDATED STATEMENTS OF INCOME (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
CONSOLIDATED STATEMENTS OF INCOME
Sales	$2,979,116	$5,116,928
Cost of sales	2,810,558	4,957,904
Gross profit	168,558	159,024
Costs and operating expenses:
Selling, general and administrative expenses	48,786	37,298
Operating expenses	68,656	47,952
Amortization expense	5,341	4,528
Loss on asset sales	437	663
Total costs and operating expenses	123,220	90,441
Operating income	45,338	68,583
Interest expense	-13,963	-11,107
Income before income tax expense	31,375	57,476
Income tax expense	-966	-322
Net income	30,409	57,154
Net loss (income) attributable to noncontrolling interest	6	-144
Net income attributable to Global Partners LP	30,415	57,010
Less: General partner's interest in net income, including incentive distribution rights	2,179	1,508
Limited partners' interest in net income	$28,236	$55,502
Basic net income per limited partner unit (in dollars per unit)	$0.92	$2.04
Diluted net income per limited partner unit (in dollars per unit)	$0.92	$2.03
Basic weighted average limited partner units outstanding (in units)	30,599	27,261
Diluted weighted average limited partner units outstanding (in units)	30,712	27,296

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
Net income	$30,409	$57,154
Other comprehensive income:
Change in fair value of cash flow hedges	183	659
Change in pension liability	91	-609
Total other comprehensive income	274	50
Comprehensive income	30,683	57,204
Comprehensive loss (income) attributable to noncontrolling interest	6	-144
Comprehensive income attributable to Global Partners LP	$30,689	$57,060

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash flows from operating activities
Net income	$30,409	$57,154
Adjustments to reconcile net income to net cash (used in) provided by operating activities:
Depreciation and amortization	28,472	19,706
Amortization of deferred financing fees	1,459	1,283
Amortization of senior notes discount	179	105
Bad debt expense	35	250
Unit-based compensation expense	945	851
Loss on asset sales	437	663
Changes in operating assets and liabilities, excluding assets acquired:
Accounts receivable	52,186	41,898
Accounts receivable - affiliate	58	-234
Inventories	-15,614	112,328
Broker margin deposits	-16,539	6,599
Prepaid expenses, all other current assets and other assets	10,157	-11,416
Accounts payable	-170,646	-182,076
Trustee taxes payable	-21,099	701
Change in derivatives	16,121	17,252
Accrued expenses, all other current liabilities and other long-term liabilities	-30,475	-11,918
Net cash (used in) provided by operating activities	-113,915	53,146
Cash flows from investing activities
Acquisitions, net of cash acquired	405,478
Capital expenditures	-14,045	-13,075
Proceeds from sale of property and equipment	1,044	1,746
Net cash used in investing activities	-418,479	-11,329
Cash flows from financing activities
Borrowings from (payments on) working capital revolving credit facility	175,400	-20,200
Borrowings from revolving credit facility	383,600
Payments on line of credit	-700
Repurchase of common units	-2,442
Noncontrolling interest capital contribution	1,880	2,400
Distribution to noncontrolling interest	-1,880	-2,400
Distributions to partners	-22,357	-17,770
Net cash provided by (used in) financing activities	533,501	-37,970
Increase in cash and cash equivalents	1,107	3,847
Cash and cash equivalents at beginning of period	5,238	9,217
Cash and cash equivalents at end of period	6,345	13,064
Supplemental information
Cash paid during the period for interest	$18,860	$9,587

CONSOLIDATED_STATEMENTS_OF_PAR

CONSOLIDATED STATEMENTS OF PARTNERS' EQUITY (USD $)	Common Unitholders	General Partner Interest	Accumulated Other Comprehensive Loss	Noncontrolling Interest	Total
In Thousands, unless otherwise specified	Common Unitholders	General Partner Interest	Accumulated Other Comprehensive Loss	Noncontrolling Interest	Total
Balance at Dec. 31, 2014	$599,406	$788	($13,252)	$49,214	$636,156
Increase (Decrease) in Partners' Capital
Net income (loss)	28,236	2,179		-6	30,409
Noncontrolling interest capital contribution				1,880	1,880
Distribution to noncontrolling interest				-1,880	-1,880
Other comprehensive income			274		274
Unit-based compensation	945				945
Distributions to partners	-20,612	-1,745			-22,357
Repurchase of common units	-2,442				-2,442
Balance at Mar. 31, 2015	$605,533	$1,222	($12,978)	$49,208	$642,985

Organization_and_Basis_of_Pres

Organization and Basis of Presentation	3 Months Ended
	Mar. 31, 2015
Organization and Basis of Presentation
Organization and Basis of Presentation	Note 1.Organization and Basis of Presentation

	Organization

	Global Partners LP (the “Partnership”) is a midstream logistics and marketing master limited partnership formed in March 2005 engaged in the purchasing, selling and logistics of transporting petroleum and related products, including domestic and Canadian crude oil, gasoline and gasoline blendstocks (such as ethanol and naphtha), 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 owns, controls or has access to one of the largest terminal networks of refined petroleum products and renewable fuels in Massachusetts, Maine, Connecticut, Vermont, New Hampshire, Rhode Island, New York, New Jersey and Pennsylvania (collectively, the “Northeast”). The Partnership owns transload and storage terminals in North Dakota and Oregon that extend its origin-to-destination capabilities from the mid-continent region of the United States and Canada to the East and West Coasts. The Partnership is one of the largest distributors of gasoline, distillates, residual oil and renewable fuels to wholesalers, retailers and commercial customers in the New England states and New York. As of March 31, 2015, the Partnership had a portfolio of 1,447 owned, leased and/or supplied gasoline stations, including 287 convenience stores, primarily in the Northeast, Maryland and Virginia.

	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, through the Partnership’s wholly owned subsidiary, Global Companies LLC (“Global Companies”), the Partnership acquired the Revere terminal (the “Revere Terminal”) located in Boston Harbor in Revere, Massachusetts from Global Petroleum Corp. (“GPC”). See Note 2.

	Global GP LLC, the Partnership’s general partner (the “General Partner”), manages the Partnership’s operations and activities and employs its officers and substantially all of its personnel, except for most of its gasoline station and convenience store employees and certain union personnel who are employed by GMG or Drake Petroleum Company, Inc. (“Drake Petroleum”).

	The General Partner, which holds a 0.74% general partner interest in the Partnership, is owned by affiliates of the Slifka family. As of March 31, 2015, affiliates of the General Partner, including its directors and executive officers and their affiliates, owned 7,293,722 common units, representing a 23.5% limited partner interest.

	Ownership by affiliates of the General Partner decreased by approximately 4,446,575 common units (from 37.9% to 23.5%) primarily as a result of the liquidation and dissolution of AE Holdings Corp. (“AE Holdings”). Immediately prior to such liquidation and dissolution, the directors and executive officers of the General Partner were deemed to beneficially own the entire 5,850,000 common units that were then owned by AE Holdings. Upon the liquidation and dissolution of AE Holdings, the 5,850,000 common units were distributed to the stockholders of AE Holdings. An aggregate 1,956,234 common units were sold by the stockholders of AE Holdings to cover their respective tax liabilities resulting from their receipt of the common units. Approximately 2,306,960 common units of the original 5,850,000 common units are held by the directors and executive officers of the General Partner, and the remaining 1,586,806 common units are held by unaffiliated members of the Slifka family.

	Basis of Presentation

	The financial results of Warren and the Revere Terminal for the three months ended March 31, 2015 are included in the accompanying statements of income for the three months ended March 31, 2015. The accompanying consolidated financial statements as of March 31, 2015 and December 31, 2014 and for the three months ended March 31, 2015 and 2014 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, 2014 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, 2015 are not necessarily indicative of the results of operations that will be realized for the entire year ending December 31, 2015. The consolidated balance sheet at December 31, 2014 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, 2014.

	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 and gasoline blendstocks during the late spring and summer months than during the fall and winter. Travel and recreational activities are typically higher in these months in the geographic areas in which the Partnership operates, increasing the demand for gasoline and gasoline blendstocks that the Partnership distributes. Therefore, the Partnership’s volumes in gasoline and gasoline blendstocks 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 sales 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.

	Reclassification

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

	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 statement 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 statement 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 income.

	Concentration of Risk

	The following table presents the Partnership’s sales, logistics revenue and rental income as a percentage of the consolidated sales for the periods presented:
		Three Months Ended
		March 31,
		2015	2014
	Gasoline sales: gasoline and gasoline blendstocks such as ethanol and naphtha	50%	54%
	Crude oil sales and logistics revenue	9%	12%
	Distillates (home heating oil, diesel and kerosene), residual oil, natural gas and propane sales	38%	33%
	Convenience store sales, rental income and sundry sales	3%	1%
	Total	100%	100%

	None of the Partnership’s customers were significant for the three months ended March 31, 2015. The Partnership had one significant customer, ExxonMobil Corporation (“ExxonMobil”) that accounted for approximately 14% of total sales for the three months ended March 31, 2014.

Business_Combinations

Business Combinations	3 Months Ended
Business Combinations	Mar. 31, 2015
Business Combinations
Business Combinations	Note 2.Business Combinations

	Acquisition of 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 320 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.

	The purchase price allocation is considered preliminary, and additional adjustments may be recorded during the allocation period in accordance with the FASB’s guidance regarding business combinations. The purchase price allocation will be finalized as the Partnership receives additional information relevant to the acquisition, including a final valuation of the assets purchased, including tangible and intangible assets, and liabilities assumed.

	The following table presents the preliminary allocation of the purchase price to the estimated fair value of the assets acquired and liabilities assumed at the date of acquisition (in thousands):
	Assets purchased:
	Accounts receivable		$	5,372
	Inventory		19,199
	Prepaid expenses		12,552
	Property and equipment		331,291
	Intangibles		36,490
	Other non-current assets		20,586
	Total identifiable assets purchased		425,490
	Liabilities assumed:
	Accounts payable		(21,511		)
	Assumption of environmental liabilities		(36,080		)
	Taxes payable		(5,538		)
	Accrued expenses		(11,595		)
	Long-term deferred taxes		(105,855		)
	Other non-current liabilities		(10,992		)
	Total liabilities assumed		(191,571		)
	Net identifiable assets acquired		233,919
	Goodwill		147,909
	Net assets acquired		$	381,828

	Management is currently in the process of evaluating the purchase price accounting. The Partnership has engaged a third-party valuation firm to assist in the valuation of Warren’s property and equipment, intangibles and leasehold interests. This valuation continues to be in progress and, during the quarter ended March 31, 2015, the Partnership received preliminary fair values of these assets. The estimated fair values of property and equipment of $331.3 million and intangibles assets, primarily supply contracts, of $36.5 million were developed by management based on their estimates, assumptions and acquisition history including preliminary reports from a third-party valuation firm. The estimated fair values of the property and equipment, intangibles and leasehold interests will be supported by valuations performed by a third party.

	The fair value of $36.1 million assigned to the assumption of environmental liabilities was estimated by management based on their estimates, assumptions and acquisition history, including preliminary reports from third-party environmental engineers (see Note 11). The fair value of this liability will be supported by a third-party environmental specialist.

	The long-term deferred taxes of $105.9 million are primarily related to temporary differences associated with the fair value allocations of property and equipment and intangible assets, which are not deductible for tax purposes, net of acquired environmental liabilities and other deductible accrued liabilities.

	The fair values of the remaining Warren assets and liabilities noted above approximate their carrying values at January 7, 2015. It is possible that once the Partnership receives the completed valuations on the property and equipment and intangible assets, the final purchase price accounting may be different than what is presented above.

	The preliminary purchase price for the acquisition was allocated to assets acquired and liabilities assumed based on their estimated fair values. The Partnership then allocated the purchase price in excess of net tangible assets acquired to identifiable intangible assets, based upon on their estimates and assumptions. Any excess purchase price over the fair value of the net tangible and intangible assets acquired was allocated to goodwill.

	The Partnership utilized accounting guidance related to intangible assets which lists the pertinent factors to be considered when estimating the useful life of an intangible asset. These factors include, in part, a review of the expected use by the Partnership of the assets acquired, the expected useful life of another asset (or group of assets) related to the acquired assets and legal, regulatory or other contractual provisions that may limit the useful life of an acquired asset. The Partnership amortizes these intangible assets over their estimated useful lives which is consistent with the estimated undiscounted future cash flows of these assets.

	As part of the purchase price allocation, identifiable intangible assets include supply contracts that are being amortized over ten years. The supply contracts are subject to renewals, and assumptions related to the renewals have been included in the determination of the value of the supply contracts at the date of acquisition. The supply contracts had a weighted average term of approximately 5 years prior to their next renewal. As the purchase price accounting is preliminary, the final assumptions related to the likelihood of renewals remains in process. For the three months ended March 31, 2015, amortization expense amounted to $0.8 million. The estimated remaining amortization expense for intangible assets acquired in connection with the acquisition for each of the five succeeding years and thereafter is as follows (in thousands):
	2015 (1/7/15 – 12/31/15)		$	2,685
	2016		3,580
	2017		3,580
	2018		3,580
	2019		3,580
	Thereafter		17,960
	Total		$	34,965

	The $147.9 million of goodwill was assigned to the Gasoline Distribution and Station Operations (“GDSO”) reporting unit. The goodwill recognized is attributable primarily to expected synergies and growth opportunities for the Partnership. The goodwill is not deductible for income tax purposes. The Partnership is responsible for federal tax obligations for the interim period, June 1, 2014 to January 6, 2015 (Warren’s fiscal year end was May 31). Any tax obligations will be funded by the selling shareholders. Any tax refund will be remitted to the selling shareholders.

	In connection with the acquisition of Warren, the Partnership incurred acquisition costs totaling approximately $6.1 million, of which $4.4 million was recorded for the three months ended March 31, 2015 and included in selling, general and administrative expenses in the accompanying consolidated statement of income. The remaining acquisition costs were incurred in 2014. Additionally, 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 income for the three months ended March 31, 2015. This charge, which is principally for redundant and/or eliminated positions as a result of the acquisition, was not part of the purchase price allocation. 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 is expected to be paid in full by December 31, 2015.

	The acquisition of Warren complements the Partnership’s existing retail presence in the Northeast and expands its footprint into the adjacent Mid-Atlantic region. The acquisition added approximately 500 million gallons of fuel sold annually through the Partnership’s network and increased the number of its total gasoline stations that it owns, leases or supplies to more than 1,500 as of the acquisition closing date. The Warren operations have been integrated into the Partnership’s GDSO reporting segment.

	Acquisition of Revere Terminal

	On January 14, 2015, through the Partnership’s wholly owned subsidiary, Global Companies, the Partnership acquired the Revere Terminal located in Boston Harbor in Revere, Massachusetts from GPC, a privately held affiliate of the Partnership, for a purchase price of $23.65 million. The acquisition includes contingent consideration which would be payable under specific circumstances involving a subsequent sale of the property, and the purchase price may be adjusted in connection with any value assigned to the contingent consideration as the purchase price accounting is finalized. The Partnership financed the transaction with available capacity 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 has 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.

At March 31, 2015, the Partnership’s preliminary purchase accounting includes estimated fair values of $28.3 million associated with the property and equipment acquired and $4.6 million of assumed liabilities. The purchase price allocation will be finalized as the Partnership receives additional information relevant to the acquisition.

Goodwill

The following table presents the changes in goodwill (in thousands):

		Goodwill Allocated to
		Wholesale			GDSO
		Reporting			Reporting
		Unit			Unit		Total
Balance at December 31, 2014		$	121,752		$	32,326	$	154,078
Acquisition of Warren		—			147,909		147,909
Balance at March 31, 2015		$	121,752		$	180,235	$	301,987

Supplemental Pro Forma Information

Revenues and net income 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 statement of income for the three months ended March 31, 2015.

The following unaudited pro forma information for 2014 presents the consolidated results of operations of the Partnership as if the acquisition of Warren occurred at the beginning of the period presented, with pro forma adjustments to give effect to intercompany sales and certain other adjustments (in thousands, except per unit data):
		Three Months
		Ended
		March 31, 2014
Sales		$	5,496,851
Net income attributable to Global Partners LP		$	51,637
Net income per limited partner unit, basic and diluted		$	1.84

Warren’s revenues and net loss included in the Partnership’s consolidated operating results from January 7, 2015, the acquisition date, through the period ended March 31, 2015 were $247.7 million and $(1.0 million), respectively.

Net_Income_Per_Limited_Partner

Net Income Per Limited Partner Unit	3 Months Ended
	Mar. 31, 2015
Net Income (Loss) Per Limited Partner Unit
Net Income Per Limited Partner Unit	Note 3.Net 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 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, 2015 and December 31, 2014 excluded 453,219 and 390,602 common units, respectively, held on behalf of the Partnership pursuant to its repurchase program (see Note 12). 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 income and the assumed allocation of net income to the limited partners’ interest for purposes of computing net income per limited partner unit for the three months ended March 31, 2015 and 2014 (in thousands, except per unit data):

		Three Months March 31, 2015										Three Months Ended March 31, 2014
	Numerator:	Total			Limited		General			IDRs		Total		Limited		General		IDRs
					Partner		Partner							Partner		Partner
					Interest		Interest							Interest		Interest
	Net income attributable to Global Partners LP (1)	$	30,415		$	28,236	$	2,179		$	—	$	57,010	$	55,502	$	1,508	$	—

	Declared distribution	$	23,260		$	21,076	$	157		$	2,027	$	18,323	$	17,145	$	143	$	1,035
	Assumed allocation of undistributed net income	7,155			7,160		(5		)	—		38,687		38,357		330		—
	Assumed allocation of net income	$	30,415		$	28,236	$	152		$	2,027	$	57,010	$	55,502	$	473	$	1,035

	Denominator:
	Basic weighted average limited partner units outstanding				30,599									27,261
	Dilutive effect of phantom units				113									35
	Diluted weighted average limited partner units outstanding				30,712									27,296

	Basic net income per limited partner unit				$	0.92								$	2.04
	Diluted net income per limited partner unit				$	0.92								$	2.03

	(1)As a result of the December 10, 2014 issuance of 3,565,000 common units in connection with the Partnership’s public offering, the general partner interest was reduced to 0.74% for the three months ended March 31, 2015 from 0.83% for the three months ended March 31, 2014.

	During 2015, the board of directors of the General Partner declared the following quarterly cash distribution:

	Cash Distribution	Per Unit Cash		Distribution Declared for the
	Declaration Date	Distribution Declared		Quarterly Period Ended
	April 22, 2015	$0.68 (1)		March 31, 2015


	(1)This declared cash distribution resulted in an incentive distribution to the General Partner, as the holder of the IDRs, and enable the Partnership to exceed its third target level distribution with respect to such IDRs.

	See Note 8, “Cash Distributions” for further information.

Inventories

Inventories	3 Months Ended
	Mar. 31, 2015
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, on a first-in, first-out basis, or market.

	Inventories consisted of the following (in thousands):
		March 31,		December 31,
		2015		2014
	Distillates: home heating oil, diesel and kerosene	$	103,057	$	163,679
	Gasoline	96,846		82,080
	Gasoline blendstocks	47,651		33,760
	Crude oil	86,385		20,769
	Residual oil	13,172		20,602
	Propane and other	2,037		5,123
	Renewable identification numbers (RINs)	1,213		2,057
	Convenience store inventory	21,266		8,743
	Total	$	371,627	$	336,813

	In addition to its own inventory, the Partnership has exchange agreements for petroleum products 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 $9.6 million and $3.9 million at March 31, 2015 and December 31, 2014, respectively. Negative exchange balances are accounted for as accounts payable and amounted to $12.1 million and $16.5 million at March 31, 2015 and December 31, 2014, respectively. Exchange transactions are valued using current carrying costs and have no income statement impact.

Derivative_Financial_Instrumen

Derivative Financial Instruments	3 Months Ended
Derivative Financial Instruments	Mar. 31, 2015
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, 2015:
			Units (1)			Unit of Measure

	Exchange-Traded Derivatives
	Long		46,736			Thousands of barrels
	Short		(50,292	)		Thousands of barrels

	OTC Derivatives (Petroleum/Ethanol)
	Long		13,318			Thousands of barrels
	Short		(10,167	)		Thousands of barrels

	OTC Derivatives (Natural Gas)
	Long		10,607			Thousands of decatherms
	Short		(10,661	)		Thousands of decatherms

	Interest Rate Swaps	$	200			Millions of U.S. dollars
	Interest Rate Cap	$	100			Millions of U.S. dollars

	Foreign Currency Derivatives
	Open Forward Exchange Contracts (2)	$	6			Millions of Canadian dollars
		$	4.7			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 (“CAD”) $1.2662 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 income 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 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 income.

	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 income for the three months ended March 31, 2015 and 2014 (in thousands):

			Statement of Gain (Loss)		Three Months Ended
			Recognized in Income on		March 31,
			Derivatives		2015			2014
	Derivatives in fair value hedging relationship
	Exchange-traded futures contracts for petroleum commodity products		Cost of sales		$	26,176		$	16,373

	Hedged items in fair value hedge relationship
	Physical inventory		Cost of sales		$	(23,621	)	$	(16,209	)

	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 hedges, 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 income through interest expense in the same period that the hedged exposure affects earnings. The ineffective portion is recognized in the consolidated statement of income 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 expires on April 13, 2016, is used to hedge the variability in interest payments due to changes in the one-month LIBOR rate above 5.5% with respect to $100.0 million of one-month LIBOR-based borrowings on the 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, 2015, 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 is not currently in a hedging relationship. Accordingly, all changes in fair value of this instrument subsequent to the date of de-designation are recorded in the consolidated statement of income 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 income and partners’ equity for the three months ended March 31, 2015 and 2014 (in thousands):

		Amount of Gain (Loss)						Location of Gain (Loss)
		Recognized in Other						Reclassified from		Amount of Gain (Loss)
		Comprehensive Income on						Accumulated Other		Reclassified from Other
		Derivatives						Comprehensive Income into		Comprehensive Income into
		(Effective Portion)						Income (Effective Portion)		Income (Effective Portion)
Derivatives Designated		Three Months Ended								Three Months Ended
in Cash Flow Hedging		March 31,								March 31,
Relationship		2015			2014					2015		2014
Interest rate swaps		$	47		$	677		Interest expense		$	—	$	—
Interest rate cap (1)		—			(18		)	Interest expense		—		—
Total		$	47		$	659				$	—	$	—

	-1		The interest rate cap was de-designated as a cash flow hedge in June 2014. Prepaid interest rate caplet amounts recognized in accumulated other comprehensive income up until the date of de-designation have been frozen in partner’s equity as of the de-designation date and are being amortized to income through the tenor of the interest rate cap instrument. The change in the fair value of the interest rate cap following de-designation is reflected in earnings and was immaterial for the three months ended March 31, 2015. As of March 31, 2015, the remaining unamortized prepaid interest rate caplets were $0.9 million and will be amortized over the remaining life for the interest rate cap which expires in April 2016.

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, 2015 and 2014.

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 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 income through cost of sales. These futures contracts 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 income 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 fixed price purchase and sale commitments are recognized in the consolidated statement of income 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 hedging relationships recognized in the consolidated statements of income for the three months ended March 31, 2015 and 2014 (in thousands):

		Statement of Gain (Loss)		Three Months Ended
		Recognized in Income on		March 31,
		Derivatives		2015			2014
Derivatives NOT designated as hedging instruments
Commodity contracts		Cost of sales		$	3,651		$	15,543
Forward foreign currency contracts		Cost of sales		18			(57		)
Total				$	3,669		$	15,486

Margin Deposits

All of 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 quality 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 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.

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, 2015 and December 31, 2014 (in thousands):

				March 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		$	17,895		$	60,354		$	78,249
Forward derivative contracts (1)		Derivative assets		—			57,470			57,470
Forward foreign currency contracts		Other Assets		—			27			27
Interest rate cap contract		Other assets		—			17			17
Total asset derivatives				$	17,895		$	117,868		$	135,763

Liability Derivatives
Forward derivative contracts (1)		Derivative liabilities		$	—		$	48,272		$	48,272
Interest rate swap contracts		Other long-term liabilities		—			6,649			6,649
Total liability derivatives				$	—		$	54,921		$	54,921

				December 31, 2014
				Derivatives			Derivatives Not
				Designated as			Designated as
				Hedging			Hedging
		Balance Sheet Location		Instruments			Instruments			Total
Asset Derivatives
Exchange-traded derivative contracts		Broker margin deposits		$	30,600		$	90,890		$	121,490
Forward derivative contracts (1)		Derivative assets		—			83,826			83,826
Forward foreign currency contracts		Other Assets		—			9			9
Interest rate cap contract		Other assets		—			17			17
Total asset derivatives				$	30,600		$	174,742		$	205,342

Liability Derivatives
Forward derivative contracts (1)		Derivative liabilities		$	—		$	58,507		$	58,507
Interest rate swap contracts		Other long-term liabilities		—			6,696			6,696
Total liability derivatives				$	—		$	65,203		$	65,203

	-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 IntercontinentalExchange (“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, 2015
Debt
Debt	Note 6.Debt

	Credit Agreement

	As of March 31, 2015, certain subsidiaries of the Partnership, as borrowers, and the Partnership and certain of its subsidiaries, as guarantors, had a $1.775 billion senior secured credit facility (the “Credit Agreement”). The Credit Agreement will mature on April 30, 2018.

	As of March 31, 2015, there were two facilities under the Credit Agreement:

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

		·	a $775.0 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 $2.075 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 $1.775 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 $1.775 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). Borrowings under the revolving credit facility bear interest at (1) the Eurocurrency rate plus 2.25% to 3.25%, (2) the cost of funds rate plus 2.25% to 3.25%, or (3) the base rate plus 1.25% to 2.25%, each depending on the Combined Total Leverage Ratio (as defined in the Credit Agreement).

	The average interest rates for the Credit Agreement were 3.4% and 3.6% for the three months ended March 31, 2015 and 2014, respectively.

	As of March 31, 2015, 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 has an interest rate cap that is hedging variable interest. The cap is 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 long-term liability representing the amounts expected to be outstanding during the entire year, and because the Partnership has a multi-year, long-term commitment from its bank group. The long-term portion of the working capital revolving credit facility was $150.0 million and $100.0 million at March 31, 2015 and December 31, 2014, respectively. In addition, the Partnership classifies a portion of its working capital revolving credit facility as a current liability because it repays amounts outstanding and reborrows funds based on its working capital requirements. The Partnership’s current portion of the working capital revolving credit facility represents the amount the Partnership expects to pay down during the course of the year. At March 31, 2015 and December 31, 2014, the current portion of the working capital revolving credit facility was $125.4 million and $0, respectively. The increase in total borrowings under the working capital revolving credit facility from December 31, 2014 reflects, in part, higher levels of stored inventory, and the Partnership expects to pay down a portion of its borrowings during the course of the year and has classified the amount as current at March 31, 2015.

	As of March 31, 2015, the Partnership had total borrowings outstanding under the Credit Agreement of $792.8 million, including $517.4 million outstanding on the revolving credit facility. In addition, the Partnership had outstanding letters of credit of $59.8 million. Subject to borrowing base limitations, the total remaining availability for borrowings and letters of credit was $0.9 billion and $1.4 billion at March 31, 2015 and December 31, 2014, 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 Partnership was in compliance with the foregoing covenants at March 31, 2015. 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 (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 have been exchanged for SEC registered notes.

	Line of Credit

	On December 9, 2013, Basin Transload entered into a line of credit facility which allows for borrowings by Basin Transload of up to $10.0 million on a revolving basis. The facility matures on December 9, 2015 and had an outstanding balance of $0 and $0.7 million at March 31, 2015 and December 31, 2014, respectively. The facility is secured by substantially all of the assets of Basin Transload and is not guaranteed by the Partnership or any of its wholly owned subsidiaries.

	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 did not capitalize additional financing fees for the three months ended March 31, 2015 and 2014. Amortization expense of approximately $1.5 million and $1.3 million for the three months ended March 31, 2015 and 2014, respectively, are included in interest expense in the accompanying consolidated statements of income. Unamortized fees are included in other current assets and other long-term assets.

Related_Party_Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2015
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 the Terminal Storage Rental and Throughput Agreement has terminated (see Note 2). Prior to the acquisition, the agreement was accounted for as an operating lease. The expenses under this agreement totaled $0.8 million and $2.3 million for the three months ended March 31, 2015 and 2014, 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 $8,000 and $24,000 for the three months ended March 31, 2015 and 2014, respectively. These charges were recorded in selling, general and administrative expenses in the accompanying consolidated statements of income.

	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 continues to provide AE Holdings with certain tax, accounting, treasury and legal support services for which AE Holdings pays the Partnership an aggregate of $15,000 per year in equal monthly installments. 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 Amended and Restated Services Agreements are each 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, 2015, no such notice of termination was given by any party.

	The General Partner employs substantially all of the Partnership’s employees, except for most of its gasoline station and convenience store employees and certain union personnel, who are employed by GMG or Drake Petroleum. The Partnership reimburses the General Partner for expenses incurred in connection with these employees. These expenses, including payroll, payroll taxes and bonus accruals, were $29.4 million and $19.0 million for the three months ended March 31, 2015 and 2014, 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,
			2015		2014
	Receivables from GPC		$	—	$	108
	Receivables from the General Partner (1)		3,845		3,795
	Total		$	3,845	$	3,903


		-1		Receivables from the General Partner reflect the Partnership’s prepayment of payroll taxes and payroll accruals to the General Partner.

Cash_Distributions

Cash Distributions

3 Months Ended

Mar. 31, 2015

Cash Distributions

Note 8.Cash Distributions

The Partnership intends to consider regular 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.

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: 99.26% to the common unitholders, pro rata, and 0.74% 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:

Total Quarterly Distribution

Marginal Percentage Interest in

Distributions

Target Amount

Unitholders

General Partner

First Target Distribution

up to $0.4625

99.26%

0.74%

Second Target Distribution

above $0.4625 up to $0.5375

86.26%

13.74%

Third Target Distribution

above $0.5375 up to $0.6625

76.26%

23.74%

Thereafter

above $0.6625

51.26%

48.74%

The Partnership paid the following cash distribution during 2015 (in thousands, except per unit data):

Cash

Per Unit

Common

General

Incentive

Total Cash

Distribution

Cash

Units

Partner

Distribution

Payment Date

Distribution

02/13/15 (1)

0.6650

20,612

154

1,591

22,357

(1)This distribution of $0.6650 per unit resulted in the Partnership exceeding its third target level distribution for the fourth quarter of 2014. As a result, the General Partner, as the holder of the IDRs, received an incentive distribution.

In addition, on April 22, 2015, the board of directors of the General Partner declared a quarterly cash distribution of $0.68 per unit ($2.72 per unit on an annualized basis) on all of its outstanding common units for the period from January 1, 2015 through March 31, 2015 to the Partnership’s unitholders of record as of the close of business on May 6, 2015. This distribution will result in the Partnership exceeding its third target level distribution for the quarter ended March 31, 2015.

Segment_Reporting

Segment Reporting	3 Months Ended
Segment Reporting	Mar. 31, 2015
Segment Reporting
Segment Reporting	Note 9.Segment Reporting

	The Partnership engages in the purchasing, selling and logistics of transporting petroleum and related products, including domestic and Canadian crude oil, gasoline and gasoline blendstocks (such as ethanol and naphtha), 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, 2015 and 2014, 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, 2014.

	In the Wholesale reporting segment, the Partnership sells branded and unbranded gasoline and gasoline blendstocks and diesel to branded and unbranded gasoline customers and other resellers of transportation fuels. 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 distillate products 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 convenience stores, rental income from gasoline stations leased to dealers or commissioned agents and sundry (car wash sales, lottery and ATM commissions). The results of Warren, acquired in January 2015 (see Note 2), are included in the GDSO segment.

	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,
			2015			2014
	Wholesale Segment:
	Sales
	Gasoline and gasoline blendstocks		$	776,143		$	1,994,556
	Crude oil (1)		252,110			591,229
	Other oils and related products (2)		943,693			1,412,771
	Total		$	1,971,946		$	3,998,556
	Product margin
	Gasoline and gasoline blendstocks		$	29,829		$	49,663
	Crude oil (1)		15,257			23,490
	Other oils and related products (2)		35,007			34,616
	Total		$	80,093		$	107,769
	Gasoline Distribution and Station Operations Segment (3):
	Sales
	Gasoline		$	697,334		$	768,904
	Station operations (4)		83,075			33,972
	Total		$	780,409		$	802,876
	Product margin
	Gasoline		$	61,699		$	33,280
	Station operations (4)(5)		36,723			19,797
	Total		$	98,422		$	53,077
	Commercial Segment:
	Sales		$	226,761		$	315,496
	Product margin		$	11,558		$	12,329
	Combined sales and product margin:
	Sales		$	2,979,116		$	5,116,928
	Product margin (6)		$	190,073		$	173,175
	Depreciation allocated to cost of sales		(21,515		)	(14,151		)
	Combined gross profit		$	168,558		$	159,024

		-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		For the three months ended March 31, 2015, the GDSO segment includes the January 2015 acquisition of Warren (see Note 2). As the Warren assets were not in place prior to January 2015, the above results are not directly comparable to the prior period.
		-4		Station operations primarily consist of convenience stores sales at the Partnership’s directly operated stores and rental income from gasoline stations leased to dealers or commissioned agents.
		-5		For the three months ended March 31, 2014, station operations includes the reclass of loss on asset sales from product margin to operating expenses to conform to the Partnership’s current presentation.
		-6		Product margin is a non-GAAP financial measure used by management and external users of our consolidated financial statements to assess our business. The table above includes a reconciliation of product margin on a combined basis to gross profit, a directly comparable GAAP measure.

	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,
			2015			2014
	Combined gross profit		$	168,558		$	159,024
	Operating costs and expenses not allocated to operating segments:
	Selling, general and administrative expenses		48,786			37,298
	Operating expenses		68,656			47,952
	Amortization expense		5,341			4,528
	Loss on asset sales		437			663
Total operating costs and expenses		123,220			90,441
Operating income		45,338			68,583
Interest expense		(13,963		)	(11,107		)
Income tax expense		(966		)	(322		)
Net income		30,409			57,154
Net (income) loss attributable to noncontrolling interest		6			(144		)
Net income attributable to Global Partners LP		$	30,415		$	57,010

The Partnership’s foreign assets and foreign sales were immaterial as of and for the three months ended March 31, 2015 and 2014.

Segment Assets

The Partnership acquired retail gasoline stations from Warren in January 2015, Alliance in March 2012 and ExxonMobil in September 2010 which have been allocated to the GDSO segment. The Partnership acquired the Revere Terminal in January 2015 and transloading facilities and other assets from Basin Transload and Cascade Kelly Holdings LLC (“Cascade Kelly”) in February 2013 which have been allocated to the Wholesale 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, 2015 and December 31, 2014 (in thousands):
		Wholesale			Commercial			GDSO		Unallocated		Total
March 31, 2015		$	773,803		$	—		$	1,184,978	$	610,003	$	2,568,784
December 31, 2014		$	811,535		$	—		$	622,860	$	605,582	$	2,039,977

The increase in total GDSO and total consolidated assets at March 31, 2015 compared to December 31, 2014 is due to the January 2015 acquisitions of Warren and the Revere Terminal (Note 2).

Property_and_Equipment

Property and Equipment	3 Months Ended
	Mar. 31, 2015
Property and Equipment
Property and Equipment	Note 10.Property and Equipment

	Property and equipment consisted of the following (in thousands):
		March 31,			December 31,
		2015			2014
	Buildings and improvements	$	930,169		$	667,172
	Land	384,078			288,929
	Fixtures and equipment	32,985			26,577
	Construction in process	72,213			66,119
	Capitalized internal use software	7,530			7,530
	Total property and equipment	1,426,975			1,056,327
	Less accumulated depreciation	(252,892		)	(231,276		)
	Total	$	1,174,083		$	825,051

	At March 31, 2015 and December 31, 2014, construction in process included $30.5 million related to the Partnership’s ethanol plant acquired from Cascade Kelly. Due to the nature of certain assets acquired from Cascade Kelly which are currently idle, the Partnership intends to make the capital improvements necessary to place the ethanol plant into service and expects the plant to be operational in 2016; therefore, as of March 31, 2015 and December 31, 2014, the recorded value of the ethanol plant is included in construction in process. After the plant has been successfully placed into service, depreciation will commence.

	As part of continuing operations, the Partnership may periodically divest certain gasoline stations. The gain (loss) on the sale, representing cash proceeds less net book value of assets at disposition, is recorded in loss on asset sales in the accompanying consolidated statements of income and amounted to $0.4 million and $0.7 million for the three months ended March 31, 2015 and 2014, respectively.

	The Partnership evaluates its assets for impairment on a quarterly basis. No impairments were required for the three months ended March 31, 2015 and 2014.

Environmental_Liabilities_Asse

Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers (RINs)	3 Months Ended
	Mar. 31, 2015
Environmental Liabilities and Renewable Identification Numbers (RINs)
Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers (RINs)	Note 11.Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers (RINs)

	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 January 2015 acquisition of the Revere Terminal (see Note 2), the Partnership assumed certain environmental liabilities, including certain ongoing environmental remediation efforts. As a result, the Partnership recorded, on an undiscounted basis, a total environmental liability of approximately $2.9 million.

	In connection with the January 2015 acquisition of Warren (see Note 2), the Partnership assumed certain environmental liabilities, including certain ongoing environmental remediation efforts at certain of the retail gasoline stations owned by Warren and future remediation activities required by applicable federal, state or local law or regulation. As a result, the Partnership recorded, on an undiscounted basis, a total environmental liability of approximately $36.1 million.

	Both the $2.9 million and $36.1 million recorded for the Revere Terminal and for Warren, respectively, were based on preliminary purchase accounting. These amounts may change as the purchase price accounting is finalized.

	In connection with the December 2012 acquisition of six New England retail gasoline stations from Mutual Oil, 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 addition to the above-mentioned environmental liabilities related to the Partnership’s retail gasoline stations, the Partnership retains environmental obligations associated with certain gasoline stations that the Partnership has sold.

	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 connection with the November 2007 acquisition of ExxonMobil’s Glenwood Landing and Inwood, New York terminals, the Partnership assumed certain environmental liabilities, including the remediation obligations under remedial action plans submitted by ExxonMobil to and approved by the New York Department of Environmental Conservation (“NYDEC”) with respect to both terminals. As a result, the Partnership initially recorded, on an undiscounted basis, total environmental liabilities of approximately $1.2 million.

	The following table presents a summary roll forward of the Partnership’s environmental liabilities at March 31, 2015 (in thousands):

		Balance at													Balance at
		December 31,		Additions in		Payments in			Dispositions			Other			March 31,
	Environmental Liability Related to:	2014		2015		2015			2015			Adjustments			2015
	Retail Gasoline Stations	$	35,792	$	36,080	$	(1,017	)	$	(67	)	$	(172	)	$	70,616
	Terminals	1,771		2,900		(16		)	—			—			4,655
	Total environmental liabilities	$	37,563	$	38,980	$	(1,033	)	$	(67	)	$	(172	)	$	75,271

	Current portion	$	3,101												$	3,085
	Long-term portion	34,462													72,186
	Total environmental liabilities	$	37,563												$	75,271

	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 U.S. 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 in specific states.

	The fair value of a liability for an asset retirement obligation is recognized 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 $5.7 million and $3.8 million in total asset retirement obligations at March 31, 2015 and December 31, 2014, respectively, which are included in other long-term liabilities in the accompanying balance sheets. Approximately $1.8 million of this obligation at March 31, 2015 was assumed in the acquisition of Warren and is based on preliminary purchase accounting. This amount may change as the purchase price accounting is finalized.

	Renewable Identification Numbers (RINs)

	A Renewable Identification Number (“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 Environmental Protection Agency’s (the “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 $0.3 million and $0.3 million at March 31, 2015 and December 31, 2014, respectively.

	The Partnership may enter into RIN forward purchase and sales commitments. Total losses from firm non-cancellable commitments were immaterial at March 31, 2015 and December 31, 2014.

LongTerm_Incentive_Plan

Long-Term Incentive Plan	3 Months Ended
	Mar. 31, 2015
Long-Term Incentive Plan
Long-Term Incentive Plan	Note 12. 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 initially 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, 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 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 connection with the awards, grantees who are employees entered into various forms of a Confidentiality, Non-Solicitation, and Non-Competition Agreement with the General Partner. On December 31, 2014, a total of 10,266 of the awards granted to one employee and the non-employee directors vested and in January 2015, these phantom unit grants were settled.

	In 2014, a total of 44,902 phantom units were granted to certain employees, and during the three months ended March 31, 2015, a total of 17,870 phantom units were granted to certain employees and the non-employee directors.

	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 these of $1.0 million and $0.9 million for the three months ended March 31, 2015 and 2014, respectively, which is included in selling, general and administrative expenses in the accompanying consolidated statement of income. The total compensation cost related to the non-vested awards not yet recognized at March 31, 2015 was approximately $15.3 million and is expected to be recognized ratably over the remaining requisite service period.

	The following table presents a summary of the status of the non-vested phantom units:
		Number of		Weighted
		Non-vested		Average
		Units		Grant Date
				Fair Value
	Outstanding non-vested units at December 31, 2014	532,748		$	39.29
	Granted	17,870		39.21
	Vested	(2,708	)	37.18
	Forfeited	—		—
	Outstanding non-vested units at March 31, 2015	547,910		$	39.3

	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 currently 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 791,792 common units pursuant to the Repurchase Program for approximately $23.3 million, of which approximately $2.4 million was purchased during the three months ended March 31, 2015.

	Common units outstanding as reported in the accompanying consolidated financial statements at March 31, 2015 and December 31, 2014 excluded 453,219 and 390,602 common units, respectively, held on behalf of the Partnership pursuant to its Repurchase Program and for future satisfaction of the General Partner’s Obligations.

Fair_Value_Measurements

Fair Value Measurements	3 Months Ended
Fair Value Measurements	Mar. 31, 2015
Fair Value Measurements
Fair Value Measurements	Note 13.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 forwards, swaps and options.

	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.

	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, 2015 and December 31, 2014 (in thousands):

			Fair Value as of March 31, 2015
			Level 1		Level 2			Level 3			Cash			Total
											Collateral
											Netting (2)
	Assets:
	Forward derivative contracts (1)		$	—	$	50,375		$	7,095		$	—		$	57,470
	Foreign currency derivatives		—		27			—			—			27
	Interest rate cap		—		17			—			—			17
	Exchange-traded/cleared derivative instruments (2)		78,249		—			—			(44,512		)	33,737
	Pension plans		17,316		—			—			—			17,316
	Total assets		$	95,565	$	50,419		$	7,095		$	(44,512	)	$	108,567

	Liabilities:
	Forward derivative contracts (1)		$	—	$	(25,583	)	$	(21,984	)	$	—		$	(47,567	)
	Swap agreements and options		—		(705		)	—			—			(705		)
	Interest rate swaps		—		(6,649		)	—			—			(6,649		)
	Total liabilities		$	—	$	(32,937	)	$	(21,984	)	$	—		$	(54,921	)

			Fair Value as of December 31, 2014
			Level 1		Level 2			Level 3			Cash			Total
											Collateral
											Netting (2)
	Assets:
	Forward derivative contracts (1)		$	—	$	81,421		$	2,405		$	—		$	83,826
	Foreign currency derivatives		—		9			—			—			9
	Interest rate cap		—		17			—			—			17
	Exchange-traded/cleared derivative instruments (2)		121,490		—			—			(104,292		)	17,198
	Pension plans		18,023		—			—			—			18,023
	Total assets		$	139,513	$	81,447		$	2,405		$	(104,292	)	$	119,073

	Liabilities:
	Forward derivative contracts (1)		$	—	$	(28,500	)	$	(27,928	)	$	—		$	(56,428	)
	Swap agreements and options		—		(2,079		)	—			—			(2,079		)
	Interest rate swaps		—		(6,696		)	—			—			(6,696		)
	Total liabilities		$	—	$	(37,275	)	$	(27,928	)	$	—		$	(65,203	)

		-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 Partnership’s credit facility approximates fair value due to the variable rate nature of these financial instruments.

	The carrying value and fair value of the Partnership’s 6.25% Notes, estimated by observing market trading prices of the 6.25% Notes, were as follows (in thousands):

			March 31, 2015					December 31, 2014
			Carrying		Fair			Carrying			Fair
			Value		Value			Value			Value

	6.25% Notes		$	375,000	$	365,411		$	375,000		$	358,594

The carrying value of the Partnership’s 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 Partnership’s 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 Partnership’s Level 1 exchange-traded/cleared derivative instruments were based on quoted process obtained from the NYMEX and CME. The fair values of the Partnership’s 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 Partnership’s 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 Partnership’s Level 2 derivative commodity contracts were derived from published and quoted NYMEX, CME, New York Harbor and third-party pricing information for the underlying instruments using market approaches. The fair value of the Partnership’s 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 Partnership’s 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, 2015.

Level 3 Information

The values of the Partnership’s 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, 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 Partnership’s 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 were $7.45 to $10.75 per barrel for the three months ended March 31, 2015 and 2014, respectively. 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	Position	Change to Input	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, 2015 (in thousands):

Fair value at December 31, 2014		$	(25,523	)
Reclass of Level 2 inputs		—
Realized and unrealized gains (losses) recorded in cost of sales		10,634
Fair value at March 31, 2015		$	(14,889	)

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 2 for acquired assets and liabilities measured on a non-recurring basis during the quarter ended March 31, 2015.

Income_Taxes

Income Taxes	3 Months Ended
Income Taxes	Mar. 31, 2015
Income Taxes
Income Taxes	Note 14.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 and 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.

	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
Legal Proceedings	Mar. 31, 2015
Legal Proceedings
Legal Proceedings	Note 15.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 11 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

	On March 26, 2015, the Partnership received a Notice of Non-Compliance (“NON”) from the Massachusetts Department of Environmental Protection (“DEP”) with respect to its terminal located at 101 and 186 Lee Burbank Highway, Revere, Massachusetts (the “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, which includes modifications to the storm water management system at the 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 have agreed to arbitrate under the rules of the American Arbitration Association. The Partnership filed for arbitration on March 24, 2015. The Partnership believes it has meritorious positions and intends to vigorously pursue a favorable result in connection with this dispute.

	On July 2, 2014, a lawsuit was filed by the Northwest Environmental Defense Center and other environmental non-government organizations (the “Plaintiffs”) against the Partnership and Cascade Kelly alleging violations of the Clean Air Act. The suit, filed in the United States District Court for the district of Oregon, alleges that Cascade Kelly is operating without the proper permit under the applicable rules. The lawsuit seeks penalties, injunctive relief and reimbursement of attorneys’ fees. The Partnership has meritorious defenses to the lawsuit and will vigorously contest the actions taken by the Plaintiffs.

	On May 16, 2014, the Partnership received a subpoena from the Securities and Exchange Commission requesting information for relevant time periods primarily relating to the Partnership’s accounting for Renewable Identification Numbers 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 intends to continue to cooperate fully with, and has produced responsive materials to, the SEC.

	On December 30, 2013, the Oregon Department of Environmental Quality (“ODEQ”) unilaterally modified (the “Modification”) an air emissions permit held by Cascade Kelly, which covers both the production of ethanol and transshipping of crude oil by the Partnership’s bio-refinery in Clatskanie, Oregon (the “Combined Permit”). This Modification proposed to limit the number of trains carrying crude oil that the bio-refinery can receive as part of the Partnership’s transloading operations. The Partnership submitted a request for a hearing to contest the Modification, which allowed the Combined Permit to remain in effect pending this appeal. On March 27, 2014, ODEQ issued the Partnership a civil penalty assessment (“CPA”) of $117,292 claiming that the Partnership was in violation of the Combined Permit because the Partnership may have received more crude oil than the Combined Permit allows. The Partnership had meritorious defenses to the Modification and the allegations in the CPA. The Partnership denies any wrong doing but resolved the dispute related to the Modifications and the CPA with ODEQ in February 2015. As part of the settlement with ODEQ, the Partnership will pay a total of $102,292.

	Separately, in August 2013, the Partnership submitted an application to ODEQ for a separate air emissions permit covering the transloading of crude oil by the bio-refinery (the “New Permit”). On August 17, 2014, ODEQ issued the New Permit to Cascade Kelly authorizing the storage and transloading of up to 1.8 billion gallons of crude oil or ethanol. The Partnership entered into a settlement with ODEQ in January 2015 to resolve all claims related to the Modification and the PEN. In exchange for the Partnership’s agreement to pay a total civil penalty of $102,292, ODEQ has agreed to withdraw the Modification and to resolve the PEN in its entirety. This settlement will allow the Partnership to continue to operate the Cascade Kelly terminal crude oil operations according to the requirements of the New Permit issued in August 2014.

	The Partnership received from the EPA, by letters dated November 2, 2011 and March 29, 2012, reporting requirements and testing orders (collectively, the “Requests for Information”) for information under the Clean Air Act. The Requests for Information were part of an EPA investigation to determine whether the Partnership has violated sections of the Clean Air Act 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 anticipates further negotiations with the EPA. While the Partnership does not believe that a material violation has occurred, and its 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_C

Changes in Accumulated Other Comprehensive Loss	3 Months Ended
	Mar. 31, 2015
Changes in Accumulated Other Comprehensive (Income) Loss
Changes in Accumulated Other Comprehensive Loss	Note 16.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, 2015 (in thousands):

		Pension			Derivatives			Total
		Plan
	Balance at December 31, 2014	$	(5,547	)	$	(7,705	)	$	(13,252	)
	Other comprehensive income before reclassifications of gain (loss)	109			183			292
	Amount of gain (loss) reclassified from accumulated other comprehensive income	(18		)	—			(18		)
	Total comprehensive income	91			183			274
	Balance at March 31, 2015	$	(5,456	)	$	(7,522	)	$	(12,978	)

	Amounts are presented prior to the income tax effect on other comprehensive income. Given the Partnership’s master limited partnership status, the effective tax rate is immaterial.

New_Accounting_Standards

New Accounting Standards	3 Months Ended
New Accounting Standards	Mar. 31, 2015
New Accounting Standards
New Accounting Standards	Note 17.New Accounting Standards

	Accounting Standards or Updates Recently Adopted

	In April 2014, the FASB issued Accounting Standards Update (“ASU”) No. 2014-08, “Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity,” which includes amendments that change the requirements for reporting discontinued operations and require additional disclosures about discontinued operations. Under the new guidance, only disposals representing a strategic shift in operations that has a major effect on the entity’s operations and financial results should be presented as discontinued operations. Additionally, this standard requires expanded disclosures about discontinued operations that will provide financial statement users with more information about the assets, liabilities, income and expenses of discontinued operations. This standard is effective prospectively for fiscal years beginning after December 15, 2014, with early adoption permitted. The Partnership adopted this standard which did not have a material impact on its consolidated financial statements.

	Accounting Standards or Updates Not Yet Effective

	In April 2015, the FASB issued ASU No. 2015-03, “ Interest-Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs.” This standard requires debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying value of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by this standard. The amendments in this standard are effective retrospectively for fiscal years, and interim periods within those years, beginning after December 15, 2015. Early adoption is permitted. The Partnership does not expect the impact of adopting this standard to be material to the Partnership’s consolidated financial statements.

	In May 2014, the FASB issued ASU No. 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. This standard is effective for fiscal years beginning after December 15, 2016. The Partnership is currently evaluating the new guidance to determine the impact it will have on its consolidated financial statements.

	The Partnership has evaluated the accounting guidance recently issued and has determined that there are no other standards or updates will not have a material impact on its financial position, results of operations or cash flows.

Subsequent_Events

Subsequent Events	3 Months Ended
Subsequent Events	Mar. 31, 2015
Subsequent Events
Subsequent Events	Note 18.Subsequent Events

	On April 9, 2015, the Partnership, as Buyer, entered into a Sale and Purchase Agreement (the “Purchase Agreement”) with 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”), as Seller. Under the terms of the Purchase Agreement, the Partnership will acquire 97 primarily Mobil and Exxon branded retail gasoline stations and seven dealer supply contracts in New York City and Prince George’s County, Maryland, along with certain related supply, franchise agreements, third party leases and other assets associated with the operations (collectively, the “Acquired Assets”) for a cash purchase price of approximately $156.0 million, subject to certain post-closing adjustments related to the Acquired Assets at the time of closing (the “CPG Acquisition”). Of the 97 locations, 18 are fee properties and the balance are the subject of long term leases.

	The Purchase Agreement provides that the closing will take place on or before June 1, 2015, subject to a one-time extension not to exceed 30 days, if required in connection with satisfying certain closing conditions, including filing under the Hart-Scott-Rodino Antitrust Improvements Act of 1976 (“HSR”) (the “Closing Date”). Closing of the CPG Acquisition is conditioned upon the satisfaction or waiver of customary closing conditions, including HSR approval, certain third party rights of first refusal and delivery of all items required by the Purchase Agreement.

	The Purchase Agreement contains customary representations and warranties and covenants by each of the parties. Among other covenants, during the period between the execution of the Purchase Agreement and the closing of the CPG Acquisition, Capitol Petroleum Group has agreed to conduct its business in substantially the same manner previously conducted and not to engage in certain types of activities and transactions. At closing, subject to the terms and conditions set forth in the Purchase Agreement, the Partnership will assume certain liabilities and obligations of Capitol Petroleum Group related to the Acquired Assets. The Partnership expects to finance the CPG Acquisition with borrowings under its revolving credit facility.

	The Partnership will account for this transaction as a business combination, and management is currently in the process of evaluating the preliminary purchase price accounting. The Partnership intends to engage a third-party valuation firm to assist in the valuation of the Acquired Assets and possible intangible assets. The operations of Acquired Assets are expected to be reported within the Partnership’s GDSO segment upon closing.

	On April 22, 2015, the board of directors of the General Partner declared a quarterly cash distribution of $0.68 per unit ($2.72 per unit on an annualized basis) for the period from January 1, 2015 through March 31, 2015. On May 15, 2015, the Partnership will pay this cash distribution to its unitholders of record as of the close of business on May 6, 2015.

Supplemental_Guarantor_Condens

Supplemental Guarantor Condensed Consolidating Financial Statements	3 Months Ended
	Mar. 31, 2015
Supplemental Guarantor Condensed Consolidating Financial Statements
Supplemental Guarantor Condensed Consolidating Financial Statements	Note 19.Supplemental Guarantor Condensed Consolidating Financial Statements

	The Partnership’s wholly-owned subsidiaries other than GLP Finance Corp. are guarantors of senior notes issued by the Partnership and GLP Finance Corp. As such, the Partnership is subject to the requirements of Rule 3-10 of Regulation S-X of the Securities and Exchange Commission 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, 2015 and December 31, 2014, the Condensed Consolidating Statements of Income for the three months ended March 31, 2015 and 2014 and the Condensed Consolidating Statements of Cash Flows for the three months ended March 31, 2015 and 2014 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
	31-Mar-15
	(In thousands)

			Issuer			Non-
			Guarantor			Guarantor
			Subsidiaries			Subsidiary			Eliminations			Consolidated
	Assets
	Current assets:
	Cash and cash equivalents		$	2,469		$	3,876		$	—		$	6,345
	Accounts receivable, net		409,579			1,302			—			410,881
	Accounts receivable—affiliates		4,059			1,045			(1,259		)	3,845
	Inventories		371,627			—			—			371,627
	Brokerage margin deposits		33,737			—			—			33,737
	Derivative assets		57,470			—			—			57,470
	Prepaid expenses and other current assets		73,504			619			—			74,123
	Total current assets		952,445			6,842			(1,259		)	958,028
	Property and equipment, net		1,128,262			45,821			—			1,174,083
	Intangible assets, net		79,772			277			—			80,049
	Goodwill		215,924			86,063			—			301,987
	Other assets		54,637			—			—			54,637
	Total assets		$	2,431,040		$	139,003		$	(1,259	)	$	2,568,784
	Liabilities and partners’ equity
	Current liabilities:
	Accounts payable		$	306,937		$	583		$	—		$	307,520
	Accounts payable - affiliates		1,045			214			(1,259		)	—
	Working capital revolving credit facility—current portion		125,400			—			—			125,400
	Environmental liabilities—current portion		3,085			—			—			3,085
	Trustee taxes payable		90,183			—			—			90,183
	Accrued expenses and other current liabilities		60,394			524			—			60,918
	Derivative liabilities		48,272			—			—			48,272
	Total current liabilities		635,316			1,321			(1,259		)	635,378
	Working capital revolving credit facility—less current portion		150,000			—			—			150,000
	Revolving credit facility		517,400			—			—			517,400
	Senior notes		368,316			—			—			368,316
	Environmental liabilities—less current portion		72,186			—			—			72,186
	Deferred tax liability		120,708			—			—			120,708
	Other long-term liabilities		61,811			—			—			61,811
	Total liabilities		1,925,737			1,321			(1,259		)	1,925,799
	Partners’ equity
	Global Partners LP equity		505,303			88,474			—			593,777
	Noncontrolling interest		—			49,208			—			49,208
	Total partners’ equity		505,303			137,682			—			642,985
	Total liabilities and partners’ equity		$	2,431,040		$	139,003		$	(1,259	)	$	2,568,784

	Condensed Consolidating Balance Sheet
	31-Dec-14
	(In thousands)

			Issuer			Non-
			Guarantor			Guarantor
			Subsidiaries			Subsidiary			Eliminations			Consolidated
	Assets
	Current assets:
	Cash and cash equivalents		$	1,478		$	2,678		$	1,082		$	5,238
	Accounts receivable, net		455,603			1,307			820			457,730
	Accounts receivable—affiliates		3,222			820			(139		)	3,903
	Inventories		336,813			—			—			336,813
Brokerage margin deposits		17,198			—			—			17,198
Derivative assets		83,826			—			—			83,826
Prepaid expenses and other current assets		55,881			634			—			56,515
Total current assets		954,021			5,439			1,763			961,223
Property and equipment, net		778,385			46,666			—			825,051
Intangible assets, net		45,870			3,032			—			48,902
Goodwill		68,015			86,063			—			154,078
Other assets		50,723			—			—			50,723
Total assets		$	1,897,014		$	141,200		$	1,763		$	2,039,977
Liabilities and partners’ equity
Current liabilities:
Accounts payable		$	454,267		$	1,671		$	681		$	456,619
Line of credit		—			700			—			700
Environmental liabilities—current portion		3,101			—			—			3,101
Trustee taxes payable		105,744			—			—			105,744
Accrued expenses and other current liabilities		81,686			1,134			—			82,820
Derivative liabilities		58,507			—			—			58,507
Total current liabilities		703,305			3,505			681			707,491
Working capital revolving credit facility—less current portion		100,000			—			—			100,000
Revolving credit facility		133,800			—			—			133,800
Senior notes		368,136			—			—			368,136
Environmental liabilities—less current portion		34,462			—			—			34,462
Deferred tax liability		14,078			—			—			14,078
Other long-term liabilities		45,854			—			—			45,854
Total liabilities		1,399,635			3,505			681			1,403,821
Partners’ equity
Global Partners LP equity		497,379			88,481			1,082			586,942
Noncontrolling interest		—			49,214			—			49,214
Total partners’ equity		497,379			137,695			1,082			636,156
Total liabilities and partners’ equity		$	1,897,014		$	141,200		$	1,763		$	2,039,977

Condensed Consolidating Statement of Income
Three Months Ended March 31, 2015
(In thousands)

		(Issuer)			Non-
		Guarantor			Guarantor
		Subsidiaries			Subsidiary			Eliminations			Consolidated

Sales		$	2,975,185		$	8,050		$	(4,119	)	$	2,979,116
Cost of sales		2,812,472			2,205			(4,119		)	2,810,558
Gross profit		162,713			5,845			—			168,558

Costs and operating expenses:
Selling, general and administrative expenses		48,026			760			—			48,786
Operating expenses		66,317			2,339			—			68,656
Amortization expense		2,586			2,755			—			5,341
Loss on asset sales		437			—			—			437
Total costs and operating expenses		117,366			5,854			—			123,220

Operating income		45,347			(9		)	—			45,338

Interest expense		(13,958		)	(5		)	—			(13,963		)

Income before income tax expense		31,389			(14		)	—			31,375

Income tax expense		(966		)	—			—			(966		)

Net income		30,423			(14		)	—			30,409

Net income attributable to noncontrolling interest		—			6			—			6

Net income attributable to Global Partners LP		30,423			(8		)	—			30,415

Less: General partner’s interest in net income,		2,179			—			—			2,179
including incentive distribution rights

Limited partners’ interest in net income		$	28,244		$	(8	)	$	—		$	28,236

Condensed Consolidating Statement of Income
Three Months Ended March 31, 2014
(In thousands)

		(Issuer)			Non-
		Guarantor			Guarantor
		Subsidiaries			Subsidiary			Eliminations			Consolidated

Sales		$	5,114,874		$	8,145		$	(6,091	)	$	5,116,928
Cost of sales		4,962,534			1,461			(6,091		)	4,957,904
Gross profit		152,340			6,684			—			159,024

Costs and operating expenses:
Selling, general and administrative expenses		36,543			755			—			37,298
Operating expenses		45,180			2,772			—			47,952
Amortization expense		1,773			2,755			—			4,528
Loss on asset sales		663			—			—			663
Total costs and operating expenses		84,159			6,282			—			90,441

Operating income		68,181			402			—			68,583

Interest expense		(11,066		)	(41		)	—			(11,107		)

Income before income tax expense		57,115			361			—			57,476

Income tax expense		(322		)	—			—			(322		)

Net income		56,793			361			—			57,154

Net income attributable to noncontrolling interest		—			(144		)	—			(144		)

Net income attributable to Global Partners LP		56,793			217			—			57,010

Less: General partner’s interest in net income,		1,508			—			—			1,508
including incentive distribution rights

Limited partners’ interest in net income		$	55,285		$	217		$	—		$	55,502


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		$	(117,146	)	$	3,231		$	(113,915	)
Cash flows from investing activities
Acquisitions		(405,478		)	—			(405,478		)
Capital expenditures		(12,712		)	(1,333		)	(14,045		)
Proceeds from sale of property and equipment		1,044			—			1,044
Net cash used in investing activities		(417,146		)	(1,333		)	(418,479		)
Cash flows from financing activities
Borrowings from on working capital revolving credit facility		175,400			—			175,400
Borrowings from revolving credit facility		383,600			—			383,600
Payments on line of credit		—			(700		)	(700		)
Repurchase of common units		(2,442		)	—			(2,442		)
Noncontrolling interest capital contribution		1,880			—			1,880
Distribution to noncontrolling interest		(1,880		)	—			(1,880		)
Distributions to partners		(22,357		)	—			(22,357		)
Net cash provided by (used in) financing activities		534,201			(700		)	533,501
Cash and cash equivalents
(Decrease) increase in cash and cash equivalents		(91		)	1,198			1,107
Cash and cash equivalents at beginning of period		2,560			2,678			5,238
Cash and cash equivalents at end of period		$	2,469		$	3,876		$	6,345

Condensed Consolidating Statement Cash Flows
Three Months Ended March 31, 2014
(In thousands)


		(Issuer)			Non-
		Guarantor			Guarantor
		Subsidiaries			Subsidiary			Consolidated
Cash flows from operating activities
Net cash provided by operating activities		$	48,362		$	4,784		$	53,146
Cash flows from investing activities
Capital expenditures		(12,301		)	(774		)	(13,075		)
Proceeds from sale of property and equipment		1,746			—			1,746
Net cash used in investing activities		(10,555		)	(774		)	(11,329		)
Cash flows from financing activities
Payments on working capital revolving credit facility		(20,200		)	—			(20,200		)
Noncontrolling interest capital contribution		2,400			—			2,400
Distribution to noncontrolling interest		(2,400		)	—			(2,400		)
Distributions to partners		(17,770		)	—			(17,770		)
Net cash used in financing activities		(37,970		)	—			(37,970		)
Cash and cash equivalents
(Decrease) increase in cash and cash equivalents		(163		)	4,010			3,847
Cash and cash equivalents at beginning of period		8,371			846			9,217
Cash and cash equivalents at end of period		$	8,208		$	4,856		$	13,064

Organization_and_Basis_of_Pres1

Organization and Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 2015
Organization and Basis of Presentation
Basis of Presentation	Basis of Presentation

	The financial results of Warren and the Revere Terminal for the three months ended March 31, 2015 are included in the accompanying statements of income for the three months ended March 31, 2015. The accompanying consolidated financial statements as of March 31, 2015 and December 31, 2014 and for the three months ended March 31, 2015 and 2014 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, 2014 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, 2015 are not necessarily indicative of the results of operations that will be realized for the entire year ending December 31, 2015. The consolidated balance sheet at December 31, 2014 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, 2014.

	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 and gasoline blendstocks during the late spring and summer months than during the fall and winter. Travel and recreational activities are typically higher in these months in the geographic areas in which the Partnership operates, increasing the demand for gasoline and gasoline blendstocks that the Partnership distributes. Therefore, the Partnership’s volumes in gasoline and gasoline blendstocks 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 sales 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.

Reclassification	Reclassification

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

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 statement 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 statement 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 income.

Concentration of Risk	Concentration of Risk

	The following table presents the Partnership’s sales, logistics revenue and rental income as a percentage of the consolidated sales for the periods presented:

		Three Months Ended
		March 31,
		2015	2014
	Gasoline sales: gasoline and gasoline blendstocks such as ethanol and naphtha	50%	54%
	Crude oil sales and logistics revenue	9%	12%
	Distillates (home heating oil, diesel and kerosene), residual oil, natural gas and propane sales	38%	33%
	Convenience store sales, rental income and sundry sales	3%	1%
	Total	100%	100%

	None of the Partnership’s customers were significant for the three months ended March 31, 2015. The Partnership had one significant customer, ExxonMobil Corporation (“ExxonMobil”) that accounted for approximately 14% of total sales for the three months ended March 31, 2014.

Organization_and_Basis_of_Pres2

Organization and Basis of Presentation (Tables)	3 Months Ended
Organization and Basis of Presentation (Tables)	Mar. 31, 2015
Organization and Basis of Presentation
Schedule of product sales and logistics revenue as a percentage of total sales		Three Months Ended
		March 31,
		2015	2014
	Gasoline sales: gasoline and gasoline blendstocks such as ethanol and naphtha	50%	54%
	Crude oil sales and logistics revenue	9%	12%
	Distillates (home heating oil, diesel and kerosene), residual oil, natural gas and propane sales	38%	33%
	Convenience store sales, rental income and sundry sales	3%	1%
	Total	100%	100%

Business_Combinations_Tables

Business Combinations (Tables)	3 Months Ended
Business Combinations (Tables)	Mar. 31, 2015
Acquisitions
Schedule of changes in goodwill	The following table presents the changes in goodwill (in thousands):
		Goodwill Allocated to
		Wholesale			GDSO
		Reporting			Reporting
		Unit			Unit		Total
	Balance at December 31, 2014	$	121,752		$	32,326	$	154,078
	Acquisition of Warren	—			147,909		147,909
	Balance at March 31, 2015	$	121,752		$	180,235	$	301,987


Schedule of pro-forma adjustments to give effect to intercompany sales and certain other adjustments
	The following unaudited pro forma information for 2014 presents the consolidated results of operations of the Partnership as if the acquisition of Warren occurred at the beginning of the period presented, with pro forma adjustments to give effect to intercompany sales and certain other adjustments (in thousands, except per unit data):
		Three Months
		Ended
		March 31, 2014
	Sales	$	5,496,851
	Net income attributable to Global Partners LP	$	51,637
	Net income per limited partner unit, basic and diluted	$	1.84


Warren Equities Inc
Acquisitions
Schedule of Preliminary allocation of the purchase price to the estimated fair value of the assets acquired and liabilities assumed	The following table presents the preliminary allocation of the purchase price to the estimated fair value of the assets acquired and liabilities assumed at the date of acquisition (in thousands):
	Assets purchased:
	Accounts receivable	$	5,372
	Inventory	19,199
	Prepaid expenses	12,552
	Property and equipment	331,291
	Intangibles	36,490
	Other non-current assets	20,586
	Total identifiable assets purchased	425,490
	Liabilities assumed:
	Accounts payable	(21,511		)
	Assumption of environmental liabilities	(36,080		)
	Taxes payable	(5,538		)
	Accrued expenses	(11,595		)
	Long-term deferred taxes	(105,855		)
	Other non-current liabilities	(10,992		)
	Total liabilities assumed	(191,571		)
	Net identifiable assets acquired	233,919
	Goodwill	147,909
	Net assets acquired	$	381,828


Schedule of estimated remaining amortization expense for intangible assets acquired in connection with the acquisition	The estimated remaining amortization expense for intangible assets acquired in connection with the acquisition for each of the five succeeding years and thereafter is as follows (in thousands):
	2015 (1/7/15 – 12/31/15)	$	2,685
	2016	3,580
	2017	3,580
	2018	3,580
	2019	3,580
	Thereafter	17,960
	Total	$	34,965

Net_Income_Per_Limited_Partner1

Net Income Per Limited Partner Unit (Tables)	3 Months Ended
Net Income Per Limited Partner Unit (Tables)	Mar. 31, 2015
Net Income (Loss) 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	The following table provides a 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 for the three months ended March 31, 2015 and 2014 (in thousands, except per unit data):
			Three Months March 31, 2015									Three Months Ended March 31, 2014
	Numerator:		Total		Limited		General			IDRs		Total		Limited		General		IDRs
					Partner		Partner							Partner		Partner
					Interest		Interest							Interest		Interest
	Net income attributable to Global Partners LP (1)		$	30,415	$	28,236	$	2,179		$	—	$	57,010	$	55,502	$	1,508	$	—

	Declared distribution		$	23,260	$	21,076	$	157		$	2,027	$	18,323	$	17,145	$	143	$	1,035
	Assumed allocation of undistributed net income		7,155		7,160		(5		)	—		38,687		38,357		330		—
	Assumed allocation of net income		$	30,415	$	28,236	$	152		$	2,027	$	57,010	$	55,502	$	473	$	1,035

	Denominator:
	Basic weighted average limited partner units outstanding				30,599									27,261
	Dilutive effect of phantom units				113									35
	Diluted weighted average limited partner units outstanding				30,712									27,296

	Basic net income per limited partner unit				$	0.92								$	2.04
	Diluted net income per limited partner unit				$	0.92								$	2.03

	(1)As a result of the December 10, 2014 issuance of 3,565,000 common units in connection with the Partnership’s public offering, the general partner interest was reduced to 0.74% for the three months ended March 31, 2015 from 0.83% for the three months ended March 31, 2014.

Schedule of quarterly cash distributions made to general partners	During 2015, the board of directors of the General Partner declared the following quarterly cash distribution:
	Cash Distribution	Per Unit Cash		Distribution Declared for the
	Declaration Date	Distribution Declared		Quarterly Period Ended
	April 22, 2015	$0.68 (1)		March 31, 2015


	(1)This declared cash distribution resulted in an incentive distribution to the General Partner, as the holder of the IDRs, and enable the Partnership to exceed its third target level distribution with respect to such IDRs.

Inventories_Tables

Inventories (Tables)	3 Months Ended
	Mar. 31, 2015
Inventories
Schedule of inventories	Inventories consisted of the following (in thousands):
		March 31,		December 31,
		2015		2014
	Distillates: home heating oil, diesel and kerosene	$	103,057	$	163,679
	Gasoline	96,846		82,080
	Gasoline blendstocks	47,651		33,760
	Crude oil	86,385		20,769
	Residual oil	13,172		20,602
	Propane and other	2,037		5,123
	Renewable identification numbers (RINs)	1,213		2,057
	Convenience store inventory	21,266		8,743
	Total	$	371,627	$	336,813

Derivative_Financial_Instrumen1

Derivative Financial Instruments (Tables)	3 Months Ended
Derivative Financial Instruments (Tables)	Mar. 31, 2015
Derivative Financial Instruments
Schedule of the volume of activity related to the derivative financial instruments	The following table summarizes the notional values related to the Partnership’s derivative instruments outstanding at March 31, 2015:
			Units (1)			Unit of Measure

	Exchange-Traded Derivatives
	Long		46,736			Thousands of barrels
	Short		(50,292	)		Thousands of barrels

	OTC Derivatives (Petroleum/Ethanol)
	Long		13,318			Thousands of barrels
	Short		(10,167	)		Thousands of barrels

	OTC Derivatives (Natural Gas)
	Long		10,607			Thousands of decatherms
	Short		(10,661	)		Thousands of decatherms

	Interest Rate Swaps	$	200			Millions of U.S. dollars
	Interest Rate Cap	$	100			Millions of U.S. dollars

	Foreign Currency Derivatives
	Open Forward Exchange Contracts (2)	$	6			Millions of Canadian dollars
		$	4.7			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 (“CAD”) $1.2662 to USD $1.00.

Derivative Financial Instruments
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
	The following table presents the gains and losses from the Partnership’s derivative instruments not involved in hedging relationships recognized in the consolidated statements of income for the three months ended March 31, 2015 and 2014 (in thousands):

			Statement of Gain (Loss)		Three Months Ended
			Recognized in Income on		March 31,
			Derivatives		2015			2014
	Derivatives NOT designated as hedging instruments
	Commodity contracts		Cost of sales		$	3,651		$	15,543
	Forward foreign currency contracts		Cost of sales		18			(57		)
	Total				$	3,669		$	15,486


Derivatives in Fair Value Hedging Relationships
Derivative Financial Instruments
Schedule of net gains and losses from derivatives recognized in consolidated statements 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 income for the three months ended March 31, 2015 and 2014 (in thousands):

			Statement of Gain (Loss)		Three Months Ended
			Recognized in Income on		March 31,
			Derivatives		2015			2014
	Derivatives in fair value hedging relationship
	Exchange-traded futures contracts for petroleum commodity products		Cost of sales		$	26,176		$	16,373

	Hedged items in fair value hedge relationship
	Physical inventory		Cost of sales		$	(23,621	)	$	(16,209	)


Cash Flow Hedges
Derivative Financial Instruments
Schedule of fair values of derivative instruments and location in consolidated balance sheets	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 income and partners’ equity for the three months ended March 31, 2015 and 2014 (in thousands):

			Amount of Gain (Loss)						Location of Gain (Loss)
			Recognized in Other						Reclassified from		Amount of Gain (Loss)
			Comprehensive Income on						Accumulated Other		Reclassified from Other
			Derivatives						Comprehensive Income into		Comprehensive Income into
			(Effective Portion)						Income (Effective Portion)		Income (Effective Portion)
	Derivatives Designated		Three Months Ended								Three Months Ended
	in Cash Flow Hedging		March 31,								March 31,
	Relationship		2015			2014					2015		2014
	Interest rate swaps		$	47		$	677		Interest expense		$	—	$	—
	Interest rate cap (1)		—			(18		)	Interest expense		—		—
	Total		$	47		$	659				$	—	$	—

		-1		The interest rate cap was de-designated as a cash flow hedge in June 2014. Prepaid interest rate caplet amounts recognized in accumulated other comprehensive income up until the date of de-designation have been frozen in partner’s equity as of the de-designation date and are being amortized to income through the tenor of the interest rate cap instrument. The change in the fair value of the interest rate cap following de-designation is reflected in earnings and was immaterial for the three months ended March 31, 2015. As of March 31, 2015, the remaining unamortized prepaid interest rate caplets were $0.9 million and will be amortized over the remaining life for the interest rate cap which expires in April 2016.

Schedule of net gains and losses from derivatives recognized in consolidated statements of operations
	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, 2015 and December 31, 2014 (in thousands):

					March 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		$	17,895		$	60,354		$	78,249
	Forward derivative contracts (1)		Derivative assets		—			57,470			57,470
	Forward foreign currency contracts		Other Assets		—			27			27
	Interest rate cap contract		Other assets		—			17			17
	Total asset derivatives				$	17,895		$	117,868		$	135,763

	Liability Derivatives
	Forward derivative contracts (1)		Derivative liabilities		$	—		$	48,272		$	48,272
	Interest rate swap contracts		Other long-term liabilities		—			6,649			6,649
	Total liability derivatives				$	—		$	54,921		$	54,921

					December 31, 2014
					Derivatives			Derivatives Not
					Designated as			Designated as
					Hedging			Hedging
			Balance Sheet Location		Instruments			Instruments			Total
	Asset Derivatives
	Exchange-traded derivative contracts		Broker margin deposits		$	30,600		$	90,890		$	121,490
	Forward derivative contracts (1)		Derivative assets		—			83,826			83,826
	Forward foreign currency contracts		Other Assets		—			9			9
	Interest rate cap contract		Other assets		—			17			17
	Total asset derivatives				$	30,600		$	174,742		$	205,342

	Liability Derivatives
	Forward derivative contracts (1)		Derivative liabilities		$	—		$	58,507		$	58,507
	Interest rate swap contracts		Other long-term liabilities		—			6,696			6,696
	Total liability derivatives				$	—		$	65,203		$	65,203

		-1		Forward derivative contracts include the Partnership’s petroleum and ethanol physical and financial forwards and OTC swaps.

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2015
Related Party Transactions
Schedule of receivables from related parties	The table below presents trade receivables with GPC and the Partnership and receivables from the General Partner (in thousands):

			March 31,		December 31,
			2015		2014
	Receivables from GPC		$	—	$	108
	Receivables from the General Partner (1)		3,845		3,795
	Total		$	3,845	$	3,903


		-1		Receivables from the General Partner reflect the Partnership’s prepayment of payroll taxes and payroll accruals to the General Partner.

Cash_Distributions_Tables

Cash Distributions (Tables)

3 Months Ended

Mar. 31, 2015

Cash Distributions

Schedule of quarterly cash distributions to the unitholders and the General Partner based on target levels

Total Quarterly Distribution

Marginal Percentage Interest in

Distributions

Target Amount

Unitholders

General Partner

First Target Distribution

up to $0.4625

99.26%

0.74%

Second Target Distribution

above $0.4625 up to $0.5375

86.26%

13.74%

Third Target Distribution

above $0.5375 up to $0.6625

76.26%

23.74%

Thereafter

above $0.6625

51.26%

48.74%

Schedule of cash distributions made by the Partnership

The Partnership paid the following cash distribution during 2015 (in thousands, except per unit data):

Cash

Per Unit

Common

General

Incentive

Total Cash

Distribution

Cash

Units

Partner

Distribution

Payment Date

Distribution

02/13/15 (1)

0.6650

20,612

154

1,591

22,357

Segment_Reporting_Tables

Segment Reporting (Tables)	3 Months Ended
Segment Reporting (Tables)	Mar. 31, 2015
Segment Reporting
Summary of financial information for 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,
			2015			2014
	Wholesale Segment:
	Sales
	Gasoline and gasoline blendstocks		$	776,143		$	1,994,556
	Crude oil (1)		252,110			591,229
	Other oils and related products (2)		943,693			1,412,771
	Total		$	1,971,946		$	3,998,556
	Product margin
	Gasoline and gasoline blendstocks		$	29,829		$	49,663
	Crude oil (1)		15,257			23,490
	Other oils and related products (2)		35,007			34,616
	Total		$	80,093		$	107,769
	Gasoline Distribution and Station Operations Segment (3):
	Sales
	Gasoline		$	697,334		$	768,904
	Station operations (4)		83,075			33,972
	Total		$	780,409		$	802,876
	Product margin
	Gasoline		$	61,699		$	33,280
	Station operations (4)(5)		36,723			19,797
	Total		$	98,422		$	53,077
	Commercial Segment:
	Sales		$	226,761		$	315,496
	Product margin		$	11,558		$	12,329
	Combined sales and product margin:
	Sales		$	2,979,116		$	5,116,928
	Product margin (6)		$	190,073		$	173,175
	Depreciation allocated to cost of sales		(21,515		)	(14,151		)
	Combined gross profit		$	168,558		$	159,024

		-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		For the three months ended March 31, 2015, the GDSO segment includes the January 2015 acquisition of Warren (see Note 2). As the Warren assets were not in place prior to January 2015, the above results are not directly comparable to the prior period.
		-4		Station operations primarily consist of convenience stores sales at the Partnership’s directly operated stores and rental income from gasoline stations leased to dealers or commissioned agents.
		-5		For the three months ended March 31, 2014, station operations includes the reclass of loss on asset sales from product margin to operating expenses to conform to the Partnership’s current presentation.
		-6		Product margin is a non-GAAP financial measure used by management and external users of our consolidated financial statements to assess our 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	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,
			2015			2014
	Combined gross profit		$	168,558		$	159,024
	Operating costs and expenses not allocated to operating segments:
	Selling, general and administrative expenses		48,786			37,298
	Operating expenses		68,656			47,952
	Amortization expense		5,341			4,528
	Loss on asset sales		437			663
	Total operating costs and expenses		123,220			90,441
	Operating income		45,338			68,583
	Interest expense		(13,963		)	(11,107		)
	Income tax expense		(966		)	(322		)
	Net income		30,409			57,154
	Net (income) loss attributable to noncontrolling interest		6			(144		)
	Net income attributable to Global Partners LP		$	30,415		$	57,010


Schedule of total assets by reportable segment	The table below presents total assets by reportable segment at March 31, 2015 and December 31, 2014 (in thousands):
			Wholesale			Commercial			GDSO		Unallocated		Total
	March 31, 2015		$	773,803		$	—		$	1,184,978	$	610,003	$	2,568,784
	December 31, 2014		$	811,535		$	—		$	622,860	$	605,582	$	2,039,977

Property_and_Equipment_Tables

Property and Equipment (Tables)	3 Months Ended
	Mar. 31, 2015
Property and Equipment
Schedule of components of property and equipment	Property and equipment consisted of the following (in thousands):
		March 31,			December 31,
		2015			2014
	Buildings and improvements	$	930,169		$	667,172
	Land	384,078			288,929
	Fixtures and equipment	32,985			26,577
	Construction in process	72,213			66,119
	Capitalized internal use software	7,530			7,530
	Total property and equipment	1,426,975			1,056,327
	Less accumulated depreciation	(252,892		)	(231,276		)
	Total	$	1,174,083		$	825,051

Environmental_Liabilities_Asse1

Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers (RINs) (Tables)	3 Months Ended
	Mar. 31, 2015
Environmental Liabilities and Renewable Identification Numbers (RINs)
Summary roll forward of the environmental liabilities	The following table presents a summary roll forward of the Partnership’s environmental liabilities at March 31, 2015 (in thousands):
		Balance at													Balance at
		December 31,		Additions in		Payments in			Dispositions			Other			March 31,
	Environmental Liability Related to:	2014		2015		2015			2015			Adjustments			2015
	Retail Gasoline Stations	$	35,792	$	36,080	$	(1,017	)	$	(67	)	$	(172	)	$	70,616
	Terminals	1,771		2,900		(16		)	—			—			4,655
	Total environmental liabilities	$	37,563	$	38,980	$	(1,033	)	$	(67	)	$	(172	)	$	75,271

	Current portion	$	3,101												$	3,085
	Long-term portion	34,462													72,186
	Total environmental liabilities	$	37,563												$	75,271

LongTerm_Incentive_Plan_Tables

Long-Term Incentive Plan (Tables)	3 Months Ended
	Mar. 31, 2015
Long-Term Incentive Plan
Summary of the status of the non-vested phantom units		Number of		Weighted
		Non-vested		Average
		Units		Grant Date
				Fair Value
	Outstanding non-vested units at December 31, 2014	532,748		$	39.29
	Granted	17,870		39.21
	Vested	(2,708	)	37.18
	Forfeited	—		—
	Outstanding non-vested units at March 31, 2015	547,910		$	39.3

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	3 Months Ended
Fair Value Measurements (Tables)	Mar. 31, 2015
Fair Value Measurements
Schedule of financial assets and financial liabilities measured at fair value on a recurring basis	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, 2015 and December 31, 2014 (in thousands):

			Fair Value as of March 31, 2015
			Level 1			Level 2			Level 3			Cash			Total
												Collateral
												Netting (2)
	Assets:
	Forward derivative contracts (1)		$	—		$	50,375		$	7,095		$	—		$	57,470
	Foreign currency derivatives		—			27			—			—			27
	Interest rate cap		—			17			—			—			17
	Exchange-traded/cleared derivative instruments (2)		78,249			—			—			(44,512		)	33,737
	Pension plans		17,316			—			—			—			17,316
	Total assets		$	95,565		$	50,419		$	7,095		$	(44,512	)	$	108,567

	Liabilities:
	Forward derivative contracts (1)		$	—		$	(25,583	)	$	(21,984	)	$	—		$	(47,567	)
	Swap agreements and options		—			(705		)	—			—			(705		)
	Interest rate swaps		—			(6,649		)	—			—			(6,649		)
	Total liabilities		$	—		$	(32,937	)	$	(21,984	)	$	—		$	(54,921	)

			Fair Value as of December 31, 2014
			Level 1			Level 2			Level 3			Cash			Total
												Collateral
												Netting (2)
	Assets:
	Forward derivative contracts (1)		$	—		$	81,421		$	2,405		$	—		$	83,826
	Foreign currency derivatives		—			9			—			—			9
	Interest rate cap		—			17			—			—			17
	Exchange-traded/cleared derivative instruments (2)		121,490			—			—			(104,292		)	17,198
	Pension plans		18,023			—			—			—			18,023
	Total assets		$	139,513		$	81,447		$	2,405		$	(104,292	)	$	119,073

	Liabilities:
	Forward derivative contracts (1)		$	—		$	(28,500	)	$	(27,928	)	$	—		$	(56,428	)
	Swap agreements and options		—			(2,079		)	—			—			(2,079		)
	Interest rate swaps		—			(6,696		)	—			—			(6,696		)
	Total liabilities		$	—		$	(37,275	)	$	(27,928	)	$	—		$	(65,203	)

		-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	The carrying value and fair value of the Partnership’s 6.25% Notes, estimated by observing market trading prices of the 6.25% Notes, were as follows (in thousands):
			March 31, 2015						December 31, 2014
			Carrying			Fair			Carrying			Fair
			Value			Value			Value			Value

	6.25% Notes		$	375,000		$	365,411		$	375,000		$	358,594


Schedule of fair value measurement to changes in significant unobservable inputs	Significant	Position	Change to Input	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	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, 2015 (in thousands):
	Fair value at December 31, 2014		$	(25,523	)
	Reclass of Level 2 inputs		—
	Realized and unrealized gains (losses) recorded in cost of sales		10,634
	Fair value at March 31, 2015		$	(14,889	)

Changes_in_Accumulated_Other_C1

Changes in Accumulated Other Comprehensive (Income) Loss (Tables)	3 Months Ended
	Mar. 31, 2015
Changes in Accumulated Other Comprehensive (Income) Loss
Schedule of 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, 2015 (in thousands):

		Pension			Derivatives			Total
		Plan
	Balance at December 31, 2014	$	(5,547	)	$	(7,705	)	$	(13,252	)
	Other comprehensive income before reclassifications of gain (loss)	109			183			292
	Amount of gain (loss) reclassified from accumulated other comprehensive income	(18		)	—			(18		)
	Total comprehensive income	91			183			274
	Balance at March 31, 2015	$	(5,456	)	$	(7,522	)	$	(12,978	)

Supplemental_Guarantor_Condens1

Supplemental Guarantor Condensed Consolidating Financial Information (Tables)	3 Months Ended
	Mar. 31, 2015
Supplemental Guarantor Condensed Consolidating Financial Statements
Schedule of condensed consolidating balance sheets	Condensed Consolidating Balance Sheet
	31-Mar-15
	(In thousands)

			Issuer			Non-
			Guarantor			Guarantor
			Subsidiaries			Subsidiary			Eliminations			Consolidated
	Assets
	Current assets:
	Cash and cash equivalents		$	2,469		$	3,876		$	—		$	6,345
	Accounts receivable, net		409,579			1,302			—			410,881
	Accounts receivable—affiliates		4,059			1,045			(1,259		)	3,845
	Inventories		371,627			—			—			371,627
	Brokerage margin deposits		33,737			—			—			33,737
	Derivative assets		57,470			—			—			57,470
	Prepaid expenses and other current assets		73,504			619			—			74,123
	Total current assets		952,445			6,842			(1,259		)	958,028
	Property and equipment, net		1,128,262			45,821			—			1,174,083
	Intangible assets, net		79,772			277			—			80,049
	Goodwill		215,924			86,063			—			301,987
	Other assets		54,637			—			—			54,637
	Total assets		$	2,431,040		$	139,003		$	(1,259	)	$	2,568,784
	Liabilities and partners’ equity
	Current liabilities:
	Accounts payable		$	306,937		$	583		$	—		$	307,520
	Accounts payable - affiliates		1,045			214			(1,259		)	—
	Working capital revolving credit facility—current portion		125,400			—			—			125,400
	Environmental liabilities—current portion		3,085			—			—			3,085
	Trustee taxes payable		90,183			—			—			90,183
	Accrued expenses and other current liabilities		60,394			524			—			60,918
	Derivative liabilities		48,272			—			—			48,272
	Total current liabilities		635,316			1,321			(1,259		)	635,378
	Working capital revolving credit facility—less current portion		150,000			—			—			150,000
	Revolving credit facility		517,400			—			—			517,400
	Senior notes		368,316			—			—			368,316
	Environmental liabilities—less current portion		72,186			—			—			72,186
	Deferred tax liability		120,708			—			—			120,708
	Other long-term liabilities		61,811			—			—			61,811
	Total liabilities		1,925,737			1,321			(1,259		)	1,925,799
	Partners’ equity
	Global Partners LP equity		505,303			88,474			—			593,777
	Noncontrolling interest		—			49,208			—			49,208
	Total partners’ equity		505,303			137,682			—			642,985
	Total liabilities and partners’ equity		$	2,431,040		$	139,003		$	(1,259	)	$	2,568,784

	Condensed Consolidating Balance Sheet
	31-Dec-14
	(In thousands)

			Issuer			Non-
			Guarantor			Guarantor
			Subsidiaries			Subsidiary			Eliminations			Consolidated
	Assets
	Current assets:
	Cash and cash equivalents		$	1,478		$	2,678		$	1,082		$	5,238
	Accounts receivable, net		455,603			1,307			820			457,730
	Accounts receivable—affiliates		3,222			820			(139		)	3,903
	Inventories		336,813			—			—			336,813
	Brokerage margin deposits		17,198			—			—			17,198
	Derivative assets		83,826			—			—			83,826
	Prepaid expenses and other current assets		55,881			634			—			56,515
	Total current assets		954,021			5,439			1,763			961,223
	Property and equipment, net		778,385			46,666			—			825,051
	Intangible assets, net		45,870			3,032			—			48,902
Goodwill		68,015			86,063			—			154,078
Other assets		50,723			—			—			50,723
Total assets		$	1,897,014		$	141,200		$	1,763		$	2,039,977
Liabilities and partners’ equity
Current liabilities:
Accounts payable		$	454,267		$	1,671		$	681		$	456,619
Line of credit		—			700			—			700
Environmental liabilities—current portion		3,101			—			—			3,101
Trustee taxes payable		105,744			—			—			105,744
Accrued expenses and other current liabilities		81,686			1,134			—			82,820
Derivative liabilities		58,507			—			—			58,507
Total current liabilities		703,305			3,505			681			707,491
Working capital revolving credit facility—less current portion		100,000			—			—			100,000
Revolving credit facility		133,800			—			—			133,800
Senior notes		368,136			—			—			368,136
Environmental liabilities—less current portion		34,462			—			—			34,462
Deferred tax liability		14,078			—			—			14,078
Other long-term liabilities		45,854			—			—			45,854
Total liabilities		1,399,635			3,505			681			1,403,821
Partners’ equity
Global Partners LP equity		497,379			88,481			1,082			586,942
Noncontrolling interest		—			49,214			—			49,214
Total partners’ equity		497,379			137,695			1,082			636,156
Total liabilities and partners’ equity		$	1,897,014		$	141,200		$	1,763		$	2,039,977


Schedule of condensed consolidating statements of income	Condensed Consolidating Statement of Income
	Three Months Ended March 31, 2015
	(In thousands)

			(Issuer)			Non-
			Guarantor			Guarantor
			Subsidiaries			Subsidiary			Eliminations			Consolidated

	Sales		$	2,975,185		$	8,050		$	(4,119	)	$	2,979,116
	Cost of sales		2,812,472			2,205			(4,119		)	2,810,558
	Gross profit		162,713			5,845			—			168,558

	Costs and operating expenses:
	Selling, general and administrative expenses		48,026			760			—			48,786
	Operating expenses		66,317			2,339			—			68,656
	Amortization expense		2,586			2,755			—			5,341
	Loss on asset sales		437			—			—			437
	Total costs and operating expenses		117,366			5,854			—			123,220

	Operating income		45,347			(9		)	—			45,338

	Interest expense		(13,958		)	(5		)	—			(13,963		)

	Income before income tax expense		31,389			(14		)	—			31,375

	Income tax expense		(966		)	—			—			(966		)

	Net income		30,423			(14		)	—			30,409

	Net income attributable to noncontrolling interest		—			6			—			6

	Net income attributable to Global Partners LP		30,423			(8		)	—			30,415

	Less: General partner’s interest in net income,		2,179			—			—			2,179
	including incentive distribution rights

	Limited partners’ interest in net income		$	28,244		$	(8	)	$	—		$	28,236

	Condensed Consolidating Statement of Income
	Three Months Ended March 31, 2014
	(In thousands)

			(Issuer)			Non-
			Guarantor			Guarantor
			Subsidiaries			Subsidiary			Eliminations			Consolidated

	Sales		$	5,114,874		$	8,145		$	(6,091	)	$	5,116,928
	Cost of sales		4,962,534			1,461			(6,091		)	4,957,904
	Gross profit		152,340			6,684			—			159,024

	Costs and operating expenses:
	Selling, general and administrative expenses		36,543			755			—			37,298
	Operating expenses		45,180			2,772			—			47,952
	Amortization expense		1,773			2,755			—			4,528
	Loss on asset sales		663			—			—			663
	Total costs and operating expenses		84,159			6,282			—			90,441

	Operating income		68,181			402			—			68,583

	Interest expense		(11,066		)	(41		)	—			(11,107		)

	Income before income tax expense		57,115			361			—			57,476

	Income tax expense		(322		)	—			—			(322		)

Net income		56,793			361			—			57,154

Net income attributable to noncontrolling interest		—			(144		)	—			(144		)

Net income attributable to Global Partners LP		56,793			217			—			57,010

Less: General partner’s interest in net income,		1,508			—			—			1,508
including incentive distribution rights

Limited partners’ interest in net income		$	55,285		$	217		$	—		$	55,502


Schedule of condensed consolidating statements of cash flows	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		$	(117,146	)	$	3,231		$	(113,915	)
	Cash flows from investing activities
	Acquisitions		(405,478		)	—			(405,478		)
	Capital expenditures		(12,712		)	(1,333		)	(14,045		)
	Proceeds from sale of property and equipment		1,044			—			1,044
	Net cash used in investing activities		(417,146		)	(1,333		)	(418,479		)
	Cash flows from financing activities
	Borrowings from on working capital revolving credit facility		175,400			—			175,400
	Borrowings from revolving credit facility		383,600			—			383,600
	Payments on line of credit		—			(700		)	(700		)
	Repurchase of common units		(2,442		)	—			(2,442		)
	Noncontrolling interest capital contribution		1,880			—			1,880
	Distribution to noncontrolling interest		(1,880		)	—			(1,880		)
	Distributions to partners		(22,357		)	—			(22,357		)
	Net cash provided by (used in) financing activities		534,201			(700		)	533,501
	Cash and cash equivalents
	(Decrease) increase in cash and cash equivalents		(91		)	1,198			1,107
	Cash and cash equivalents at beginning of period		2,560			2,678			5,238
	Cash and cash equivalents at end of period		$	2,469		$	3,876		$	6,345

	Condensed Consolidating Statement Cash Flows
	Three Months Ended March 31, 2014
	(In thousands)


			(Issuer)			Non-
			Guarantor			Guarantor
			Subsidiaries			Subsidiary			Consolidated
	Cash flows from operating activities
	Net cash provided by operating activities		$	48,362		$	4,784		$	53,146
	Cash flows from investing activities
	Capital expenditures		(12,301		)	(774		)	(13,075		)
	Proceeds from sale of property and equipment		1,746			—			1,746
	Net cash used in investing activities		(10,555		)	(774		)	(11,329		)
	Cash flows from financing activities
	Payments on working capital revolving credit facility		(20,200		)	—			(20,200		)
	Noncontrolling interest capital contribution		2,400			—			2,400
	Distribution to noncontrolling interest		(2,400		)	—			(2,400		)
	Distributions to partners		(17,770		)	—			(17,770		)
	Net cash used in financing activities		(37,970		)	—			(37,970		)
	Cash and cash equivalents
	(Decrease) increase in cash and cash equivalents		(163		)	4,010			3,847
	Cash and cash equivalents at beginning of period		8,371			846			9,217
	Cash and cash equivalents at end of period		$	8,208		$	4,856		$	13,064

Organization_and_Basis_of_Pres3

Organization and Basis of Presentation (Details)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014	Feb. 01, 2013	Jan. 07, 2015
	item
	store
Organization
Number of owned, leased and/or supplied gasoline stations	1,447
Number of owned, leased and/or supplied convenience stores	287
General partner interest (as a percent)	0.74%	0.83%
Number of common units held	30,542,344		30,604,961
Number of common units sold	3,565,000
Affiliates of general partner
Organization
Number of common units held	7,293,722
Limited partner ownership interest (as a percent)	23.50%
Decrease in number of common units held	4,446,575
Affiliates of general partner \| Directors and Chief Executive Officers
Organization
Number of common units held	2,306,960
AE Holdings
Organization
Number of common units held	5,850,000
Limited partner ownership interest (as a percent)	37.90%
Decrease in Limited partner ownership interest (as a percent)	23.50%
Number of common units sold	1,956,234
Basin Transload LLC
Organization
Percentage of outstanding membership interests acquired				60.00%
Warren Equities Inc
Organization
Percentage of outstanding membership interests acquired					100.00%
Members of Slifka family \| AE Holdings
Organization
Number of common units held	1,586,806

Organization_and_Basis_of_Pres4

Organization and Basis of Presentation (Details 2) (Sales)	3 Months Ended
Organization and Basis of Presentation (Details 2) (Sales)	Mar. 31, 2015	Mar. 31, 2014
Product
Concentration of Risk
Percentage of total sales	100.00%	100.00%
Product \| Gasoline sales: gasoline and gasoline blendstocks such as ethanol and naphtha
Concentration of Risk
Percentage of total sales	50.00%	54.00%
Product \| Crude oil sales and logistics revenue
Concentration of Risk
Percentage of total sales	9.00%	12.00%
Product \| Distillates (home heating oil, diesel and kerosene), residual oil, natural gas and propane sales
Concentration of Risk
Percentage of total sales	38.00%	33.00%
Product \| Convenience store sales, rental income and sundry sales
Concentration of Risk
Percentage of total sales	3.00%	1.00%
Customer
Concentration of Risk
Number of significant customers	0	1
Customer \| ExxonMobil
Concentration of Risk
Percentage of total sales		14.00%

Business_Combinations_Details

Business Combinations (Details) (USD $)	3 Months Ended	0 Months Ended
Business Combinations (Details) (USD $)	Mar. 31, 2015	Jan. 07, 2015	Jan. 14, 2015	Dec. 31, 2014
Acquisitions
Number of common units sold	3,565,000
Liabilities assumed:
Goodwill	$301,987,000			$154,078,000
GDSO
Liabilities assumed:
Goodwill	180,235,000			32,326,000
Underwriters allotment option
Acquisitions
Number of common units sold		3,565,000
Warren Equities Inc
Acquisitions
Percentage of outstanding membership interests acquired from AE Holdings		100.00%
Number of convenience stores and related fuel operations owned by acquiree		147
Number of business location agents operated by acquiree		53
Number of fuel supply rights for dealers owned by acquiree		320
Restructuring Charges	2,300,000
Restructuring charge paid	500,000
Restructuring reserve expected to be paid	1,800,000
Increase in fuel sales (in gallons)	500,000,000
Number of owned, leased and/or supplied gasoline stations	1,500
Purchase price		381,800,000
Intangible assets acquired
Amortization period	10 years
Amortization expense	800,000
Estimated remaining amortization expense
2015 (1/7/15 - 12/31/15)	2,685,000
2016	3,580,000
2017	3,580,000
2018	3,580,000
2019	3,580,000
Thereafter	17,960,000
Total	34,965,000
Assets purchased:
Accounts receivable		5,372,000
Inventory		19,199,000
Prepaid expenses		12,552,000
Property and equipment		331,291,000
Intangibles		36,490,000
Other non-current assets		20,586,000
Total identifiable assets purchased		425,490,000
Liabilities assumed:
Accounts payable		-21,511,000
Assumption of environmental liabilities		-36,080,000
Taxes payable		-5,538,000
Accrued expenses		-11,595,000
Long-term deferred taxes		-105,855,000
Other non-current liabilities		-10,992,000
Total liabilities assumed		-191,571,000
Net identifiable assets acquired		233,919,000
Goodwill		147,909,000
Net assets acquired		381,828,000
Fair value assigned to intangibles		36,500,000
Acquisition related costs
Acquisition related costs incurred	6,100,000
Warren Equities Inc \| Supply Contracts
Intangible assets acquired
Amortization period	5 years
Warren Equities Inc \| GDSO
Liabilities assumed:
Goodwill	147,900,000
Warren Equities Inc \| Selling, general and administrative expenses
Acquisition related costs
Acquisition related costs incurred	4,400,000
Revere terminal
Acquisitions
Purchase price			23,650,000
Assets purchased:
Property and equipment	28,300,000
Liabilities assumed:
Total liabilities assumed	$4,600,000

Business_Combinations_Details_

Business Combinations (Details 2) (USD $)	3 Months Ended
Business Combinations (Details 2) (USD $)	Mar. 31, 2015	Mar. 31, 2014	Mar. 31, 2014	Jan. 07, 2015
Goodwill
Goodwill, Beginning Balance	$154,078,000
Acquisition of Warren	147,909,000
Goodwill, Ending Balance	301,987,000
Supplemental Pro-Forma Information
Sales	5,496,851,000
Net income attributable to Global Partners LP	51,637,000
Net income per limited partner unit, basic and diluted	$1.84
Sales	2,979,116,000	5,116,928,000
GDSO
Goodwill
Goodwill, Beginning Balance	32,326,000
Acquisition of Warren	147,909,000
Goodwill, Ending Balance	180,235,000
Supplemental Pro-Forma Information
Sales	780,409,000	802,876,000
Wholesale Segment
Goodwill
Goodwill, Beginning Balance	121,752,000
Goodwill, Ending Balance	121,752,000
Supplemental Pro-Forma Information
Sales	1,971,946,000	3,998,556,000
Warren Equities Inc
Goodwill
Goodwill, Beginning Balance				147,909,000
Goodwill, Ending Balance				147,909,000
Supplemental Pro-Forma Information
Sales			247,700,000
Net Loss			-1,000,000
Warren Equities Inc \| GDSO
Goodwill
Goodwill, Ending Balance	$147,900,000

Net_Income_Per_Limited_Partner2

Net Income Per Limited Partner Unit (Details) (USD $)	3 Months Ended		0 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Apr. 22, 2015	Dec. 31, 2014
Net Income (Loss) Per Limited Partner Unit
Repurchased units not deemed outstanding	453,219			390,602
Net Income (Loss) Per Limited Partner Unit
Net income attributable to Global Partners LP	$30,415	$57,010
Declared distribution	23,260	18,323
Assumed allocation of undistributed net income	7,155	38,687
Assumed allocation of net income	30,415	57,010
Denominator:
Basic weighted average limited partner units outstanding	30,599,000	27,261,000
Diluted weighted average limited partner units outstanding	30,712,000	27,296,000
Basic net income per limited partner unit (in dollars per unit)	$0.92	$2.04
Diluted net income per limited partner unit (in dollars per unit)	$0.92	$2.03
Number of common units sold	3,565,000
General partner interest (as a percent)	0.74%	0.83%
General Partner Interest
Denominator:
Quarterly cash distribution declared (in dollars per unit)			$0.68
Common Unitholders
Net Income (Loss) Per Limited Partner Unit
Net income attributable to Global Partners LP	28,236	55,502
Declared distribution	21,076	17,145
Assumed allocation of undistributed net income	7,160	38,357
Assumed allocation of net income	28,236	55,502
Denominator:
Basic weighted average limited partner units outstanding	30,599,000	27,261,000
Dilutive effect of phantom units	113,000	35,000
Diluted weighted average limited partner units outstanding	30,712,000	27,296,000
Basic net income per limited partner unit (in dollars per unit)	$0.92	$2.04
Diluted net income per limited partner unit (in dollars per unit)	$0.92	$2.03
General Partner Interest
Net Income (Loss) Per Limited Partner Unit
Net income attributable to Global Partners LP	2,179	1,508
Declared distribution	157	143
Assumed allocation of undistributed net income	-5	330
Assumed allocation of net income	152	473
IDRs
Net Income (Loss) Per Limited Partner Unit
Declared distribution	2,027	1,035
Assumed allocation of net income	$2,027	$1,035

Inventories_Details

Inventories (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
Inventories
Inventories	$371,627,000	$336,813,000
Positive exchange balances on inventory exchange agreements accounted for as accounts receivable	9,600,000	3,900,000
Negative exchange balances on inventory exchange agreements accounted for as accounts payable	12,100,000	16,500,000
Distillates: home heating oil, diesel and kerosene
Inventories
Inventories	103,057,000	163,679,000
Gasoline
Inventories
Inventories	96,846,000	82,080,000
Gasoline blendstocks
Inventories
Inventories	47,651,000	33,760,000
Crude Oil
Inventories
Inventories	86,385,000	20,769,000
Residual Oil
Inventories
Inventories	13,172,000	20,602,000
Propane and other
Inventories
Inventories	2,037,000	5,123,000
Renewable identification numbers (RINs)
Inventories
Inventories	1,213,000	2,057,000
Convenience store inventory
Inventories
Inventories	$21,266,000	$8,743,000

Derivative_Financial_Instrumen2

Derivative Financial Instruments (Details)	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2015
In Millions, unless otherwise specified	Exchange-Traded Derivatives	Exchange-Traded Derivatives	OTC Derivatives (Petroleum/Ethanol)	OTC Derivatives (Petroleum/Ethanol)	OTC Derivatives (Natural Gas)	OTC Derivatives (Natural Gas)	Interest rate swaps	Interest rate cap	Open Forward Exchange Contracts	Open Forward Exchange Contracts
	Long	Short	Long	Short	Long	Short	USD ($)	USD ($)	USD ($)	CAD
	item	item	item	item	item	item
Volume of activity related to derivative financial instruments
Nonmonetary units	46,736,000	-50,292,000	13,318,000	-10,167,000	10,607,000	-10,661,000
Monetary units							$200	$100	$4.70	6
Forward rate of CAD to USD									1.2662	1.2662

Derivative_Financial_Instrumen3

Derivative Financial Instruments (Details 2) (Derivatives in Fair Value Hedging Relationships, Cost of sales, USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Futures contracts
Fair values of derivative financial instruments
Amount of Gain (Loss) Recognized in Income on Derivatives	$26,176	$16,373
Inventories
Fair values of derivative financial instruments
Amount of Gain (Loss) Recognized in Income on Hedged Items	($23,621)	($16,209)

Derivative_Financial_Instrumen4

Derivative Financial Instruments (Details 3) (USD $)	1 Months Ended
Derivative Financial Instruments (Details 3) (USD $)	Sep. 30, 2013	Oct. 31, 2009	Apr. 30, 2011	Mar. 31, 2015	Dec. 31, 2014	Jun. 19, 2014
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 revolving credit facility
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 interest rate swap agreements held				2
Cash Flow Hedges \| Interest rate swaps \| Revolving credit facility
Fair values of derivative financial instruments
Hedged borrowings	100,000,000	100,000,000
Borrowings variable interest rate	one-month LIBOR	one-month LIBOR
Fixed rate (as a percent)	1.82%	3.93%
Cash Flow Hedges \| Interest rate cap \| Revolving credit facility
Fair values of derivative financial instruments
Hedged borrowings			$100,000,000
Borrowings variable interest rate			one-month LIBOR
Maximum cap rate (as a percent)			5.50%

Derivative_Financial_Instrumen5

Derivative Financial Instruments (Details 4) (USD $)	3 Months Ended
Derivative Financial Instruments (Details 4) (USD $)	Mar. 31, 2015	Mar. 31, 2014
Gains and losses from derivatives
Remaining unamortized prepaid interest rate caplets	$900,000
Cash Flow Hedges
Gains and losses from derivatives
Amount of Gain (Loss) Recognized in Other Comprehensive Income on Derivatives	47,000	659,000
Cash Flow Hedges \| Interest rate swaps
Gains and losses from derivatives
Amount of Gain (Loss) Recognized in Other Comprehensive Income on Derivatives	47,000	677,000
Cash Flow Hedges \| Interest rate cap
Gains and losses from derivatives
Amount of Gain (Loss) Recognized in Other Comprehensive Income on Derivatives		($18,000)

Derivative_Financial_Instrumen6

Derivative Financial Instruments (Details 5) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Derivative Financial Instruments
Amount of Gain (Loss) Recognized in Income on Derivatives	$0	$0
Derivatives not designated as hedging instruments
Derivative Financial Instruments
Amount of Gain (Loss) Recognized in Income on Derivatives	3,669	15,486
Derivatives not designated as hedging instruments \| Product contracts \| Maximum
Derivative Financial Instruments
Nonmonetary units	250,000
Derivatives not designated as hedging instruments \| Product contracts \| Cost of sales
Derivative Financial Instruments
Amount of Gain (Loss) Recognized in Income on Derivatives	3,651	15,543
Derivatives not designated as hedging instruments \| Foreign currency derivatives \| Cost of sales
Derivative Financial Instruments
Amount of Gain (Loss) Recognized in Income on Derivatives	$18	($57)

Derivative_Financial_Instrumen7

Derivative Financial Instruments (Details 6) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Credit Risk
Number of clearing brokers, primarily utilized	3
Cash Flow Hedges
Fair values of derivative financial instruments
Asset Derivatives	$135,763	$205,342
Liability Derivatives	54,921	65,203
Cash Flow Hedges \| Exchange-Traded Derivatives \| Broker margin deposits
Fair values of derivative financial instruments
Asset Derivatives	78,249	121,490
Cash Flow Hedges \| Forward derivative contracts
Fair values of derivative financial instruments
Asset Derivatives	57,470	83,826
Liability Derivatives	48,272	58,507
Cash Flow Hedges \| Open Forward Exchange Contracts \| Other assets
Fair values of derivative financial instruments
Asset Derivatives	27	9
Cash Flow Hedges \| Interest rate cap \| Other assets
Fair values of derivative financial instruments
Asset Derivatives	17	17
Cash Flow Hedges \| Interest rate swaps \| Other long-term liabilities
Fair values of derivative financial instruments
Liability Derivatives	6,649	6,696
Derivatives designated as hedging instruments and firm commitments \| Cash Flow Hedges
Fair values of derivative financial instruments
Asset Derivatives	17,895	30,600
Derivatives designated as hedging instruments and firm commitments \| Cash Flow Hedges \| Exchange-Traded Derivatives \| Broker margin deposits
Fair values of derivative financial instruments
Asset Derivatives	17,895	30,600
Derivatives not designated as hedging instruments \| Cash Flow Hedges
Fair values of derivative financial instruments
Asset Derivatives	117,868	174,742
Liability Derivatives	54,921	65,203
Derivatives not designated as hedging instruments \| Cash Flow Hedges \| Exchange-Traded Derivatives \| Broker margin deposits
Fair values of derivative financial instruments
Asset Derivatives	60,354	90,890
Derivatives not designated as hedging instruments \| Cash Flow Hedges \| Forward derivative contracts
Fair values of derivative financial instruments
Asset Derivatives	57,470	83,826
Liability Derivatives	48,272	58,507
Derivatives not designated as hedging instruments \| Cash Flow Hedges \| Open Forward Exchange Contracts \| Other assets
Fair values of derivative financial instruments
Asset Derivatives	27	9
Derivatives not designated as hedging instruments \| Cash Flow Hedges \| Interest rate cap \| Other assets
Fair values of derivative financial instruments
Asset Derivatives	17	17
Derivatives not designated as hedging instruments \| Cash Flow Hedges \| Interest rate swaps \| Other long-term liabilities
Fair values of derivative financial instruments
Liability Derivatives	$6,649	$6,696

Debt_Details

Debt (Details) (USD $)	3 Months Ended		0 Months Ended
Debt (Details) (USD $)	Mar. 31, 2015	Mar. 31, 2014	Jun. 24, 2014	Jun. 24, 2014	Dec. 31, 2014	Jun. 19, 2014	Dec. 09, 2013
Debt
Working capital revolving credit facility-current portion	$125,400,000				$0
Debt default
Amortization expenses	1,459,000	1,283,000
Senior Notes 6.25 Percent Due 2022
Debt
Aggregate principal amount	375,000,000				375,000,000	375,000,000
Minimum percentage of principal amount held by trustee or the holders to declare notes due and payable			0.25%
Stated interest rate (as a percent)	6.25%		6.25%	6.25%		6.25%
Percentage of notes exchanged for SEC registered notes			100.00%
Debt default
Period for payment of default			60 days
Indebtedness unpaid or accelerated debt triggering debt default			15,000,000
Swing line loans
Debt
Total available commitments	1,775,000,000
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 Two [Member] \| Senior Notes 6.25 Percent Due 2022
Debt
Redemption price as a percentage of principal amount				104.69%
Debt Instrument, Redemption, Period Three [Member] \| Senior Notes 6.25 Percent Due 2022
Debt
Redemption price as a percentage of principal amount				103.13%
Debt Instrument, Redemption, Period Four [Member] \| Senior Notes 6.25 Percent Due 2022
Debt
Redemption price as a percentage of principal amount				101.56%
Debt Instrument, Redemption, Period Five [Member] \| Senior Notes 6.25 Percent Due 2022
Debt
Redemption price as a percentage of principal amount				100.00%
Credit Agreement
Debt
Number of line of credit facilities	2
Average interest rates (as a percent)	3.40%	3.60%
Number of interest rate swaps	2
Total borrowings outstanding	792,800,000
Total remaining availability for borrowings and letters of credit	900,000,000				1,400,000,000
Debt default
Amortization expenses	1,500,000	1,300,000
Credit Agreement \| Maximum
Debt
Commitment fee on the unused portion (as a percent)	0.50%
Credit Agreement \| Minimum
Debt
Commitment fee on the unused portion (as a percent)	0.38%
Credit Agreement \| Accordion feature \| Maximum
Debt
Additional available commitments	300,000,000
Increased credit facility	2,075,000,000
Working capital revolving credit facility
Debt
Total available commitments	1,000,000,000
Long-term portion	150,000,000				100,000,000
Working capital revolving credit facility \| Eurocurrency/Eurodollar rate
Debt
Variable rate basis	Eurocurrency rate
Working capital revolving credit facility \| Eurocurrency/Eurodollar rate \| Maximum
Debt
Interest rate margin (as a percent)	2.50%
Working capital revolving credit facility \| Eurocurrency/Eurodollar rate \| Minimum
Debt
Interest rate margin (as a percent)	2.00%
Working capital revolving credit facility \| Cost of funds rate
Debt
Variable rate basis	cost of funds
Working capital revolving credit facility \| Cost of funds rate \| Maximum
Debt
Interest rate margin (as a percent)	2.50%
Working capital revolving credit facility \| Cost of funds rate \| Minimum
Debt
Interest rate margin (as a percent)	2.00%
Working capital revolving credit facility \| Base rate
Debt
Variable rate basis	base rate
Working capital revolving credit facility \| Base rate \| Maximum
Debt
Interest rate margin (as a percent)	1.50%
Working capital revolving credit facility \| Base rate \| Minimum
Debt
Interest rate margin (as a percent)	1.00%
Working capital revolving credit facility \| Swing line loans
Debt
Total available commitments	50,000,000
Working capital revolving credit facility \| Credit Agreement \| Accordion feature \| Maximum
Debt
Additional available commitments	300,000,000
Letter of credit
Debt
Outstanding letters of credit	59,800,000
Revolving credit facility
Debt
Total available commitments	775,000,000
Total borrowings outstanding	517,400,000
Revolving credit facility \| Eurocurrency/Eurodollar rate
Debt
Variable rate basis	Eurocurrency rate
Revolving credit facility \| Eurocurrency/Eurodollar rate \| Maximum
Debt
Interest rate margin (as a percent)	3.25%
Revolving credit facility \| Eurocurrency/Eurodollar rate \| Minimum
Debt
Interest rate margin (as a percent)	2.25%
Revolving credit facility \| Cost of funds rate
Debt
Variable rate basis	cost of funds
Revolving credit facility \| Cost of funds rate \| Maximum
Debt
Interest rate margin (as a percent)	3.25%
Revolving credit facility \| Cost of funds rate \| Minimum
Debt
Interest rate margin (as a percent)	2.25%
Revolving credit facility \| Base rate
Debt
Variable rate basis	base rate
Revolving credit facility \| Base rate \| Maximum
Debt
Interest rate margin (as a percent)	2.25%
Revolving credit facility \| Base rate \| Minimum
Debt
Interest rate margin (as a percent)	1.25%
Revolving credit facility \| Credit Agreement \| Accordion feature \| Maximum
Debt
Additional available commitments	300,000,000
Credit Agreement
Debt
Total available commitments	1,775,000,000
Line of Credit \| Basin Transload LLC
Debt
Total available commitments							10,000,000
Total borrowings outstanding	$0				$700,000

RelatedParty_Transactions_Deta

Related-Party Transactions (Details) (USD $)	3 Months Ended
Related-Party Transactions (Details) (USD $)	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Information on related party transaction
Receivables from related parties	$3,845,000		$3,903,000
GPC
Information on related party transaction
Receivables from related parties			108,000
GPC \| Second amended and restated terminal storage rental and throughput agreement \| Members of Slifka family
Related Party Transactions
Percentage ownership interest	100.00%
GPC \| Amended and restated services agreement
Information on related party transaction
Income from services provided to related parties	8,000	24,000
AE Holdings \| Shared services agreement \| Global Companies LLC
Information on related party transaction
Amount to be paid per year	15,000
Notice period to terminate the receipt of services under the agreement	90 days
General Partner Interest
Information on related party transaction
Expenses incurred from transactions with related parties	29,400,000	19,000,000
Receivables from related parties	3,845,000		3,795,000
General Partner Interest \| Second amended and restated terminal storage rental and throughput agreement \| Members of Slifka family
Information on related party transaction
Expenses incurred from transactions with related parties	$800,000	$2,300,000

Cash_Distributions_Details

Cash Distributions (Details) (USD $)	0 Months Ended	3 Months Ended	0 Months Ended	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Feb. 13, 2015	Mar. 31, 2015	Apr. 22, 2015	Dec. 31, 2014
	Feb. 13, 2015	item	Apr. 22, 2015	Dec. 31, 2014
Cash Distributions
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		4
Cash Distribution Payment
Per Unit Cash Distribution (in dollars per unit)	$0.67
Incentive Distribution	$1,591
Cash distribution to common unitholders	22,357
General Partner Interest
Distribution declared
Quarterly cash distribution declared (in dollars per unit)			$0.68
Subsequent event \| General Partner Interest
Cash Distributions
Total Quarterly Distribution Target Amount (in dollars per unit)			$0.68
Distribution declared
Quarterly cash distribution declared (in dollars per unit)			$0.68
Subsequent event \| General Partner Interest \| Annualized basis
Distribution declared
Quarterly cash distribution declared (in dollars per unit)			$2.72
Common Unitholders
Cash Distribution Payment
Cash distribution to common unitholders	20,612
General Partner Interest
Cash Distribution Payment
Cash distribution to common unitholders	$154
Minimum Quarterly Distribution \| Common Unitholders
Cash Distributions
Marginal Percentage Interest in Distributions		99.26%
Minimum Quarterly Distribution \| General Partner Interest
Cash Distributions
Marginal Percentage Interest in Distributions		0.74%
First Target Distribution \| Maximum
Cash Distributions
Total Quarterly Distribution Target Amount (in dollars per unit)		0.4625
First Target Distribution \| Common Unitholders
Cash Distributions
Marginal Percentage Interest in Distributions		99.26%
First Target Distribution \| General Partner Interest
Cash Distributions
Marginal Percentage Interest in Distributions		0.74%
Second Target Distribution \| Minimum
Cash Distributions
Total Quarterly Distribution Target Amount (in dollars per unit)		0.4625
Second Target Distribution \| Maximum
Cash Distributions
Total Quarterly Distribution Target Amount (in dollars per unit)		0.5375
Second Target Distribution \| Common Unitholders
Cash Distributions
Marginal Percentage Interest in Distributions		86.26%
Second Target Distribution \| General Partner Interest
Cash Distributions
Marginal Percentage Interest in Distributions		13.74%
Third Target Distribution
Cash Distribution Payment
Per Unit Cash Distribution (in dollars per unit)				$0.67
Third Target Distribution \| Minimum
Cash Distributions
Total Quarterly Distribution Target Amount (in dollars per unit)		0.5375
Third Target Distribution \| Maximum
Cash Distributions
Total Quarterly Distribution Target Amount (in dollars per unit)		0.6625
Third Target Distribution \| Common Unitholders
Cash Distributions
Marginal Percentage Interest in Distributions		76.26%
Third Target Distribution \| General Partner Interest
Cash Distributions
Marginal Percentage Interest in Distributions		23.74%
Thereafter \| Minimum
Cash Distributions
Total Quarterly Distribution Target Amount (in dollars per unit)		0.6625
Thereafter \| Common Unitholders
Cash Distributions
Marginal Percentage Interest in Distributions		51.26%
Thereafter \| General Partner Interest
Cash Distributions
Marginal Percentage Interest in Distributions		48.74%

Segment_Reporting_Details

Segment Reporting (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Summarized financial information for the Partnership's reportable segments
Sales	$2,979,116	$5,116,928
Product margin	190,073	173,175
Gross profit	168,558	159,024
Wholesale Segment
Summarized financial information for the Partnership's reportable segments
Sales	1,971,946	3,998,556
Product margin	80,093	107,769
Gasoline sales: gasoline and gasoline blendstocks such as ethanol and naphtha
Summarized financial information for the Partnership's reportable segments
Sales	776,143	1,994,556
Product margin	29,829	49,663
Crude Oil
Summarized financial information for the Partnership's reportable segments
Sales	252,110	591,229
Product margin	15,257	23,490
Other oils and related products
Summarized financial information for the Partnership's reportable segments
Sales	943,693	1,412,771
Product margin	35,007	34,616
GDSO
Summarized financial information for the Partnership's reportable segments
Sales	780,409	802,876
Product margin	98,422	53,077
Gasoline
Summarized financial information for the Partnership's reportable segments
Sales	697,334	768,904
Product margin	61,699	33,280
Station operations
Summarized financial information for the Partnership's reportable segments
Sales	83,075	33,972
Product margin	36,723	19,797
Commercial Segment
Summarized financial information for the Partnership's reportable segments
Sales	226,761	315,496
Product margin	11,558	12,329
Operating costs and expenses not allocated to operating segments
Summarized financial information for the Partnership's reportable segments
Depreciation allocated to cost of sales	($21,515)	($14,151)

Segment_Reporting_Details_2

Segment Reporting (Details 2) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Reconciliation of the totals reported for the reportable segments to the applicable line items in the consolidated financial statements
Combined gross profit	$168,558	$159,024
Operating costs and expenses
Selling, general and administrative expenses	48,786	37,298
Operating expenses	68,656	47,952
Amortization expense	5,341	4,528
Loss on asset sales	437	663
Total costs and operating expenses	123,220	90,441
Operating income	45,338	68,583
Interest expense	-13,963	-11,107
Income tax expense	-966	-322
Net income	30,409	57,154
Net (income) loss attributable to noncontrolling interest	6	-144
Net income attributable to Global Partners LP	30,415	57,010
Operating costs and expenses not allocated to operating segments
Operating costs and expenses
Selling, general and administrative expenses	48,786	37,298
Operating expenses	68,656	47,952
Amortization expense	5,341	4,528
Total costs and operating expenses	$123,220	$90,441

Segment_Reporting_Details_3

Segment Reporting (Details 3) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Segment assets
Total	$2,568,784	$2,039,977
Wholesale Segment
Segment assets
Total	773,803	811,535
GDSO
Segment assets
Total	1,184,978	622,860
Operating costs and expenses not allocated to operating segments
Segment assets
Total	$610,003	$605,582

Property_and_Equipment_Details

Property and Equipment (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Property and Equipment
Total property and equipment	$1,426,975	$1,056,327
Less accumulated depreciation	-252,892	-231,276
Total	1,174,083	825,051
Buildings and improvements
Property and Equipment
Total property and equipment	930,169	667,172
Land
Property and Equipment
Total property and equipment	384,078	288,929
Fixtures and equipment
Property and Equipment
Total property and equipment	32,985	26,577
Construction in process
Property and Equipment
Total property and equipment	72,213	66,119
Construction in process \| Ethanol plant
Property and Equipment
Total	30,500	30,500
Capitalized internal use software
Property and Equipment
Total property and equipment	$7,530	$7,530

Environmental_Liabilities_Asse2

Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers (RINs) (Details) (USD $)	3 Months Ended	12 Months Ended	0 Months Ended
	Mar. 31, 2015	Dec. 31, 2012	Jun. 30, 2010	Dec. 31, 2014	Sep. 30, 2010	Mar. 31, 2012	Nov. 30, 2007	Jan. 07, 2015	Jan. 14, 2015
	Mar. 31, 2015	item	item	Dec. 31, 2014	Sep. 30, 2010	Mar. 31, 2012	Nov. 30, 2007	Jan. 07, 2015	Jan. 14, 2015
Changes in environmental liabilities during the period
Balance at the beginning of the period	$37,563,000
Additions	38,980,000
Payments	-1,033,000
Dispositions	-67,000
Other Adjustments	-172,000
Balance at the end of the period	75,271,000
Environmental liabilities
Current portion	3,085,000			3,101,000
Long-term portion	72,186,000			34,462,000
Total environmental liabilities	75,271,000
Asset Retirement Obligations
Total assets retirement obligations	5,700,000			3,800,000
Renewable Identification Numbers (RINs)
Settlement period of RVO	1 year
RIN Deficiency	300,000			300,000
ExxonMobil Gasoline Stations
Environmental Liabilities
Assumed environmental liabilities, recorded on an undiscounted basis					30,000,000
Mutual Oil
Environmental Liabilities
Number of gasoline stations acquired		6
Assumed environmental liabilities, recorded on an undiscounted basis		600,000
Retail Gasoline Stations
Changes in environmental liabilities during the period
Balance at the beginning of the period	35,792,000
Additions	36,080,000
Payments	-1,017,000
Dispositions	-67,000
Other Adjustments	-172,000
Balance at the end of the period	70,616,000
Environmental liabilities
Total environmental liabilities	70,616,000
Terminals
Changes in environmental liabilities during the period
Balance at the beginning of the period	1,771,000
Additions	2,900,000
Payments	-16,000
Balance at the end of the period	4,655,000
Environmental liabilities
Total environmental liabilities	4,655,000
Alliance
Environmental Liabilities
Assumed environmental liabilities, recorded on an undiscounted basis						16,100,000
Newburgh Terminals Acquisition
Environmental Liabilities
Number of refined petroleum products terminals acquired			3
Assumed environmental liabilities, recorded on an undiscounted basis			1,500,000
Glenwood Landing and Inwood, New York Terminal Acquisitions
Environmental Liabilities
Assumed environmental liabilities, recorded on an undiscounted basis							1,200,000
Warren Equities Inc
Environmental Liabilities
Assumed environmental liabilities, recorded on an undiscounted basis								36,100,000
Asset Retirement Obligations
Total assets retirement obligations	1,800,000
Revere terminal
Environmental Liabilities
Assumed environmental liabilities, recorded on an undiscounted basis									$2,900,000

LongTerm_Incentive_Plan_Detail

Long-Term Incentive Plan (Details) (USD $)	3 Months Ended	12 Months Ended	71 Months Ended	12 Months Ended	0 Months Ended
Long-Term Incentive Plan (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014	Mar. 31, 2015	Dec. 31, 2013	Dec. 31, 2014
Long-Term Incentive Plan
Number of common units available for issuance	4,300,000		4,300,000
Long-Term Incentive Plan
Phantom units granted (in shares)	17,870
Compensation expenses for phantom unit awards	$1,000,000	$900,000
Repurchase Program
Aggregate common units authorized to be acquired (in shares)	1,242,427		1,242,427
Common units repurchased by General Partner (in shares)			791,792
Common units repurchased by General Partner	2,400,000		23,300,000
Repurchased units not deemed outstanding	453,219	390,602	453,219		390,602
Number of Non-vested Units
Outstanding non-vested units at the beginning of the period (in shares)	532,748
Granted (in shares)	17,870
Vested (in shares)	-2,708
Outstanding non-vested units at the end of the period (in shares)	547,910	532,748	547,910		532,748
Weighted Average Grant Date Fair Value
Outstanding non-vested units at the beginning of the period (in dollars per share)	$39.29
Granted (in dollars per share)	$39.21
Vested (in dollars per share)	$37.18
Outstanding non-vested units at the end of the period (in dollars per share)	$39.30	$39.29	$39.30		39.29
Phantom Unit Awards
Long-Term Incentive Plan
Phantom units granted (in shares)		44,902		498,112
Number of Non-vested Units
Granted (in shares)		44,902		498,112
CEO Authorized LTIP
Long-Term Incentive Plan
Aggregate amount of CEO authorized shares to grant in each calendar year	2,000,000
CEO Authorized LTIP expiration period	3 years
Maximum value of grant	550,000
CEO Authorized LTIP vesting period	6 years
One employee \| Phantom Unit Awards
Long-Term Incentive Plan
Phantom units granted (in shares)					10,266
Number of Non-vested Units
Granted (in shares)					10,266
Non-employee directors
Long-Term Incentive Plan
Compensation cost related to the non-vested awards not yet recognized	$15,300,000		$15,300,000
Non-employee directors \| Phantom Unit Awards
Long-Term Incentive Plan
Phantom units granted (in shares)	17,870				10,266
Number of Non-vested Units
Granted (in shares)	17,870				10,266

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014	Jun. 24, 2014	Jun. 19, 2014
Changes in fair value of Level 3 financial assets
Estimates Margin for Transportation and Throughput Costs Per Barrel	7.45	10.75
Senior Notes 6.25 Percent Due 2022
Liabilities:
Stated interest rate (as a percent)	6.25%			6.25%	6.25%
Carrying value of debt instrument	$375,000		$375,000		$375,000
Fair value of debt instrument	365,411		358,594
Level 3
Changes in fair value of Level 3 financial assets
Fair value at the beginning of the period	-25,523
Realized and unrealized gains (losses) recorded in cost of sales	10,634
Fair value at the end of the period	-14,889
Recurring basis
Assets:
Total assets	-44,512		-104,292
Recurring basis \| Exchange-Traded Derivatives
Assets:
Cash Collateral Netting	-44,512		-104,292
Recurring basis \| Total estimated fair value
Assets:
Pension plans	17,316		18,023
Total assets	108,567		119,073
Liabilities:
Total liabilities	-54,921		-65,203
Recurring basis \| Total estimated fair value \| Forward derivative contracts
Assets:
Derivative assets	57,470		83,826
Liabilities:
Derivative liabilities	-47,567		-56,428
Recurring basis \| Total estimated fair value \| Swap agreements and option contracts
Liabilities:
Derivative liabilities	-705		-2,079
Recurring basis \| Total estimated fair value \| Interest rate cap
Assets:
Derivative assets	17		17
Recurring basis \| Total estimated fair value \| Exchange-Traded Derivatives
Assets:
Exchange-traded/cleared derivative instruments	33,737		17,198
Recurring basis \| Total estimated fair value \| Interest rate swaps
Liabilities:
Derivative liabilities	-6,649
Recurring basis \| Total estimated fair value \| Foreign currency derivatives
Assets:
Derivative assets	27		9
Recurring basis \| Total estimated fair value \| Interest rate swaps
Liabilities:
Derivative liabilities			-6,696
Recurring basis \| Level 1
Assets:
Pension plans	17,316		18,023
Total assets	95,565		139,513
Recurring basis \| Level 1 \| Exchange-Traded Derivatives
Assets:
Exchange-traded/cleared derivative instruments	78,249		121,490
Recurring basis \| Level 2
Assets:
Total assets	50,419		81,447
Liabilities:
Total liabilities	-32,937		-37,275
Recurring basis \| Level 2 \| Forward derivative contracts
Assets:
Derivative assets	50,375		81,421
Liabilities:
Derivative liabilities	-25,583		-28,500
Recurring basis \| Level 2 \| Swap agreements and option contracts
Liabilities:
Derivative liabilities	-705		-2,079
Recurring basis \| Level 2 \| Interest rate cap
Assets:
Derivative assets	17		17
Recurring basis \| Level 2 \| Interest rate swaps
Liabilities:
Derivative liabilities	-6,649		-6,696
Recurring basis \| Level 2 \| Foreign currency derivatives
Assets:
Derivative assets	27		9
Recurring basis \| Level 3
Assets:
Total assets	7,095		2,405
Liabilities:
Total liabilities	-21,984		-27,928
Recurring basis \| Level 3 \| Forward derivative contracts
Assets:
Derivative assets	7,095		2,405
Liabilities:
Derivative liabilities	($21,984)		($27,928)

Income_Taxes_Details

Income Taxes (Details)	3 Months Ended
	Mar. 31, 2015
	item
Income Taxes
Number of wholly owned subsidiaries which are taxable for federal and state income tax purposes	1

Legal_Proceedings_Details

Legal Proceedings (Details) (USD $)	3 Months Ended	0 Months Ended
	Mar. 31, 2015	Mar. 27, 2014	Aug. 17, 2014
	Mar. 31, 2015	Mar. 27, 2014	gal
Other legal proceedings
Civil penalty assessment sought by Oregon Department of Environmental Quality	$12,000,000
Storage and transloading capacity of oil or ethanol			1,800,000,000
Civil penalty payable	102,292
Violation of existing permit
Other legal proceedings
Civil penalty assessment sought by Oregon Department of Environmental Quality		$117,292

Changes_in_Accumulated_Other_C2

Changes in Accumulated Other Comprehensive Income (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Changes in Accumulated other comprehensive (income) loss
Balance at the beginning of the period	($13,252)
Other comprehensive income before reclassifications of gain (loss)	292
Amount of gain (loss) reclassified from accumulated other comprehensive income	-18
Total other comprehensive income	274	50
Balance at the end of the period	-12,978
Pension Plan
Changes in Accumulated other comprehensive (income) loss
Balance at the beginning of the period	-5,547
Other comprehensive income before reclassifications of gain (loss)	109
Amount of gain (loss) reclassified from accumulated other comprehensive income	-18
Total other comprehensive income	91
Balance at the end of the period	-5,456
Derivatives
Changes in Accumulated other comprehensive (income) loss
Balance at the beginning of the period	-7,705
Other comprehensive income before reclassifications of gain (loss)	183
Total other comprehensive income	183
Balance at the end of the period	($7,522)

Subsequent_Event_Details

Subsequent Event (Details) (USD $)	0 Months Ended
In Millions, except Per Share data, unless otherwise specified	Apr. 22, 2015	Apr. 09, 2015
	Apr. 22, 2015	item
General Partner Interest
Subsequent Events
Quarterly cash distribution declared (in dollars per unit)	$0.68
Subsequent event \| Purchase commitment \| Capitol Petroleum Group
Subsequent Events
Number of gasoline stations acquired		97
Number of dealer supply contracts		7
Total consideration		$156
Number of fee properties		18
Subsequent event \| General Partner Interest
Subsequent Events
Quarterly cash distribution declared (in dollars per unit)	$0.68
Subsequent event \| General Partner Interest \| Annualized basis
Subsequent Events
Quarterly cash distribution declared (in dollars per unit)	$2.72
Subsequent event \| Maximum \| Purchase commitment \| Capitol Petroleum Group
Subsequent Events
Period of extension for acquisition		30 days

Supplemental_Guarantor_Condens2

Supplemental Guarantor Condensed Consolidating Financial Statements (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014	Mar. 31, 2014	Dec. 31, 2013
Current assets:
Cash and cash equivalents	$6,345	$5,238	$13,064	$9,217
Accounts receivable, net	410,881	457,730
Accounts receivable-affiliates	3,845	3,903
Inventories	371,627	336,813
Brokerage margin deposits	33,737	17,198
Derivate assets	57,470	83,826
Prepaid expenses and other current assets	74,123	56,515
Total current assets	958,028	961,223
Property and equipment, net	1,174,083	825,051
Intangible assets, net	80,049	48,902
Goodwill	301,987	154,078
Other assets	54,637	50,723
Total assets	2,568,784	2,039,977
Current liabilities:
Accounts payable	307,520	456,619
Working capital revolving credit facility-current portion	125,400	0
Line of credit		700
Environmental liabilities-current portion	3,085	3,101
Trustee taxes payable	90,183	105,744
Accrued expenses and other current liabilities	60,918	82,820
Derivative liabilities	48,272	58,507
Total current liabilities	635,378	707,491
Working capital revolving credit facility-less current portion	150,000	100,000
Revolving credit facility	517,400	133,800
Senior notes	368,316	368,136
Environmental liabilities-less current portion	72,186	34,462
Deferred tax liability	120,708	14,078
Other long-term liabilities	61,811	45,854
Total liabilities	1,925,799	1,403,821
Partners' equity
Total Global Partners LP equity	593,777	586,942
Noncontrolling interest	49,208	49,214
Total partners' equity	642,985	636,156
Total liabilities and partners' equity	2,568,784	2,039,977
Eliminations
Current assets:
Cash and cash equivalents		1,082
Accounts receivable, net		820
Accounts receivable-affiliates	-1,259	-139
Total current assets	-1,259	1,763
Total assets	-1,259	1,763
Current liabilities:
Accounts payable		681
Accounts payable - affiliates	-1,259
Total current liabilities	-1,259	681
Total liabilities	-1,259	681
Partners' equity
Total Global Partners LP equity		1,082
Total partners' equity		1,082
Total liabilities and partners' equity	-1,259	1,763
(Issuer) Guarantor Subsidiaries
Current assets:
Cash and cash equivalents	2,469	1,478	8,208	8,371
Accounts receivable, net	409,579	455,603
Accounts receivable-affiliates	4,059	3,222
Inventories	371,627	336,813
Brokerage margin deposits	33,737	17,198
Derivate assets	57,470	83,826
Prepaid expenses and other current assets	73,504	55,881
Total current assets	952,445	954,021
Property and equipment, net	1,128,262	778,385
Intangible assets, net	79,772	45,870
Goodwill	215,924	68,015
Other assets	54,637	50,723
Total assets	2,431,040	1,897,014
Current liabilities:
Accounts payable	306,937	454,267
Accounts payable - affiliates	1,045
Working capital revolving credit facility-current portion	125,400
Environmental liabilities-current portion	3,085	3,101
Trustee taxes payable	90,183	105,744
Accrued expenses and other current liabilities	60,394	81,686
Derivative liabilities	48,272	58,507
Total current liabilities	635,316	703,305
Working capital revolving credit facility-less current portion	150,000	100,000
Revolving credit facility	517,400	133,800
Senior notes	368,316	368,136
Environmental liabilities-less current portion	72,186	34,462
Deferred tax liability	120,708	14,078
Other long-term liabilities	61,811	45,854
Total liabilities	1,925,737	1,399,635
Partners' equity
Total Global Partners LP equity	505,303	497,379
Total partners' equity	505,303	497,379
Total liabilities and partners' equity	2,431,040	1,897,014
Non-Guarantor Subsidiary
Current assets:
Cash and cash equivalents	3,876	2,678	4,856	846
Accounts receivable, net	1,302	1,307
Accounts receivable-affiliates	1,045	820
Prepaid expenses and other current assets	619	634
Total current assets	6,842	5,439
Property and equipment, net	45,821	46,666
Intangible assets, net	277	3,032
Goodwill	86,063	86,063
Total assets	139,003	141,200
Current liabilities:
Accounts payable	583	1,671
Accounts payable - affiliates	214
Line of credit		700
Accrued expenses and other current liabilities	524	1,134
Total current liabilities	1,321	3,505
Total liabilities	1,321	3,505
Partners' equity
Total Global Partners LP equity	88,474	88,481
Noncontrolling interest	49,208	49,214
Total partners' equity	137,682	137,695
Total liabilities and partners' equity	$139,003	$141,200

Supplemental_Guarantor_Condens3

Supplemental Guarantor Condensed Consolidating Financial Statements (Details 2) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Sales	$2,979,116	$5,116,928
Cost of sales	2,810,558	4,957,904
Gross profit	168,558	159,024
Costs and operating expenses:
Selling, general and administrative expenses	48,786	37,298
Operating expenses	68,656	47,952
Amortization expense	5,341	4,528
Loss on asset sales	437	663
Total costs and operating expenses	123,220	90,441
Operating income	45,338	68,583
Interest expense	-13,963	-11,107
Income before income tax expense	31,375	57,476
Income tax expense	-966	-322
Net income	30,409	57,154
Net (income) loss attributable to noncontrolling interest	6	-144
Net income attributable to Global Partners LP	30,415	57,010
Less: General partner's interest in net income, including incentive distribution rights	2,179	1,508
Limited partners' interest in net income	28,236	55,502
Eliminations
Sales	-4,119	-6,091
Cost of sales	-4,119	-6,091
(Issuer) Guarantor Subsidiaries
Sales	2,975,185	5,114,874
Cost of sales	2,812,472	4,962,534
Gross profit	162,713	152,340
Costs and operating expenses:
Selling, general and administrative expenses	48,026	36,543
Operating expenses	66,317	45,180
Amortization expense	2,586	1,773
Loss on asset sales	437	663
Total costs and operating expenses	117,366	84,159
Operating income	45,347	68,181
Interest expense	-13,958	-11,066
Income before income tax expense	31,389	57,115
Income tax expense	-966	-322
Net income	30,423	56,793
Net income attributable to Global Partners LP	30,423	56,793
Less: General partner's interest in net income, including incentive distribution rights	2,179	1,508
Limited partners' interest in net income	28,244	55,285
Non-Guarantor Subsidiary
Sales	8,050	8,145
Cost of sales	2,205	1,461
Gross profit	5,845	6,684
Costs and operating expenses:
Selling, general and administrative expenses	760	755
Operating expenses	2,339	2,772
Amortization expense	2,755	2,755
Total costs and operating expenses	5,854	6,282
Operating income	-9	402
Interest expense	-5	-41
Income before income tax expense	-14	361
Net income	-14	361
Net (income) loss attributable to noncontrolling interest	6	-144
Net income attributable to Global Partners LP	-8	217
Limited partners' interest in net income	($8)	$217

Supplemental_Guarantor_Condens4

Supplemental Guarantor Condensed Consolidating Financial Statements (Details 3) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Cash flows from operating activities
Net cash (used in) provided by operating activities	($113,915)	$53,146
Cash flows from investing activities
Acquisitions	-405,478
Capital expenditures	-14,045	-13,075
Proceeds from sale of property and equipment	1,044	1,746
Net cash used in investing activities	-418,479	-11,329
Cash flows from financing activities
Borrowings from (payments on) working capital revolving credit facility	175,400	-20,200
Borrowings from revolving credit facility	383,600
Payments on line of credit	-700
Repurchase of common units	-2,442
Noncontrolling interest capital contribution	1,880	2,400
Distribution to noncontrolling interest	-1,880	-2,400
Distributions to partners	-22,357	-17,770
Net cash provided by (used in) financing activities	533,501	-37,970
Cash and cash equivalents
Increase in cash and cash equivalents	1,107	3,847
Cash and cash equivalents at beginning of period	5,238	9,217
Cash and cash equivalents at end of period	6,345	13,064
Eliminations
Cash and cash equivalents
Cash and cash equivalents at beginning of period			1,082
Cash and cash equivalents at end of period			1,082
(Issuer) Guarantor Subsidiaries
Cash flows from operating activities
Net cash (used in) provided by operating activities	-117,146	48,362
Cash flows from investing activities
Acquisitions	-405,478
Capital expenditures	-12,712	-12,301
Proceeds from sale of property and equipment	1,044	1,746
Net cash used in investing activities	-417,146	-10,555
Cash flows from financing activities
Borrowings from (payments on) working capital revolving credit facility	175,400	-20,200
Borrowings from revolving credit facility	383,600
Repurchase of common units	-2,442
Noncontrolling interest capital contribution	1,880	2,400
Distribution to noncontrolling interest	-1,880	-2,400
Distributions to partners	-22,357	-17,770
Net cash provided by (used in) financing activities	534,201	-37,970
Cash and cash equivalents
Increase in cash and cash equivalents	-91	-163
Cash and cash equivalents at beginning of period	1,478	8,371
Cash and cash equivalents at end of period	2,469	8,208
Non-Guarantor Subsidiary
Cash flows from operating activities
Net cash (used in) provided by operating activities	3,231	4,784
Cash flows from investing activities
Capital expenditures	-1,333	-774
Net cash used in investing activities	-1,333	-774
Cash flows from financing activities
Payments on line of credit	-700
Net cash provided by (used in) financing activities	-700
Cash and cash equivalents
Increase in cash and cash equivalents	1,198	4,010
Cash and cash equivalents at beginning of period	2,678	846
Cash and cash equivalents at end of period	$3,876	$4,856