Global Partners (GLP) 10-Q 9 May 14 2014 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2014	6-May-14
Document and Entity Information	'	'
Entity Registrant Name	'GLOBAL PARTNERS LP	'
Entity Central Index Key	'0001323468	'
Document Type	'10-Q	'
Document Period End Date	31-Mar-14	'
Amendment Flag	'false	'
Current Fiscal Year End Date	'--12-31	'
Entity Current Reporting Status	'Yes	'
Entity Filer Category	'Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	27,430,563
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q1	'

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$13,064	$9,217
Accounts receivable, net	644,244	686,392
Accounts receivable-affiliates	1,638	1,404
Inventories	460,478	572,806
Brokerage margin deposits	15,193	21,792
Fair value of forward fixed price contracts	80,488	46,007
Prepaid expenses and other current assets	48,325	36,693
Total current assets	1,263,430	1,374,311
Property and equipment, net	799,124	803,636
Intangible assets, net	63,241	67,769
Goodwill	154,078	154,078
Other assets	26,630	28,128
Total assets	2,306,503	2,427,922
Current liabilities:	'	'
Accounts payable	599,043	781,119
Working capital revolving credit facility-current portion	175,000	'
Line of credit	3,700	3,700
Environmental liabilities-current portion	3,360	3,377
Trustee taxes payable	80,917	80,216
Accrued expenses and other current liabilities	56,963	65,963
Obligations on forward fixed price contracts	89,930	38,197
Total current liabilities	1,008,913	972,572
Working capital revolving credit facility-less current portion	131,800	327,000
Revolving credit facility	434,700	434,700
Senior notes	148,373	148,268
Environmental liabilities-less current portion	37,252	37,762
Other long-term liabilities	42,000	44,440
Total liabilities	1,803,038	1,964,742
Global Partners LP equity:	'	'
Common unitholders (27,430,563 units issued and 27,260,747 outstanding at March 31, 2014 and December 31, 2013)	466,440	426,785
General partner interest (0.83% interest with 230,303 equivalent units outstanding at March 31, 2014 and December 31, 2013)	198	-238
Accumulated other comprehensive loss	-11,260	-11,310
Total Global Partners LP equity	455,378	415,237
Noncontrolling interest	48,087	47,943
Total partners' equity	503,465	463,180
Total liabilities and partners' equity	$2,306,503	$2,427,922

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical)	Mar. 31, 2014	Dec. 31, 2013
CONSOLIDATED BALANCE SHEETS	'	'
Common unitholders, units issued	27,430,563	27,430,563
Common unitholders, units outstanding	27,260,747	27,260,747
General partner interest (as a percent)	0.83%	0.83%
General partner interest, equivalent units outstanding	230,303	230,303

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
CONSOLIDATED STATEMENTS OF OPERATIONS	'	'
Sales	$5,116,928	$5,589,190
Cost of sales	4,958,567	5,530,118
Gross profit	158,361	59,072
Costs and operating expenses:	'	'
Selling, general and administrative expenses	37,298	25,663
Operating expenses	47,952	43,340
Amortization expense	4,528	3,774
Total costs and operating expenses	89,778	72,777
Operating income (loss)	68,583	-13,705
Interest expense	-11,107	-10,486
Income (loss) before income tax (expense) benefit	57,476	-24,191
Income tax (expense) benefit	-322	1,875
Net income (loss)	57,154	-22,316
Net (income) loss attributable to noncontrolling interest	-144	249
Net income (loss) attributable to Global Partners LP	57,010	-22,067
Less: General partner's interest in net income (loss), including incentive distribution rights	-1,508	-500
Limited partners' interest in net income (loss)	$55,502	($22,567)
Basic net income (loss) per limited partner unit (in dollars per unit)	$2.04	($0.83)
Diluted net income (loss) per limited partner unit (in dollars per unit)	$2.03	($0.83)
Basic weighted average limited partner units outstanding (in units)	27,261	27,323
Diluted weighted average limited partner units outstanding (in units)	27,296	27,323

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)	'	'
Net income (loss)	$57,154	($22,316)
Other comprehensive income:	'	'
Change in fair value of cash flow hedges	659	1,473
Change in pension liability	-609	766
Total other comprehensive income	50	2,239
Comprehensive income (loss)	57,204	-20,077
Comprehensive (income) loss attributable to noncontrolling interest	-144	249
Comprehensive income (loss) attributable to Global Partners LP	$57,060	($19,828)

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Cash flows from operating activities	'	'
Net income (loss)	$57,154	($22,316)
Adjustments to reconcile net income (loss) to net provided by in operating activities:	'	'
Depreciation and amortization	19,706	16,089
Amortization of deferred financing fees	1,283	1,571
Amortization of senior notes discount	105	53
Bad debt expense	250	1,953
Stock-based compensation expense	851	104
Changes in operating assets and liabilities, exclusive of business combinations:	'	'
Accounts receivable	41,898	-145,293
Accounts receivable - affiliate	-234	-48
Inventories	112,328	206,435
Broker margin deposits	6,599	26,297
Prepaid expenses, all other current assets and other assets	-11,416	11,154
Accounts payable	-182,076	185,103
Trustee taxes payable	701	-12,499
Change in fair value of forward fixed price contracts	17,252	-671
Accrued expenses, all other current liabilities and other long-term liabilities	-11,255	14,846
Net cash provided by operating activities	53,146	282,778
Cash flows from investing activities	'	'
Acquisitions	'	-185,281
Capital expenditures	-13,075	-12,258
Proceeds from sale of property and equipment	1,746	400
Net cash used in investing activities	-11,329	-197,139
Cash flows from financing activities	'	'
Payments on working capital revolving credit facility	-20,200	-223,000
Payments on revolving credit facility	'	-22,300
Proceeds from issuance of term loan	'	115,000
Proceeds from senior notes, net of discount	'	67,900
Noncontrolling interest capital contribution	2,400	'
Distribution to noncontrolling interest	-2,400	'
Distributions to partners	-17,770	-16,278
Net cash used in financing activities	-37,970	-78,678
Increase in cash and cash equivalents	3,847	6,961
Cash and cash equivalents at beginning of period	9,217	5,977
Cash and cash equivalents at end of period	13,064	12,938
Supplemental information	'	'
Cash paid during the period for interest	$9,587	$8,176

CONSOLIDATED_STATEMENTS_OF_PAR

CONSOLIDATED STATEMENTS OF PARTNERS' EQUITY (USD $)	Total	Common Unitholders	General Partner Interest	Accumulated Other Comprehensive Loss	Noncontrolling Interest
In Thousands, unless otherwise specified
Balance at Dec. 31, 2013	$463,180	$426,785	($238)	($11,310)	$47,943
Increase (Decrease) in Partners' Capital	'	'	'	'	'
Net income	57,154	55,502	1,508	'	144
Noncontrolling interest capital contribution	2,400	'	'	'	2,400
Distribution to noncontrolling interest	-2,400	'	'	'	-2,400
Other comprehensive income	50	'	'	50	'
Stock-based compensation	851	851	'	'	'
Distributions to partners	-17,874	-16,802	-1,072	'	'
Phantom unit dividends	104	104	'	'	'
Balance at Mar. 31, 2014	$503,465	$466,440	$198	($11,260)	$48,087

Organization_and_Basis_of_Pres

Organization and Basis of Presentation	3 Months Ended
	Mar. 31, 2014
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 publicly traded Delaware master limited partnership formed in March 2005.  As of March 31, 2014, the Partnership had the following wholly owned subsidiaries:  Global Companies LLC, Glen Hes Corp., Global Montello Group Corp. (“GMG”), Chelsea Sandwich LLC, Global Energy Marketing LLC, Alliance Energy LLC, Bursaw Oil LLC, GLP Finance Corp., Global Energy Marketing II LLC, Global CNG LLC and Cascade Kelly Holdings LLC.  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 its gasoline station and convenience store employees and certain union personnel who are employed by GMG.
	The Partnership is a midstream logistics and marketing company.  The Partnership is one of the largest distributors of gasoline (including gasoline blendstocks such as ethanol and naphtha), distillates (such as home heating oil, diesel and kerosene), residual oil and renewable fuels to wholesalers, retailers and commercial customers in the New England states and New York.  The Partnership also engages in the purchasing, selling and logistics of transporting domestic and Canadian crude oil and other products via rail, establishing a “virtual pipeline” from the mid-continent region of the United States and Canada to the East and West Coasts for distribution to refiners and other customers.  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 also owns and controls transload terminals in North Dakota and Oregon that extend its origin-to- destination capabilities. The Partnership is a major multi-brand gasoline distributor and, as of March 31, 2014, had a portfolio of approximately 900 owned, leased and/or supplied gasoline stations primarily in the Northeast.  The Partnership receives revenue from retail sales of gasoline, convenience store sales and gasoline station rental income.  The Partnership is also a distributor of natural gas and propane.
	On February 1, 2013, the Partnership acquired a 60% membership interest in Basin Transload, LLC (“Basin Transload”), and on February 15, 2013, the Partnership acquired 100% of the membership interests in Cascade Kelly Holdings LLC (“Cascade Kelly”).  See Note 2.
	The General Partner, which holds a 0.83% general partner interest in the Partnership, is owned by affiliates of the Slifka family.  As of March 31, 2014, affiliates of the General Partner, including its directors and executive officers and their affiliates, owned 11,559,252 common units, representing a 42.1% limited partner interest.
	Basis of Presentation
	The financial results of Basin Transload for the two months ended March 31, 2013 and of Cascade Kelly for the one and one-half months ended March 31, 2013 are included in the accompanying statements of operations for the three months ended March 31, 2013.  The Partnership consolidates the balance sheet and statement of operations of Basin Transload because the Partnership controls the entity.  The accompanying consolidated financial statements as of March 31, 2014 and December 31, 2013 and for the three months ended March 31, 2014 and 2013 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, 2013 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, 2014 are not necessarily indicative of the results of operations that will be realized for the entire year ending December 31, 2014.  The consolidated balance sheet at December 31, 2013 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, 2013.
	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 significant fluctuations in the Partnership’s quarterly operating results.
	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 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 sheet and statement of operations.
	Concentration of Risk
	The following table presents the Partnership’s product sales and logistics revenue as a percentage of total sales for the periods presented:
		Three Months Ended
		March 31,
		2014	2013
	Gasoline sales: gasoline and gasoline blendstocks such as ethanol and naphtha	55%	53%
	Crude oil sales and logistics revenue	12%	18%
	Distillates (home heating oil, diesel and kerosene), residual oil, natural gas and propane sales	33%	29%
	Total	100%	100%
	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, and two significant customers, ExxonMobil and Phillips 66, that accounted for approximately 13% and 14%, respectively, of total sales for the three months ended March 31, 2013.

Business_Combinations

Business Combinations	3 Months Ended
	Mar. 31, 2014
Business Combinations	'
Business Combinations	'
	Note 2.                     Business Combinations
	Acquisition of Basin Transload LLC
	On February 1, 2013, the Partnership acquired a 60% membership interest in Basin Transload, which operates two transloading facilities in Columbus and Beulah, North Dakota for crude oil and other products, with a combined rail loading capacity of 160,000 barrels per day.  The purchase price, including in expenditures related to certain capital expansion projects, was approximately $91.1 million which the Partnership financed with borrowings under its credit facility.
	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 its membership interest in Basin Transload subsequent to the acquisition date.
	The 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 a valuation from the Partnership’s third-party valuation firm.  Any excess purchase price over the fair value of the net tangible and intangible assets acquired was allocated to goodwill and assigned to the Wholesale reporting unit.
	As part of the purchase price allocation, identifiable intangible assets include customer relationships that are being amortized, based on the economic use of the asset, over two years which is consistent with the contractual period of the existing customers.  Amortization expense amounted to $2.7 million and $2.0 million for the three months ended March 31, 2014 and 2013, respectively.  The following table presents the estimated remaining amortization expense for intangible assets acquired in connection with the acquisition (in thousands):
	2014 (4/1/14-12/31/14)	$	8,266
	2015	2,869
	Total	$	11,135
	Acquisition of Cascade Kelly Holdings LLC
	On February 15, 2013, the Partnership acquired 100% of the membership interests in Cascade Kelly, which owns a West Coast crude oil and ethanol facility near Portland, Oregon.  The total cash purchase price was approximately $94.2 million which the Partnership funded with borrowings under its credit facility and with proceeds from the issuance of the Partnership’s unsecured 8.00% senior notes due 2018 (see Note 6).  Cascade Kelly’s assets include a rail transloading facility serviced by the Burlington Northern Santa Fe Railway, 200,000 barrels of storage capacity, a deepwater marine terminal with access to a 1,200-foot leased dock and the largest ethanol plant on the West Coast.  Situated along the Columbia River in Clatskanie, Oregon, the site is located on land leased under a long-term agreement from the Port of St. Helens.
	The acquisition was accounted for using the purchase method of accounting in accordance with the FASB’s guidance regarding business combinations.  The Partnership’s financial statements include the results of operations of Cascade Kelly subsequent to the acquisition date.
	The 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, if any, based upon on a valuation from the Partnership’s third-party valuation firm.  No intangible assets were identified.  Any excess purchase price over the fair value of the net tangible assets acquired was allocated to goodwill and assigned to the Wholesale reporting unit.
	Supplemental Pro Forma Information
	Revenues and net income included in the Partnership’s consolidated operating results for Basin Transload from January 1, 2013 to February 1, 2013, the acquisition date, and for Cascade Kelly from January 1, 2013 to February 15, 2013, the acquisition date, were immaterial.  Accordingly, the supplemental pro forma information for the three months ended March 31, 2013 is consistent with the amounts reported in the accompanying statement of operations for the three months ended March 31, 2013.

Net_Income_Loss_Per_Limited_Pa

Net Income (Loss) Per Limited Partner Unit	3 Months Ended
	Mar. 31, 2014
Net Income (Loss) Per Limited Partner Unit	'
Net Income (Loss) Per Limited Partner Unit	'
	Note 3.                     Net Income (Loss) 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, 2014 and December 31, 2013 excluded 169,816 common units held on behalf of the Partnership pursuant to its repurchase program.  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 (loss) and the assumed allocation of net income (loss) to the limited partners’ interest for purposes of computing net income (loss) per limited partner unit for the three months ended March 31, 2014 and 2013 (in thousands, except per unit data):
		Three Months Ended March 31, 2014								Three Months Ended March 31, 2013
	Numerator:	Total		Limited		General		IDRs		Total			Limited			General			IDRs
				Partner		Partner							Partner			Partner
				Interest		Interest							Interest			Interest
	Net income (loss) attributable to Global Partners LP	$	57,010	$	55,502	$	1,508	$	—	$	(22,067	)	$	(22,567	)	$	500		$	—
	Declared distribution	$	18,323	$	17,145	$	143	$	1,035	$	16,796		$	15,979		$	134		$	683
	Assumed allocation of undistributed net income (loss)	38,687		38,357		330		—		(38,863		)	(38,546		)	(317		)	—
	Assumed allocation of net income (loss)	$	57,010	$	55,502	$	473	$	1,035	$	(22,067	)	$	(22,567	)	$	(183	)	$	683
	Denominator:
	Basic weighted average limited partner units outstanding			27,261									27,323
	Dilutive effect of phantom units			35									—
	Diluted weighted average limited partner units outstanding			27,296									27,323
	Basic net income (loss) per limited partner unit			$	2.04								$	(0.83	)
	Diluted net income (loss) per limited partner unit (1)			$	2.03								$	(0.83	)
	(1)          Basic units were used to calculate diluted net income per limited partner unit for the three months ended March 31, 2013, as using the effects of phantom units would have an anti-dilutive effect on income per limited partner unit.
	On April 23, 2014, the board of directors of the General Partner declared a quarterly cash distribution of $0.6250 per unit for the period from January 1, 2014 through March 31, 2014.  This declared cash distribution will result in an incentive distribution to the General Partner, as the holder of the IDRs, and enable the Partnership to exceed its second target level distribution with respect to such IDRs.  See Note 8, “Cash Distributions” for further information.

Inventories

Inventories	3 Months Ended
	Mar. 31, 2014
Inventories	'
Inventories	'
	Note 4.                     Inventories
	Except for its convenience store inventory and its Renewable Identification Numbers (“RINs”) inventory, the Partnership hedges substantially all of its inventory, primarily through futures contracts.  These futures contracts are entered into when inventory is purchased and are designated as fair value hedges against the inventory on a specific barrel basis.  Changes in the fair value of these contracts, as well as the offsetting gain or loss on the hedged inventory item, are recognized in earnings as an increase or decrease in cost of sales.  All hedged inventory is valued using the lower of cost, as determined by specific identification, or market.  Prior to sale, hedges are removed from specific barrels of inventory, and the then unhedged inventory is sold and accounted for on a first-in, first-out basis.  Convenience store inventory and RIN inventory are carried at the lower of historical cost or market.
	Inventories consisted of the following (in thousands):
		March 31,		December 31,
		2014		2013
	Distillates: home heating oil, diesel and kerosene	$	163,547	$	272,760
	Gasoline	100,133		96,539
	Gasoline blendstocks	93,352		54,076
	Renewable identification numbers (RINs)	2,760		3,186
	Crude oil	52,024		87,022
	Residual oil	37,116		48,793
	Propane and other	3,416		3,443
	Convenience store inventory	8,130		6,987
	Total	$	460,478	$	572,806
	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 $34.0 million and $48.2 million at March 31, 2014 and December 31, 2013, respectively.  Negative exchange balances are accounted for as accounts payable and amounted to $51.7 million and $46.7 million at March 31, 2014 and December 31, 2013, respectively.  Exchange transactions are valued using current carrying costs.

Derivative_Financial_Instrumen

Derivative Financial Instruments	3 Months Ended
	Mar. 31, 2014
Derivative Financial Instruments	'
Derivative Financial Instruments	'
	Note 5.                     Derivative Financial Instruments
	Accounting and reporting guidance for derivative instruments and hedging activities requires that an entity recognize derivatives as either assets or liabilities on the balance sheet and measure the instruments at fair value.  Changes in the fair value of the derivative are to be recognized currently in earnings, unless specific hedge accounting criteria are met.  The Partnership principally uses derivative instruments to hedge the commodity risk associated with its inventory and product purchases and sales and to hedge variable interest rates associated with the Partnership’s credit facilities.
	The following table presents the volume of activity related to the Partnership’s derivative financial instruments at March 31, 2014:
			Units (1)		Unit of Measure
	Futures Contracts
	Long		12,756		Thousands of barrels
	Short		(15,748	)	Thousands of barrels
	Natural Gas Contracts
	Long		4,537		Thousands of decatherms
	Short		(4,537	)	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)	$	16.7		Millions of Canadian dollars
		$	15.1		Millions of U.S. dollars
	(1)          Number of open positions and gross notional amounts do not quantify risk or represent assets or liabilities of the Partnership, but are used in the calculation of daily cash settlements under the contracts.
	(2)          All-in forward rate Canadian dollars (“CAD”) $1.1053 to USD $1.00.
	Fair Value Hedges
	The Partnership enters into futures contracts in the normal course of business to reduce the risk of loss of inventory value, which could result from fluctuations in market prices.  These futures contracts are designated as fair value hedges against the inventory with specific futures contracts matched to specific barrels of inventory.  As a result of the Partnership’s hedge designation on these transactions, the futures contracts are recorded on the Partnership’s consolidated balance sheet and marked to market through the use of independent markets based on the prevailing market prices of such instruments at the date of valuation.  Likewise, the underlying inventory being hedged is also marked to market.  Changes in the fair value of the futures contracts, as well as the change in the fair value of the hedged inventory, are recognized in the consolidated statement of income through cost of sales.  These futures contracts are settled on a daily basis by the Partnership through brokerage margin accounts.
	The Partnership’s futures contracts are settled daily; therefore, there was no corresponding asset or liability on the Partnership’s consolidated balance sheet related to these contracts at March 31, 2014 and December 31, 2013.  These contracts remain open until their contract end date.  The daily settlement of these futures contracts is accomplished through the use of brokerage margin deposit accounts.
	The following table presents the hedge ineffectiveness from derivatives involved in fair value hedging relationships recognized in the Partnership’s consolidated statements of operations for the three months ended March 31, 2014 and 2013 (in thousands):
					Amount of Gain (Loss)
					Recognized in Income on
					Derivatives
			Location of Gain (Loss)		Three Months Ended
	Derivatives in Fair Value		Recognized in		March 31,
	Hedging Relationships		Income on Derivatives		2014			2013
	Futures contracts		Cost of sales		$	16,373		$	(10,384	)
					Amount of Gain (Loss)
					Recognized in Income on
					Hedged Items
			Location of Gain (Loss)		Three Months Ended
	Hedged Items in Fair Value		Recognized in Income		March 31,
	Hedge Relationships		on Hedged Item		2014			2013
	Inventories		Cost of sales		$	(16,209	)	$	10,396
	Cash Flow Hedges
	The Partnership utilizes various interest rate derivative instruments to hedge variable interest rate on its debt.  These derivative instruments are designated as cash flow hedges of the underlying debt.  To the extent such hedges are effective, the changes in the fair value of the derivative instrument are reported as a component of other comprehensive income (loss) and reclassified into interest expense or interest income in the same period during which the hedged transaction affects earnings.
	In September 2008, the Partnership executed a zero premium interest rate collar with a major financial institution.  The collar, which became effective on October 2, 2008 and expired on October 2, 2013, was used to hedge the variability in cash flows in monthly interest payments made on $100.0 million of one-month LIBOR-based borrowings on the credit facility (and subsequent refinancings thereof) due to changes in the one-month LIBOR rate.
	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%.  This swap essentially replaced the interest rate collar that expired on October 2, 2013.
	The following table presents the fair value of the Partnership’s derivative instruments involved in cash flow hedging relationships and their location in the Partnership’s consolidated balance sheets at March 31, 2014 and December 31, 2013 (in thousands):
					March 31,			December 31,
	Derivatives Designated as				2014			2013
	Hedging Instruments		Balance Sheet Location		Fair Value			Fair Value
	Asset derivatives
	Interest rate cap		Other assets		$	7		$	25
	Liability derivatives
	Interest rate swaps		Other long-term liabilities		$	8,785		$	9,462
	The following table presents the amount of net gains and losses from derivatives involved in cash flow hedging relationships recognized in the Partnership’s consolidated statements of operations and partners’ equity for the three months ended March 31, 2014 and 2013 (in thousands):
									Recognized in Income
			Amount of Gain (Loss)						on Derivatives
			Recognized in Other						(Ineffectiveness Portion
			Comprehensive Income						and Amount Excluded
			on Derivatives						from Effectiveness Testing)
			Three Months Ended						Three Months Ended
	Derivatives in Cash Flow		March 31,			March 31,			March 31,			March 31,
	Hedging Relationship		2014			2013			2014			2013
	Interest rate collar		$	—		$	615		$	—		$	—
	Interest rate swaps		677			863			—			—
	Interest rate cap		(18		)	(5		)	—			—
	Total		$	659		$	1,473		$	—		$	—
	Ineffectiveness related to the interest rate swaps, collar and cap is recognized as interest expense and was immaterial for the three months ended March 31, 2014 and 2013.  There were no amounts reclassified into earnings for the three months ended March 31, 2014 and 2013 under these instruments.
Other Derivative Activity
The Partnership uses futures contracts, and occasionally swap agreements, to hedge its commodity exposure under forward fixed price purchase and sale commitments on its products.  These derivatives are not designated by the Partnership as either fair value hedges or cash flow hedges.  Rather, the forward fixed price purchase and sales commitments, which meet the definition of a derivative, are reflected in the Partnership’s consolidated balance sheet.  The related futures contracts (and swaps, if applicable) are also reflected in the Partnership’s consolidated balance sheet, thereby creating an economic hedge.  Changes in the fair value of the futures contracts (and swaps, if applicable), as well as offsetting gains or losses due to the change in the fair value of forward fixed price purchase and sale commitments, are recognized in the consolidated statement of operations 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 product purchase activities, it may experience net unbalanced positions for short periods of time as a result of variances in daily sales and transportation and delivery schedules as well as other logistical issues inherent in the business, such as weather conditions.  In connection with managing these positions, maintaining a constant presence in the marketplace, and managing the futures market outlook for future anticipated inventories, which are necessary for its business, the Partnership engages in a controlled trading program for up to an aggregate of 250,000 barrels of products at any one point in time.  Any derivatives not involved in a direct hedging activity are marked to market and recognized in the consolidated statement of operations through cost of sales.
The Partnership also markets and sells natural gas by entering into forward purchase commitments for natural gas when it enters into arrangements for the forward sale commitment of product for physical delivery to third-party users.  The Partnership reflects the fair value of forward fixed purchase and sales commitments in its consolidated balance sheet.  Changes in the fair value of the forward fixed price purchase and sale commitments are recognized in the consolidated statement of income through cost of sales.
During the three months ended March 31, 2014 and 2013, the Partnership entered into forward currency contracts to hedge certain foreign denominated (Canadian) product purchases.  These forward contracts are not designated and are reflected in the consolidated balance sheets.  Changes in the fair values of these forward currency contracts are reflected in cost of sales.
Similar to the futures contracts used by the Partnership to hedge its inventory, the Partnership uses future contracts to economically hedge forward purchase and sale contracts for which the Partnership does not take the normal purchase and sale exemption.  Additionally, these futures contracts are settled daily and, accordingly, there was no corresponding asset or liability in the Partnership’s consolidated balance sheets related to these contracts at March 31, 2014 and December 31, 2013.  These contracts remain open until their contract end date.  The daily settlement of these futures contracts is accomplished through the use of brokerage margin deposit accounts.
The following table summarizes the derivatives not designated by the Partnership as either fair value hedges or cash flow hedges and their respective fair values and location in the Partnership’s consolidated balance sheets at March 31, 2014 and December 31, 2013 (in thousands):
						March 31,			December 31,
				Balance Sheet		2014			2013
Summary of Other Derivatives		Item Pertains to		Location		Fair Value			Fair Value
Asset Derivatives
Forward purchase commitments		Gasoline and Gasoline Blendstocks		-1		$	67,354		$	14,119
		Distillates		-1		525			2,232
		Residual Oil		-1		47			34
		Crude Oil		-1		8,969			13,693
Total forward purchase commitments						76,895			30,078
Forward sales commitments		Gasoline and Gasoline Blendstocks		-1		672			1,486
		Distillates		-1		391			797
		Residual Oil		-1		—			655
		Crude Oil		-1		1,166			383
		Natural Gas		-1		1,364			12,608
Total forward sales commitments						3,593			15,929
Total fair value of forward fixed price contracts						$	80,488		$	46,007
Liability Derivatives
Forward purchase commitments		Gasoline and Gasoline Blendstocks		-2		$	1,950		$	3,625
		Distillates		-2		734			1,396
		Residual Oil		-2		—			990
		Crude Oil		-2		6,134			2,122
		Natural Gas		-2		1,353			12,485
Total forward purchase commitments						10,171			20,618
Forward sales commitments		Gasoline and Gasoline Blendstocks		-2		71,577			10,709
		Distillates		-2		452			3,809
		Residual Oil		-2		539			—
		Crude Oil		-2		7,191			3,061
Total forward sales commitments						79,759			17,579
Total obligations on forward fixed price contracts and other derivatives						89,930			38,197
Foreign currency forward contract		Foreign Denominated Sales		-3		74			16
Total liability derivatives						$	90,004		$	38,213
(1)          Fair value of forward fixed price contracts
(2)          Obligations on forward fixed price contracts
(3)          Accrued expenses and other current liabilities
The following table presents the amount of gains and losses from derivatives not involved in a fair value hedging relationship or in a hedging relationship recognized in the Partnership’s consolidated statements of operations for the three months ended March 31, 2014 and 2013 (in thousands):
				Amount of Gain (Loss)
				Recognized in Income
				on Derivatives
		Location of Gain (Loss)		Three Months Ended
Derivatives Not Designated as		Recognized in		March 31,			March 31,
Hedging Instruments		Income on Derivatives		2014			2013
Product contracts		Cost of sales		$	15,543		$	666
Foreign currency contracts		Cost of sales		(57		)	(321		)
Total				$	15,486		$	345
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 of forward purchase and sale commitments, futures contracts and swap agreements, but the Partnership has no current reason to expect any material nonperformance by any of these counterparties.  Futures 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”) and Chicago Mercantile Exchange (“CME”) derivative transactions and the right of offset exists.  Accordingly, the fair value of derivative instruments is presented on a net basis in the consolidated balance sheets.  Exposure on forward purchase and sale commitments and swap agreements is limited to the amount of the recorded fair value as of the balance sheet dates.

Debt

Debt	3 Months Ended
	Mar. 31, 2014
Debt	'
Debt	'
	Note 6.                     Debt
	Credit Agreement
	On December 16, 2013, the Partnership entered into a Second Amended and Restated Credit Agreement (the “Credit Agreement”), which increased the total commitments available under the Credit Agreement to $1.625 billion from $1.615 billion under the prior credit agreement.  The Credit Agreement will mature on April 30, 2018.
	As of March 31, 2014, 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 $625.0 million revolving credit facility to be used for acquisitions, joint ventures, capital expenditures, letters of credit and general corporate purposes.
	In addition, the Credit Agreement has an accordion feature whereby the Partnership may request on the same terms and conditions of its then existing credit agreement, provided no Event of Default (as defined in the Credit Agreement) then exists, an increase to the working capital revolving credit facility, the revolving credit facility, or both, by up to another $300.0 million, in the aggregate, for a total credit facility of up to $1.925 billion.  Any such request for an increase by the Partnership must be in a minimum amount of $5.0 million.  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 $1.625 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 $1.625 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 “Receivables Sales Agreement”).  Also pursuant to the Credit Agreement, the Loan Parties are permitted to sell or transfer any account receivable to an AR Buyer only to the extent that (i) no Default or Event of Default (as such terms are defined in the Credit Agreement) has occurred and is continuing or would exist after giving effect to any such sale or transfer; (ii) such accounts receivable are sold for cash; (iii) the cash purchase price to be paid to the selling Loan Party for each account receivable is not less than the amount of credit such Loan Party would have been able to get for such account receivable had such account receivable been included in the Borrowing Base (as defined in the Credit Agreement) or, to the extent such account receivable is not otherwise eligible to be included in the Borrowing Base, then the cash purchase price to be paid is not less than 85% of the face amount of such account receivable; (iv) such account receivable is sold pursuant to a Receivables Sales Agreement; (v) the Loan Parties have complied with the notice requirement set forth in the Credit Agreement; (vi) neither the AR Buyer nor the Administrative Agent has delivered any notice of a termination event; (vii) the aggregate amount of the accounts receivable sold to one or more AR Buyers which has not yet been collected will not exceed $75.0 million at any time; and (viii) the cash proceeds received from the applicable Loan Party in connection with such sale will be used to immediately repay any outstanding WC Loans (as defined 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 minimus.
	Borrowings under the Credit Agreement are available in U.S. Dollars and Canadian Dollars. The aggregate amount of loans made under the Credit Agreement denominated in Canadian Dollars cannot exceed $200.0 million.
	Availability under the working capital revolving credit facility is subject to a borrowing base which is redetermined from time to time and based on specific advance rates on eligible current assets.  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.
	Commencing December 16, 2013, 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).  From January 1, 2013 through December 15, 2013, borrowings under the working capital revolving credit facility bore interest at (1) the Eurodollar rate plus 2.00% to 2.50%, (2) the cost of funds rate plus 2.00% to 2.50%, or (3) the base rate plus 1.00% to 1.50%, each depending on the Utilization Amount (as defined in the prior credit agreement).
	Commencing December 16, 2013, 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).  From January 1, 2013 through December 15, 2013, borrowings under the revolving credit facility bore interest at (1) the Eurodollar rate plus 2.50% to 3.50%, (2) the cost of funds rate plus 2.50% to 3.50%, or (3) the base rate plus 1.50% to 2.50%, each depending on the Combined Total Leverage Ratio (as defined in the prior credit agreement).
	The average interest rates for the Credit Agreement were 3.6% and 4.0% for the three months ended March 31, 2014 and 2013, respectively.
	As of March 31, 2014, the Partnership had a two interest rate swaps and an interest rate cap, all 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.
	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 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 $131.8 million and $327.0 million at March 31, 2014 and December 31, 2013, respectively, representing the amounts expected to be outstanding during the entire year.  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.  At March 31, 2014 and December 31, 2013, the current portion of the working capital revolving credit facility was $175 million and $0, respectively, representing the amount the Partnership expects to pay down during the course of the year. Due to unexpected excess cash received as of  March 31, 2014, the Partnership paid down a portion of the working capital revolving credit facility that was previously classified as long term at December 31, 2013.
	As of March 31, 2014, the Partnership had total borrowings outstanding under the Credit Agreement of $741.5 million, including $434.7 million outstanding on the revolving credit facility.  In addition, the Partnership had outstanding letters of credit of $280.8 million.  Subject to borrowing base limitations, the total remaining availability for borrowings and letters of credit was $602.7 million and $479.9 million at March 31, 2014 and December 31, 2013, 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 subsidiary, Bursaw Oil LLC.  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, 2014.  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).
	8.00% Senior Notes
	On February 14, 2013, the Partnership entered into a Note Purchase Agreement (the “February Purchase Agreement”) with FS Energy and Power Fund (“FS Energy”), with respect to the issue and sale by the Partnership to FS Energy of an aggregate principal amount of $70.0 million unsecured 8.00% Senior Notes due 2018 (the “8.00% Notes”).  The 8.00% Notes were issued in a private placement exempt from registration under the Securities Act of 1933, as amended (the “Securities Act”) and have not been registered under the Securities Act or any state securities laws, and may not be offered or sold except pursuant to an exemption from the registration requirements of the Securities Act and applicable state laws.
	Closing of the offering occurred on February 14, 2013.  The 8.00% Notes were sold to FS Energy at 97% of their face amount, resulting in net proceeds to the Partnership of approximately $67.9 million.  Additionally, the Partnership separately paid fees and offering expenses.  The discount of $2.1 million at issuance will be accreted as additional interest over the expected term on the 8.00% Notes.  On February 15, 2013, the Partnership used the net proceeds from the offering, after paying fees and offering expenses, to finance a portion of its acquisition of all of the outstanding membership interests in Cascade Kelly and to pay related transaction costs.
	The 8.00% Notes were issued pursuant to an indenture dated as of February 14, 2013 (as amended or supplemented, the “February Indenture”) among the Partnership, its subsidiary guarantors and FS Energy.  The 8.00% Notes will mature on February 14, 2018.  Interest on the 8.00% Notes accrued from February 14, 2013 and is paid semi-annually on February 14 and August 14 of each year, beginning on August 14, 2013.
	The Partnership may redeem all or some of the 8.00% Notes at any time or from time to time pursuant to the terms of the February Indenture.  The 8.00% Notes are also subject to optional or mandatory exchange for HY Bonds (as such term is defined in the February Indenture) at the time and on the terms specified in the February Indenture.  The holders of the 8.00% Notes may require the Partnership to repurchase the 8.00% Notes following certain asset sales or a Change of Control (as defined in the February Indenture) at the prices and on the terms specified in the February Indenture.
	On December 20, 2013, the Partnership, its subsidiary guarantors and FS Energy entered into a Second Supplemental Indenture, which is supplemental to the February Indenture (the “Second Supplemental Indenture”).  The Second Supplemental Indenture (i) adds Global CNG LLC as a guarantor, (ii) increases the amount of Equity Interests (as defined in the February Indenture) of the Partnership or any Restricted Subsidiary (as defined in the February Indenture) of the Partnership that the Partnership and the Restricted Subsidiaries may purchase, redeem or otherwise acquire in any calendar year from $5.0 million to $10.0 million, and (iii) allows the Partnership and its Restricted Subsidiaries to incur Indebtedness (as defined in the February Indenture) represented by Capital Lease Obligations (as defined in the February Indenture), mortgage financings or purchase money obligations incurred to finance construction or improvement of property, plant or equipment, up to the greater of $60.0 million or 5.5% of the Partnership’s Consolidated Net Tangible Assets (as defined in the February Indenture).
	The 8.00% Notes are guaranteed on a senior, unsecured basis by certain of the Partnership’s wholly-owned subsidiaries.  The February Indenture contains covenants that are no more restrictive to the Partnership in the aggregate than the terms, conditions, covenants and defaults contained in its Credit Agreement and will limit the Partnership’s ability to, among other things, incur additional indebtedness, make distributions to equity owners, make certain investments, restrict distributions by its subsidiaries, create liens, enter into sale-leaseback transactions, sell assets or merge with other entities.
	7.75% Senior Notes
	On December 23, 2013, the Partnership entered into a Note Purchase Agreement (the “December Purchase Agreement”) with FS Energy and Power Fund, KARBO, L.P., Kayne Anderson Capital Income Partners (QP), L.P., Kayne Anderson Income Partners, L.P., Kayne Anderson Infrastructure Income Fund, L.P., Kayne Anderson Non-Traditional Investments, L.P., KANTI (QP), L.P. and Kayne Energy Credit Opportunities, L.P. as purchasers (the “Purchasers”), with respect to the issue and sale by the Partnership to the Purchasers of an aggregate principal amount of $80.0 million unsecured 7.75% Senior Notes due 2018 (the “7.75% Notes”).  The 7.75% Notes were issued in a private placement exempt from registration under the Securities Act and have not been registered under the Securities Act or any state securities laws, and may not be offered or sold except pursuant to an exemption from the registration requirements of the Securities Act and applicable state laws.
	Closing of the offering occurred on December 23, 2013. The 7.75% Notes were sold to the Purchasers at their face amount, resulting in proceeds to the Partnership of $80.0 million.  Additionally, the Partnership separately paid fees and offering expenses.  The Partnership used a portion of the net proceeds from the offering to pay outstanding indebtedness and for general partnership purposes.
	The 7.75% Notes were issued pursuant to an indenture dated as of December 23, 2013 (the “December Indenture”) among the Partnership, its subsidiary guarantors and the Purchasers.  The 7.75% Notes will mature on December 23, 2018.  Interest on the 7.75% Notes accrued from December 23, 2013.  Interest will be paid on the 7.75% Notes semi-annually on December 23 and June 23 of each year, beginning on June 23, 2014.
	The Partnership may redeem all or some of the 7.75% Notes at any time or from time to time pursuant to the terms of the December Indenture.  The 7.75% Notes are also subject to optional or mandatory exchange for HY Bonds (as such term is defined in the December Indenture) at the time and on the terms specified in the December Indenture.  The holders of the 7.75% Notes may require the Partnership to repurchase the 7.75% Notes following certain asset sales or a Change of Control (as defined in the December Indenture) at the prices and on the terms specified in the December Indenture.
	The 7.75% Notes are guaranteed on a senior, unsecured basis by certain of the Partnership’s wholly-owned subsidiaries.  The December Indenture contains covenants that are no more restrictive to the Partnership in the aggregate than the terms, conditions, covenants and defaults contained in its Credit Agreement and will limit the Partnership’s ability to, among other things, incur additional indebtedness, make distributions to equity owners, make certain investments, restrict distributions by its subsidiaries, create liens, enter into sale-leaseback transactions, sell assets or merge with other entities.
	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, 2014 and had an outstanding balance of $3.7 million at March 31, 2014 and December 31, 2013.  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, 2014.  Amortization expenses of approximately $1.3 million and $1.6 million for the three months ended March 31, 2014 and 2013, respectively, are included in interest expense in the accompanying consolidated statements of operations.  Unamortized fees are included in other current assets and other long-term assets.

Related_Party_Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2014
Related Party Transactions	'
Related Party Transactions	'
	Note 7.                     Related Party Transactions
	The Partnership is a party to a Second Amended and Restated Terminal Storage Rental and Throughput Agreement, as amended, with Global Petroleum Corp. (“GPC”), an affiliate of the Partnership that is 100% owned by members of the Slifka family.  The agreement, which extends through July 31, 2015 with annual renewal options thereafter, is accounted for as an operating lease.  After July 31, 2015, the agreement continues for successive one year terms unless either party gives notice to terminate at least 90 days prior to the expiration of the then current term.  The expenses under this agreement totaled approximately $2.3 million for each of the three months ended March 31, 2014 and 2013.
	Pursuant to an Amended and Restated Services Agreement with GPC, GPC provides certain terminal operating management services to the Partnership and uses certain administrative, accounting and information processing services of the Partnership.  The expenses from these services totaled approximately $24,000 for each of the three months ended March 31, 2014 and 2013.  These charges were recorded in selling, general and administrative expenses in the accompanying consolidated statements of operations.  On March 9, 2012, in connection with the Partnership’s acquisition of Alliance Energy LLC (“Alliance”), the agreement was amended to include the services provided by GPC to Alliance.  The agreement is for an indefinite term, and either party may terminate its receipt of some or all of the services thereunder upon 180 days’ notice at any time.  As of March 31, 2014, no such notice of termination was given by either party.
	In addition, on March 9, 2012, following the closing of the acquisition of Alliance, Global Companies and AE Holdings LLC (“AE Holdings”) entered into a shared services agreement pursuant to which Global Companies provides AE Holdings with certain tax, accounting, treasury and legal support services for which AE Holdings pays Global Companies $15,000 per year.  The shared services agreement is for an indefinite term and AE Holdings may terminate its receipt of some or all of the services upon 180 days’ notice.  As of March 31, 2014, no such notice of termination was given by AE Holdings.
	The General Partner employs all of the Partnership’s employees, except for its gasoline station and convenience store employees and certain union personnel, who are employed by GMG.  The Partnership reimburses the General Partner for expenses incurred in connection with these employees.  These expenses, including payroll, payroll taxes and bonus accruals, were $22.1 million and $13.8 million for the three months ended March 31, 2014 and 2013, 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,
		2014		2013
	Receivables from GPC	$	438	$	436
	Receivables from the General Partner (1)	1,200		968
	Total	$	1,638	$	1,404
	(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, 2014

Cash Distributions

'

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: 99.17% to the common unitholders, pro rata, and 0.83% 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

Minimum Quarterly Distribution

$0.46

99.17%

0.83%

First Target Distribution

$0.46

99.17%

0.83%

Second Target Distribution

above $0.4625 up to $0.5375

86.17%

13.83%

Third Target Distribution

above $0.5375 up to $0.6625

76.17%

23.83%

Thereafter

above $0.6625

51.17%

48.83%

The Partnership paid the following cash distribution during 2014 (in thousands, except per unit data):

Cash

Per Unit

Common

General

Incentive

Total Cash

Distribution

Cash

Units

Partner

Distribution

Distribution

Payment Date

Distribution

02/14/14 (1)

$

0.6125

$

16,802

$

140

$

932

$

17,874

(1)          This distribution of $0.6125 per unit resulted in the Partnership exceeding its second target level distribution for the fourth quarter of 2013.  As a result, the General Partner, as the holder of the IDRs, received an incentive distribution.

In addition, on April 23, 2014, the board of directors of the General Partner declared a quarterly cash distribution of $0.6250 per unit ($2.50 per unit on an annualized basis) for the period from January 1, 2014 through March 31, 2014.  On May 15, 2014, the Partnership will pay this cash distribution to its common unitholders of record as of the close of business May 6, 2014.  This distribution will result in the Partnership exceeding its second target level distribution for the quarter ended March 31, 2014.

Segment_Reporting

Segment Reporting	3 Months Ended
	Mar. 31, 2014
Segment Reporting	'
Segment Reporting	'
	Note 9.                     Segment Reporting
	The Partnership engages in the distribution of refined petroleum products, renewable fuels, crude oil natural gas and propane.  The Partnership also engages in the purchasing, selling and logistics of transporting domestic and Canadian crude oil and other products.  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, Gasoline Distribution and Station Operations (“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, 2014 and 2013, 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, 2013.
	In the Wholesale reporting segment, the Partnership sells unbranded gasoline (including gasoline blendstocks such as ethanol and naphtha) and diesel to unbranded gasoline customers and other resellers of transportation fuels.  The Partnership sells home heating oil, diesel, kerosene, residual oil and propane to home heating oil and propane retailers and wholesale distributors.  The Partnership also sells and transports crude oil to refiners.  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.  Crude oil is aggregated by truck or pipeline in the mid-continent, transported on land by train and shipped to refineries on the East Coast and West Coast in barges.  Additionally, ethanol is shipped primarily by rail and by barge.  The results of Basin Transload and Cascade Kelly, both acquired in February 2013 (see Note 2), are included in the Wholesale segment.
	In the GDSO reporting segment, the Partnership sells branded and unbranded gasoline to gasoline stations and other sub-jobbers.  This segment also includes gasoline, convenience store, car wash and other ancillary sales at the Partnership’s directly operated stores, as well as rental income from dealer leased or commission agent leased gasoline stations.
	The Commercial segment includes sales and deliveries to end user customers in the public sector and to large commercial and industrial end users of unbranded gasoline, home heating oil, diesel, kerosene, residual oil, renewable fuels and natural gas.  In the case of commercial and industrial end user customers, the Partnership sells products primarily either through a competitive bidding process or through contracts of various terms.  The Commercial segment also includes sales of custom blended fuels delivered by barges or from a terminal dock to ships through bunkering activity.
	Commercial segment end user customers include federal and state agencies, municipalities, large industrial companies, many autonomous authorities such as transportation authorities and water resource authorities, colleges and universities and a group of small utilities.  In the Commercial segment, the Partnership generally arranges the delivery of the product to the customer’s designated location.  The Partnership typically hires third-party common carriers to deliver the product.
	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.  There were no intersegment sales for any of the years presented below.
	Summarized financial information for the Partnership’s reportable segments is presented in the table below (in thousands):
		Three Months Ended
		March 31,
		2014			2013
	Wholesale Segment (1):
	Sales
	Gasoline and gasoline blendstocks	$	1,994,556		$	2,201,469
	Crude oil (2)	591,229			983,965
	Other oils and related products (3)	1,412,771			1,332,554
	Total	$	3,998,556		$	4,517,988
	Product margin
	Gasoline and gasoline blendstocks (4)	$	49,663		$	(29,426	)
	Crude oil (2)	23,490			26,168
	Other oils and related products (3)	34,616			17,658
	Total (4)	$	107,769		$	14,400
	Gasoline Distribution and Station Operations Segment:
	Sales
	Gasoline	$	768,904		$	745,590
	Station operations (5)	33,972			31,608
	Total	$	802,876		$	777,198
	Product margin
	Gasoline	$	33,280		$	28,193
	Station operations (5)	19,134			17,836
	Total	$	52,414		$	46,029
	Commercial Segment:
	Sales	$	315,496		$	294,004
	Product margin	$	12,329		$	10,425
	Combined sales and product margin:
	Sales	$	5,116,928		$	5,589,190
	Product margin (4)(6)	$	172,512		$	70,854
	Depreciation allocated to cost of sales	(14,151		)	(11,782		)
	Combined gross profit (4)	$	158,361		$	59,072
	(1)         Segment reporting results for the prior period have been reclassified to conform to the Partnership’s current presentation.
	(2)         Crude oil consists of the Partnership’s crude oil sales and revenue from its logistics activities and includes the February 2013 acquisitions of Basin Transload and Cascade Kelly.  As the Basin Transload and Cascade Kelly assets were not in place for a portion of the quarter ended March 31, 2013, the above results are not directly comparable for periods prior to February 2013.
	(3)         Other oils and related products primarily consist of distillates, residual oil and propane.
	(4)         As of March 31, 2014, the mark to market loss related to RIN forward commitments was $0.1 million and the mark to market value of a Renewable Volume Obligation (“RVO”) deficiency was $3.9 million.  As of March 31, 2013, the mark to market loss related to RIN forward commitments was $32.7 million and the mark to market value of a RVO deficiency was $2.6 million.
	(5)         Station operations primarily consist of convenience store sales at the Partnership’s directly operated stores and rental income from dealer leased or commission agent leased gasoline stations.
	(6)         Product margin is a non-GAAP financial measure used by management and external users of the Partnership’s consolidated financial statements to assess the Partnership’s 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,
		2014			2013
	Combined gross profit (1)	$	158,361		$	59,072
	Operating costs and expenses not allocated to operating segments:
	Selling, general and administrative expenses	37,298			25,663
	Operating expenses	47,952			43,340
	Amortization expense	4,528			3,774
	Total operating costs and expenses	89,778			72,777
	Operating income (loss)	68,583			(13,705		)
	Interest expense	(11,107		)	(10,486		)
	Income tax (expense) benefit	(322		)	1,875
	Net income (loss) (1)	57,154			(22,316		)
	Net (income) loss attributable to noncontrolling interest	(144		)	249
	Net income (loss) attributable to Global Partners LP (1)	$	57,010		$	(22,067	)
	(1)          As of March 31, 2014, the mark to market loss related to RIN forward commitments was $0.1 million and the mark to market value of a RVO deficiency was $3.9 million.  As of March 31, 2013, the mark to market loss related to RIN forward commitments was $32.7 million and the mark to market value of a RVO deficiency was $2.6 million.
The Partnership’s foreign sales were immaterial for the three months ended March 31, 2014 and 2013.  The Partnership has no foreign assets.
Segment Assets
In connection with its acquisitions of Cascade Kelly and a 60% membership interest in Basin Transload in February 2013, the Partnership acquired assets, including goodwill, of approximately $240.5 million, of which approximately $90.0 million of property and equipment has primarily been allocated to the Wholesale segment as of the respective acquisition dates.  The Partnership acquired retail gasoline stations from Alliance in March 2012 and ExxonMobil in September 2010 which have been allocated to the GDSO segment.
Due to the commingled nature and uses of the remainder of the Partnership’s assets, it is not reasonably possible for the Partnership to allocate these assets among its reportable segments.
The table below presents total assets by reportable segment at March 31, 2014 and December 31, 2013 (in thousands):
	Wholesale			Commercial			GDSO		Unallocated (1)		Total
March 31, 2014	$	79,589		$	—		$	496,310	$	1,730,604	$	2,306,503
December 31, 3013	$	83,208		$	—		$	499,966	$	1,844,748	$	2,427,922
(1)          Includes 40% owned by the noncontrolling interest at Basin Transload.

Property_and_Equipment

Property and Equipment	3 Months Ended
	Mar. 31, 2014
Property and Equipment	'
Property and Equipment	'
	Note 10.              Property and Equipment
	Property and equipment consisted of the following (in thousands):
		March 31			December 31,
		2014			2013
	Buildings and improvements	$	601,727		$	601,900
	Land	285,971			287,044
	Fixtures and equipment	20,961			19,890
	Construction in process	67,206			59,277
	Capitalized internal use software	5,847			5,847
	Total property and equipment	981,712			973,958
	Less accumulated depreciation	(182,588		)	(170,322		)
	Total	$	799,124		$	803,636
	At March 31, 2014, construction in process includes $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 by 2016; therefore, as of March 31, 2014, the fair value of the ethanol plant is included in construction in process.  After the plant has been successfully placed into service, depreciation will commence.

Environmental_Liabilities_Asse

Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers (RINs)	3 Months Ended
	Mar. 31, 2014
Environmental Liabilities, Asset Retirement Obligations 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 December 2012 acquisition of six New England gasoline stations from Mutual Oil, the Partnership assumed certain environmental liabilities, including certain ongoing remediation efforts.  As a result, the Partnership 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 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 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 recorded, on an undiscounted basis, total environmental liabilities of approximately $30.0 million.
	In connection with the June 2010 acquisition of three refined petroleum products terminals in Newburgh, New York, the Partnership assumed certain environmental liabilities, including certain ongoing remediation efforts.  As a result, the Partnership 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 recorded, on an undiscounted basis, total environmental liabilities of approximately $1.2 million.
	In connection with the May 2007 acquisition of ExxonMobil’s Albany and Newburgh, New York and Burlington, Vermont terminals, the Partnership assumed certain environmental liabilities, including the remediation obligations under a proposed remedial action plan submitted by ExxonMobil to NYDEC with respect to the Albany, New York terminal.  As a result, the Partnership recorded, on an undiscounted basis, total environmental liabilities of approximately $8.0 million.
	The following table presents a summary roll forward of the Partnership’s environmental liabilities at March 31, 2014 (in thousands):
		Balance at											Balance at
		December 31,		Payments in			Dispositions			Other			March 31,
	Environmental Liability Related to:	2013		2014			2014			Adjustments			2014
	ExxonMobil Gasoline Stations	$	24,745	$	(148	)	$	(159	)	$	(206	)	$	24,232
	Alliance Gasoline Stations	13,921		(44		)	—			48			13,925
	Mutual Oil	625		—			—			—			625
	Newburgh	1,500		—			—			—			1,500
	Glenwood Landing and Inwood	301		(16		)	—			—			285
	Albany	47		(2		)	—			—			45
	Total environmental liabilities	$	41,139	$	(210	)	$	(159	)	$	(158	)	$	40,612
	Current portion	$	3,377										$	3,360
	Long-term portion	37,762											37,252
	Total environmental liabilities	$	41,139										$	40,612
	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.  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.  At March 31, 2014 and December 31, 2013, the Partnership recorded approximately $2.1 million in total asset retirement obligations which are included in other long-term liabilities in the accompanying balance sheets.
	Renewable Identification Numbers (RINs)
	A Renewable Identification Number (“RIN”) is a serial number assigned to a batch of biofuel for the purpose of tracking its production, use, and trading as required by the Environmental Protection Agency’s (“EPA”) Renewable Fuel Standard that originated with the Energy Policy Act of 2005.  To evidence that the required volume of renewable fuel is blended with gasoline, obligated parties must retire sufficient RINs to cover their Renewable Volume Obligation (“RVO”).  The Partnership’s EPA obligations relative to renewable fuel reporting are largely limited to the foreign gasoline that the Partnership may choose to import.  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 a RVO is a calendar year, the settlement of the RVO can occur, under certain deferral elections, 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 the Partnership does not have a sufficient number of RINs to satisfy the obligation 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 $3.9 million and $13.1 million at March 31, 2014 and December 31, 2013, respectively.
	The Partnership may enter into RIN forward purchase and sales commitments.  These contracts are valued at the end of each quarter based on the then RIN spot rate.  The Partnership accrued for losses of these firm non-cancellable commitments of approximately $0.1 million and $6.2 million at March 31, 2014 and December 31, 2013, respectively.

LongTerm_Incentive_Plan

Long-Term Incentive Plan	3 Months Ended
	Mar. 31, 2014
Long-Term Incentive Plan	'
Long-Term Incentive Plan	'
	Note 12.              Long-Term Incentive Plan
	The General Partner has a Long-Term Incentive Plan (“LTIP”) whereby 564,242 common units were initially authorized for issuance.  On June 22, 2012, the Partnership’s common unitholders approved an amendment and restatement of the LTIP (the “Restated LTIP”).  The Restated LTIP: (i) increases the number of common units available for delivery with respect to awards under the LTIP so that, effective June 22, 2012 a total of 4,300,000 common units are available for delivery with respect to awards under the Restated LTIP, (ii) adds a prohibition on repricing of unit options and unit appreciation rights without approval of the Partnership’s unitholders, except in the case of adjustments implemented to reflect certain Partnership transactions, (iii) adds a prohibition on granting unit options or unit appreciation rights with an exercise price less than the fair market value of a common unit on the grant date (other than “substitute awards” granted in substitution for similar awards held by individuals who become employees, consultants and directors of the Partnership or one of its affiliates as a result of a merger, consolidation or acquisition by the Partnership or its affiliate of another entity or the assets of another entity), (iv) permits the granting of fully-vested common units and (v) incorporates certain other non-material ministerial changes.  Any units delivered pursuant to an award under the Restated LTIP may be acquired in the open market, issued by the Partnership, or any combination of the foregoing.  The Restated 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 Restated LTIP allows for the award of options, unit appreciation rights, restricted units, phantom units, distribution equivalent rights, unit awards and substitute awards.
	Phantom Unit Awards
	On June 27, 2013, the Compensation Committee of the board of directors of the General Partner granted a total of 498,112 phantom units under the Restated 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.  The Partnership currently intends and reasonably expects to issue and deliver the common units upon vesting.
	The awards granted to employees, with one exception, will vest on a cumulative basis as follows, subject to continued employment: 331/3% on July 1, 2017, 662/3% on July 1, 2018 and 100% on July 1, 2019.  The phantom unit award to one employee will vest on a cumulative basis as follows, subject to continued employment: 331/3% on December 31, 2014, 662/3% on December 31, 2015 and 100% on December 31, 2016.  The awards granted to the non-employee directors will vest on a cumulative basis as follows: 331/3% on December 31, 2014, 662/3% on December 31, 2015 and 100% on December 31, 2016.
	Accounting guidance for share-based compensation requires that a non-vested equity share unit awarded to an employee is to be measured at its fair value as if it were vested and issued on the grant date.  The fair value of the award at the June 27, 2013 grant date approximated the fair value of the Partnership’s common unit at that date.
	Compensation cost for an award of share-based employee compensation classified as equity, as is the case of the Partnership’s award, is recognized over the requisite service period.  The requisite service period for the Partnership is from June 27, 2013, the grant date, through the vesting dates described above.  The Partnership will recognize as compensation expense for the awards granted to employees and non-employee directors the value of the portion of the award that is ultimately expected to vest over the requisite service period on a straight-line basis.  In accordance with the guidance issued for share-based compensation, the Partnership estimated forfeitures at the time of grant.  Such estimates, which were based on the Partnership’s service history, will be revised, if necessary, in subsequent periods if actual forfeitures differ from estimates.  The Partnership recorded compensation expense related to these awards of approximately $0.8 million for the three months ended March 31, 2014, 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, 2014 was approximately $17.0 million and is expected to be recognized ratably over the remaining requisite service period.
	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 742,427 of its common units in the aggregate over an extended period of time, consistent with the General Partner’s Obligations.  Common units of the Partnership may be repurchased from time to time in open market transactions, including block purchases, or in privately negotiated transactions.  Such authorized unit repurchases may be modified, suspended or terminated at any time, and are subject to price, economic and market conditions, applicable legal requirements and available liquidity.  Since the Repurchase Program was implemented, the General Partner repurchased 495,415 common units pursuant to the Repurchase Program for approximately $12.2 million, of which approximately $0 was purchased in 2014.
	Common units outstanding as reported in the accompanying consolidated financial statements at March 31, 2014 and December 31, 2013 excluded 169,816 common units 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
	Mar. 31, 2014
Fair Value Measurements	'
Fair Value Measurements	'
	Note 13.              Fair Value Measurements
	Certain of the Partnership’s assets and liabilities are measured at fair value.  Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date.
	The FASB established a fair value hierarchy, which prioritizes the inputs used in measuring fair value into the following three levels:
	Level 1	—	Observable inputs such as quoted prices in active markets for identical assets or liabilities.
	Level 2	—	Inputs other than the quoted prices in active markets that are observable for assets or liabilities, either directly or indirectly. These include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in inactive markets.
	Level 3	—	Unobservable inputs based on the entity’s own assumptions.
	The following table presents those financial assets and financial liabilities measured at fair value on a recurring basis as of March 31, 2014 and December 31, 2013 (in thousands):
			Fair Value as of March 31, 2014												Fair Value as of December 31, 2013
			Total			Level 1			Level 2			Level 3			Total			Level 1			Level 2			Level 3
	Assets:
	Hedged inventories		$	248,918		$	—		$	248,918		$	—		$	452,302		$	—		$	452,302		$	—
	Fair value of forward fixed price contracts		80,488			—			70,353			10,135			46,007			—			31,931			14,076
	Swap agreements and options		58			10			48			—			116			74			42			—
	Interest rate cap		7			—			7			—			25			—			25			—
	Broker margin deposits		15,193			15,193			—			—			21,792			21,792			—			—
	Pension plan		17,666			17,666			—			—			18,267			18,267			—			—
	Total		$	362,330		$	32,869		$	319,326		$	10,135		$	538,509		$	40,133		$	484,300		$	14,076
	Liabilities:
	Obligations on forward fixed price contracts		$	(89,930	)	$	—		$	(76,605	)	$	(13,325	)	$	(38,197	)	$	—		$	(33,014	)	$	(5,183	)
	Mark to market loss related to RIN forward commitments		(122		)	—			(122		)	—			(6,166		)	—			(6,166		)	—
	Swap agreements and option contracts		(10		)	(10		)	—			—			(108		)	(74		)	(34		)	—
	Foreign currency derivatives		(74		)	—			(74		)	—			(16		)	—			(16		)	—
	Interest rate swaps		(8,785		)	—			(8,785		)	—			(9,462		)	—			(9,462		)	—
	Total liabilities		$	(98,921	)	$	(10	)	$	(85,586	)	$	(13,325	)	$	(53,949	)	$	(74	)	$	(48,692	)	$	(5,183	)
	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 facilities approximate fair value due to the variable rate nature of these financial instruments.  The fair values of the derivatives used by the Partnership are disclosed in Note 5.
	The majority of the Partnership’s derivatives outstanding are reported at fair value based market quotes that are deemed to be observable inputs in an active market for similar assets and liabilities and are considered Level 2 inputs for purposes of fair value disclosures.  Specifically, the fair values of the Partnership’s financial assets and financial liabilities provided above were derived from NYMEX and New York Harbor quotes for the Partnership’s hedged inventories, forward fixed price contracts, swap agreements and option contracts and from the LIBOR rates for the Partnership’s interest rate swaps and interest rate cap.  The fair value of the foreign currency derivatives and the mark to market loss related to RIN forward commitments are based on broker price quotations.  Except as discussed below, the Partnership has not changed its valuation techniques or Level 2 inputs during the three months ended March 31, 2014.
	The fair value for the Partnership’s forward fixed price contracts related to crude oil are derived from a combination of quoted NYMEX market commodity prices as well as significant unobservable inputs (Level 3), including internally developed assumptions where there is little, if any, market activity.  The unobservable inputs used in the measurement of the Partnership’s forward fixed price contracts include estimates for location basis, transportation and throughput costs net of an estimated margin for current market participants.  Gains and losses recognized in earnings (or changes in net assets) are disclosed in Note 5.
	The following table presents a summary of the changes in fair value of the Partnership’s Level 3 financial assets and liabilities at March 31, 2014:
	Fair value at December 31, 2013		$	8,894
	Change in fair value recorded in Cost of Sales		(12,084		)
	Fair value at March 31, 2014		$	(3,190	)
	The fair values of the Partnership’s pension plan assets at March 31, 2014 and December 31, 2013 were determined by Level 1 inputs which principally consist of quoted prices in active markets for identical assets.  The plan assets primarily consisted of fixed income securities, equity securities and cash and cash equivalents.
	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.
	Financial Instruments
	The fair value of the Partnership’s financial instruments approximated the carrying value as of March 31, 2014 and December 31, 2013, in each case due to the short-term nature and the variable interest rate of the financial instruments.

Income_Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2014
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 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
	Mar. 31, 2014
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 December 30, 2013, the Oregon Department of Environmental Quality (“ODEQ”) unilaterally modified (the “Modification”) an air emissions permit held by the Partnership’s subsidiary, Cascade Kelly Holdings LLC, which covers both the production of ethanol and transshipping of crude oil by the Partnership’s bio-refinery in Clatskanie, Oregon (the “Existing 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 contesting the Modification, which allows the Existing Permit to remain in effect pending such appeal.  In addition, the Partnership received a Pre- Enforcement Notice (“PEN”) letter dated January 10, 2014 from ODEQ claiming that the Partnership is in violation of the Existing Permit and informing it that ODEQ is considering a possible notice of violation and penalty assessment.  In summary, the PEN asserts that the Partnership may have received, and be receiving, more crude oil than the Existing Permit allows.  On March 27, 2014, ODEQ issued the Partnership a civil penalty assessment (“CPA”) of $117,292.  The Partnership believes that it has meritorious defenses to the Modification, the PEN and the CPA and will vigorously contest any actions that may be taken by ODEQ with respect to the foregoing.
	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”).  The Partnership is working through the customary permitting process with ODEQ.  The draft of the New Permit is currently out for public notice and comment.  The Partnership anticipates that the New Permit will be issued in the second quarter of 2014.  The Partnership believes that the issuance of the New Permit will resolve ODEQ’s concerns regarding the Existing Permit as noted above.  It is possible, however, that the issuance of the New Permit may be delayed and that a significant delay may have a negative impact on the Partnership’s operations in Oregon.
	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 are 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.  The Partnership has submitted all required information requested under the Requests for Information.  The Partnership does not believe that a material violation has occurred nor does the Partnership believe any adverse determination in connection with such investigation would have a material impact on its operations.

Changes_in_Accumulated_Other_C

Changes in Accumulated Other Comprehensive (Income) Loss	3 Months Ended
	Mar. 31, 2014
Changes in Accumulated Other Comprehensive (Income) Loss	'
Changes in Accumulated Other Comprehensive (Income) Loss	'
	Note 16.              Changes in Accumulated Other Comprehensive (Income) Loss
	The following table presents the changes in accumulated other comprehensive (income) loss by component for the three months ended March 31, 2014 (in thousands):
		Pension			Derivatives			Total
		Plan
	Balance at December 31, 2013	$	(454	)	$	(10,856	)	$	(11,310	)
	Other comprehensive (loss) income before reclassifications of gain (loss)	(481		)	659			178
	Amount of gain (loss) reclassified from accumulated other comprehensive income	(128		)	—			(128		)
	Total comprehensive (loss) income	(609		)	659			50
	Balance at March 31, 2014	$	(1,063	)	$	(10,197	)	$	(11,260	)
	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
	Mar. 31, 2014
New Accounting Standards	'
New Accounting Standards	'
	Note 17.              New Accounting Standards
	Accounting Standards or Updates Recently Adopted
	In July 2013, the FASB issued Accounting Standards Update (“ASU”) No. 2013-11, “Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exist.”  ASU 2013-11 amends the presentation requirements of ASC 740, “Income Taxes,” and requires an unrecognized tax benefit to be presented in the financial statements as a reduction to a deferred tax asset for a net operating loss carryforward, similar tax loss, or a tax credit carryforward.  To the extent the tax benefit is not available at the reporting date under the governing tax law or if the entity does not intend to use the deferred tax asset for such purpose, the unrecognized tax benefit should be presented as a liability and not combined with deferred tax assets.  The amendments are to be applied to all unrecognized tax benefits that exist as of the effective date and may be applied retrospectively to each prior reporting period presented.  The Partnership adopted this guidance on January 1, 2014 which did not have a material impact on the Partnership’s financial position, results of operations or cash flows as the Partnership’s current practice is consistent with this standard.
	Accounting Standards or Updates Not Yet Effective
	The Partnership has evaluated the accounting guidance recently issued and has determined that there are no other standards or updates that will not have a material impact on its financial position, results of operations or cash flows.

Subsequent_Event

Subsequent Event	3 Months Ended
	Mar. 31, 2014
Subsequent Event	'
Subsequent Event	'
	Note 18.              Subsequent Event
	On April 23, 2014, the board of directors of the General Partner declared a quarterly cash distribution of $0.6250 per unit ($2.50 per unit on an annualized basis) for the period from January 1, 2014 through March 31, 2014.  On May 15, 2014, the Partnership will pay this cash distribution to its common unitholders of record as of the close of business May 6, 2014.

Organization_and_Basis_of_Pres1

Organization and Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 2014
Organization and Basis of Presentation	'
Basis of Presentation	'
	Basis of Presentation
	The financial results of Basin Transload for the two months ended March 31, 2013 and of Cascade Kelly for the one and one-half months ended March 31, 2013 are included in the accompanying statements of operations for the three months ended March 31, 2013.  The Partnership consolidates the balance sheet and statement of operations of Basin Transload because the Partnership controls the entity.  The accompanying consolidated financial statements as of March 31, 2014 and December 31, 2013 and for the three months ended March 31, 2014 and 2013 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, 2013 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, 2014 are not necessarily indicative of the results of operations that will be realized for the entire year ending December 31, 2014.  The consolidated balance sheet at December 31, 2013 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, 2013.
	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 significant fluctuations in the Partnership’s quarterly operating results.
Noncontrolling Interest	'
	Noncontrolling Interest
	These financial statements reflect the application of ASC 810, “Consolidations” (“ASC 810”) which establishes accounting and reporting standards that require: (i) the ownership interest in subsidiaries held by parties other than the parent to be clearly identified and presented in the consolidated balance sheet within shareholder’s equity, but separate from the parent’s equity; (ii) the amount of consolidated net income attributable to the parent and the noncontrolling interest to be clearly identified and presented on the face of the consolidated 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 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 sheet and statement of operations.
Concentration of Risk	'
	Concentration of Risk
	The following table presents the Partnership’s product sales and logistics revenue as a percentage of total sales for the periods presented:
		Three Months Ended
		March 31,
		2014	2013
	Gasoline sales: gasoline and gasoline blendstocks such as ethanol and naphtha	55%	53%
	Crude oil sales and logistics revenue	12%	18%
	Distillates (home heating oil, diesel and kerosene), residual oil, natural gas and propane sales	33%	29%
	Total	100%	100%
	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, and two significant customers, ExxonMobil and Phillips 66, that accounted for approximately 13% and 14%, respectively, of total sales for the three months ended March 31, 2013.

Organization_and_Basis_of_Pres2

Organization and Basis of Presentation (Tables)	3 Months Ended
	Mar. 31, 2014
Organization and Basis of Presentation	'
Schedule of product sales and logistics revenue as a percentage of total sales	'
		Three Months Ended
		March 31,
		2014	2013
	Gasoline sales: gasoline and gasoline blendstocks such as ethanol and naphtha	55%	53%
	Crude oil sales and logistics revenue	12%	18%
	Distillates (home heating oil, diesel and kerosene), residual oil, natural gas and propane sales	33%	29%
	Total	100%	100%

Business_Combinations_Tables

Business Combinations (Tables) (Basin Transload)	3 Months Ended
	Mar. 31, 2014
Basin Transload	'
Acquisitions	'
Schedule of estimated remaining amortization expense for intangible assets acquired in connection with the acquisition	'
	The following table presents the estimated remaining amortization expense for intangible assets acquired in connection with the acquisition (in thousands):
	2014 (4/1/14-12/31/14)	$	8,266
	2015	2,869
	Total	$	11,135

Net_Income_Loss_Per_Limited_Pa1

Net Income (Loss) Per Limited Partner Unit (Tables)	3 Months Ended
	Mar. 31, 2014
Net Income (Loss) Per Limited Partner Unit	'
Schedule of reconciliation of net income (loss) and the assumed allocation of net income (loss) to the limited partners' interest for purposes of computing net income (loss) per limited partner unit	'
	The following table provides a reconciliation of net income (loss) and the assumed allocation of net income (loss) to the limited partners’ interest for purposes of computing net income (loss) per limited partner unit for the three months ended March 31, 2014 and 2013 (in thousands, except per unit data):
		Three Months Ended March 31, 2014								Three Months Ended March 31, 2013
	Numerator:	Total		Limited		General		IDRs		Total			Limited			General			IDRs
				Partner		Partner							Partner			Partner
				Interest		Interest							Interest			Interest
	Net income (loss) attributable to Global Partners LP	$	57,010	$	55,502	$	1,508	$	—	$	(22,067	)	$	(22,567	)	$	500		$	—
	Declared distribution	$	18,323	$	17,145	$	143	$	1,035	$	16,796		$	15,979		$	134		$	683
	Assumed allocation of undistributed net income (loss)	38,687		38,357		330		—		(38,863		)	(38,546		)	(317		)	—
	Assumed allocation of net income (loss)	$	57,010	$	55,502	$	473	$	1,035	$	(22,067	)	$	(22,567	)	$	(183	)	$	683
	Denominator:
	Basic weighted average limited partner units outstanding			27,261									27,323
	Dilutive effect of phantom units			35									—
	Diluted weighted average limited partner units outstanding			27,296									27,323
	Basic net income (loss) per limited partner unit			$	2.04								$	(0.83	)
	Diluted net income (loss) per limited partner unit (1)			$	2.03								$	(0.83	)
	(1)          Basic units were used to calculate diluted net income per limited partner unit for the three months ended March 31, 2013, as using the effects of phantom units would have an anti-dilutive effect on income per limited partner unit.

Inventories_Tables

Inventories (Tables)	3 Months Ended
	Mar. 31, 2014
Inventories	'
Schedule of inventories	'
	Inventories consisted of the following (in thousands):
		March 31,		December 31,
		2014		2013
	Distillates: home heating oil, diesel and kerosene	$	163,547	$	272,760
	Gasoline	100,133		96,539
	Gasoline blendstocks	93,352		54,076
	Renewable identification numbers (RINs)	2,760		3,186
	Crude oil	52,024		87,022
	Residual oil	37,116		48,793
	Propane and other	3,416		3,443
	Convenience store inventory	8,130		6,987
	Total	$	460,478	$	572,806

Derivative_Financial_Instrumen1

Derivative Financial Instruments (Tables)	3 Months Ended
	Mar. 31, 2014
Derivative Financial Instruments	'
Schedule of the volume of activity related to the derivative financial instruments	'
			Units (1)		Unit of Measure
	Futures Contracts
	Long		12,756		Thousands of barrels
	Short		(15,748	)	Thousands of barrels
	Natural Gas Contracts
	Long		4,537		Thousands of decatherms
	Short		(4,537	)	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)	$	16.7		Millions of Canadian dollars
		$	15.1		Millions of U.S. dollars
	(1)          Number of open positions and gross notional amounts do not quantify risk or represent assets or liabilities of the Partnership, but are used in the calculation of daily cash settlements under the contracts.
	(2)          All-in forward rate Canadian dollars (“CAD”) $1.1053 to USD $1.00.
Summary of derivatives not designated as either fair value hedges or cash flow hedges and their respective fair values and location	'
	The following table summarizes the derivatives not designated by the Partnership as either fair value hedges or cash flow hedges and their respective fair values and location in the Partnership’s consolidated balance sheets at March 31, 2014 and December 31, 2013 (in thousands):
							March 31,			December 31,
					Balance Sheet		2014			2013
	Summary of Other Derivatives		Item Pertains to		Location		Fair Value			Fair Value
	Asset Derivatives
	Forward purchase commitments		Gasoline and Gasoline Blendstocks		-1		$	67,354		$	14,119
			Distillates		-1		525			2,232
			Residual Oil		-1		47			34
			Crude Oil		-1		8,969			13,693
	Total forward purchase commitments						76,895			30,078
	Forward sales commitments		Gasoline and Gasoline Blendstocks		-1		672			1,486
			Distillates		-1		391			797
			Residual Oil		-1		—			655
			Crude Oil		-1		1,166			383
			Natural Gas		-1		1,364			12,608
	Total forward sales commitments						3,593			15,929
	Total fair value of forward fixed price contracts						$	80,488		$	46,007
	Liability Derivatives
	Forward purchase commitments		Gasoline and Gasoline Blendstocks		-2		$	1,950		$	3,625
			Distillates		-2		734			1,396
			Residual Oil		-2		—			990
			Crude Oil		-2		6,134			2,122
			Natural Gas		-2		1,353			12,485
	Total forward purchase commitments						10,171			20,618
	Forward sales commitments		Gasoline and Gasoline Blendstocks		-2		71,577			10,709
			Distillates		-2		452			3,809
			Residual Oil		-2		539			—
			Crude Oil		-2		7,191			3,061
	Total forward sales commitments						79,759			17,579
	Total obligations on forward fixed price contracts and other derivatives						89,930			38,197
	Foreign currency forward contract		Foreign Denominated Sales		-3		74			16
	Total liability derivatives						$	90,004		$	38,213
	(1)          Fair value of forward fixed price contracts
	(2)          Obligations on forward fixed price contracts
	(3)          Accrued expenses and other current liabilities
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 amount of gains and losses from derivatives not involved in a fair value hedging relationship or in a hedging relationship recognized in the Partnership’s consolidated statements of operations for the three months ended March 31, 2014 and 2013 (in thousands):
					Amount of Gain (Loss)
					Recognized in Income
					on Derivatives
			Location of Gain (Loss)		Three Months Ended
	Derivatives Not Designated as		Recognized in		March 31,			March 31,
	Hedging Instruments		Income on Derivatives		2014			2013
	Product contracts		Cost of sales		$	15,543		$	666
	Foreign currency contracts		Cost of sales		(57		)	(321		)
	Total				$	15,486		$	345
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 hedge ineffectiveness from derivatives involved in fair value hedging relationships recognized in the Partnership’s consolidated statements of operations for the three months ended March 31, 2014 and 2013 (in thousands):
					Amount of Gain (Loss)
					Recognized in Income on
					Derivatives
			Location of Gain (Loss)		Three Months Ended
	Derivatives in Fair Value		Recognized in		March 31,
	Hedging Relationships		Income on Derivatives		2014			2013
	Futures contracts		Cost of sales		$	16,373		$	(10,384	)
					Amount of Gain (Loss)
					Recognized in Income on
					Hedged Items
			Location of Gain (Loss)		Three Months Ended
	Hedged Items in Fair Value		Recognized in Income		March 31,
	Hedge Relationships		on Hedged Item		2014			2013
	Inventories		Cost of sales		$	(16,209	)	$	10,396
Cash flow hedging relationships	'
Derivative Financial Instruments	'
Schedule of fair values of derivative instruments and location in consolidated balance sheets	'
	The following table presents the fair value of the Partnership’s derivative instruments involved in cash flow hedging relationships and their location in the Partnership’s consolidated balance sheets at March 31, 2014 and December 31, 2013 (in thousands):
					March 31,			December 31,
	Derivatives Designated as				2014			2013
	Hedging Instruments		Balance Sheet Location		Fair Value			Fair Value
	Asset derivatives
	Interest rate cap		Other assets		$	7		$	25
	Liability derivatives
	Interest rate swaps		Other long-term liabilities		$	8,785		$	9,462
Schedule of net gains and losses from derivatives recognized in consolidated statements of operations	'
	The following table presents the amount of net gains and losses from derivatives involved in cash flow hedging relationships recognized in the Partnership’s consolidated statements of operations and partners’ equity for the three months ended March 31, 2014 and 2013 (in thousands):
									Recognized in Income
			Amount of Gain (Loss)						on Derivatives
			Recognized in Other						(Ineffectiveness Portion
			Comprehensive Income						and Amount Excluded
			on Derivatives						from Effectiveness Testing)
			Three Months Ended						Three Months Ended
	Derivatives in Cash Flow		March 31,			March 31,			March 31,			March 31,
	Hedging Relationship		2014			2013			2014			2013
	Interest rate collar		$	—		$	615		$	—		$	—
	Interest rate swaps		677			863			—			—
	Interest rate cap		(18		)	(5		)	—			—
	Total		$	659		$	1,473		$	—		$	—

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2014
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,
		2014		2013
	Receivables from GPC	$	438	$	436
	Receivables from the General Partner (1)	1,200		968
	Total	$	1,638	$	1,404
	(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, 2014

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

Minimum Quarterly Distribution

$0.46

99.17%

0.83%

First Target Distribution

$0.46

99.17%

0.83%

Second Target Distribution

above $0.4625 up to $0.5375

86.17%

13.83%

Third Target Distribution

above $0.5375 up to $0.6625

76.17%

23.83%

Thereafter

above $0.6625

51.17%

48.83%

Schedule of cash distribution made by the Partnership

'

The Partnership paid the following cash distribution during 2014 (in thousands, except per unit data):

Cash

Per Unit

Common

General

Incentive

Total Cash

Distribution

Cash

Units

Partner

Distribution

Distribution

Payment Date

Distribution

02/14/14 (1)

$

0.6125

$

16,802

$

140

$

932

$

17,874

(1)          This distribution of $0.6125 per unit resulted in the Partnership exceeding its second target level distribution for the fourth quarter of 2013.  As a result, the General Partner, as the holder of the IDRs, received an incentive distribution.

Segment_Reporting_Tables

Segment Reporting (Tables)	3 Months Ended
	Mar. 31, 2014
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,
		2014			2013
	Wholesale Segment (1):
	Sales
	Gasoline and gasoline blendstocks	$	1,994,556		$	2,201,469
	Crude oil (2)	591,229			983,965
	Other oils and related products (3)	1,412,771			1,332,554
	Total	$	3,998,556		$	4,517,988
	Product margin
	Gasoline and gasoline blendstocks (4)	$	49,663		$	(29,426	)
	Crude oil (2)	23,490			26,168
	Other oils and related products (3)	34,616			17,658
	Total (4)	$	107,769		$	14,400
	Gasoline Distribution and Station Operations Segment:
	Sales
	Gasoline	$	768,904		$	745,590
	Station operations (5)	33,972			31,608
	Total	$	802,876		$	777,198
	Product margin
	Gasoline	$	33,280		$	28,193
	Station operations (5)	19,134			17,836
	Total	$	52,414		$	46,029
	Commercial Segment:
	Sales	$	315,496		$	294,004
	Product margin	$	12,329		$	10,425
	Combined sales and product margin:
	Sales	$	5,116,928		$	5,589,190
	Product margin (4)(6)	$	172,512		$	70,854
	Depreciation allocated to cost of sales	(14,151		)	(11,782		)
	Combined gross profit (4)	$	158,361		$	59,072
	(1)         Segment reporting results for the prior period have been reclassified to conform to the Partnership’s current presentation.
	(2)         Crude oil consists of the Partnership’s crude oil sales and revenue from its logistics activities and includes the February 2013 acquisitions of Basin Transload and Cascade Kelly.  As the Basin Transload and Cascade Kelly assets were not in place for a portion of the quarter ended March 31, 2013, the above results are not directly comparable for periods prior to February 2013.
	(3)         Other oils and related products primarily consist of distillates, residual oil and propane.
	(4)         As of March 31, 2014, the mark to market loss related to RIN forward commitments was $0.1 million and the mark to market value of a Renewable Volume Obligation (“RVO”) deficiency was $3.9 million.  As of March 31, 2013, the mark to market loss related to RIN forward commitments was $32.7 million and the mark to market value of a RVO deficiency was $2.6 million.
	(5)         Station operations primarily consist of convenience store sales at the Partnership’s directly operated stores and rental income from dealer leased or commission agent leased gasoline stations.
	(6)         Product margin is a non-GAAP financial measure used by management and external users of the Partnership’s consolidated financial statements to assess the Partnership’s 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,
		2014			2013
	Combined gross profit (1)	$	158,361		$	59,072
	Operating costs and expenses not allocated to operating segments:
	Selling, general and administrative expenses	37,298			25,663
	Operating expenses	47,952			43,340
	Amortization expense	4,528			3,774
	Total operating costs and expenses	89,778			72,777
	Operating income (loss)	68,583			(13,705		)
	Interest expense	(11,107		)	(10,486		)
	Income tax (expense) benefit	(322		)	1,875
	Net income (loss) (1)	57,154			(22,316		)
	Net (income) loss attributable to noncontrolling interest	(144		)	249
	Net income (loss) attributable to Global Partners LP (1)	$	57,010		$	(22,067	)
	(1)          As of March 31, 2014, the mark to market loss related to RIN forward commitments was $0.1 million and the mark to market value of a RVO deficiency was $3.9 million.  As of March 31, 2013, the mark to market loss related to RIN forward commitments was $32.7 million and the mark to market value of a RVO deficiency was $2.6 million.
Schedule of total assets by reportable segment	'
	The table below presents total assets by reportable segment at March 31, 2014 and December 31, 2013 (in thousands):
		Wholesale			Commercial			GDSO		Unallocated (1)		Total
	March 31, 2014	$	79,589		$	—		$	496,310	$	1,730,604	$	2,306,503
	December 31, 3013	$	83,208		$	—		$	499,966	$	1,844,748	$	2,427,922
	(1)          Includes 40% owned by the noncontrolling interest at Basin Transload.

Property_and_Equipment_Tables

Property and Equipment (Tables)	3 Months Ended
	Mar. 31, 2014
Property and Equipment	'
Schedule of components of property and equipment	'
	Property and equipment consisted of the following (in thousands):
		March 31			December 31,
		2014			2013
	Buildings and improvements	$	601,727		$	601,900
	Land	285,971			287,044
	Fixtures and equipment	20,961			19,890
	Construction in process	67,206			59,277
	Capitalized internal use software	5,847			5,847
	Total property and equipment	981,712			973,958
	Less accumulated depreciation	(182,588		)	(170,322		)
	Total	$	799,124		$	803,636

Environmental_Liabilities_Asse1

Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers (RINs) (Tables)	3 Months Ended
	Mar. 31, 2014
Environmental Liabilities, Asset Retirement Obligations 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, 2014 (in thousands):
		Balance at											Balance at
		December 31,		Payments in			Dispositions			Other			March 31,
	Environmental Liability Related to:	2013		2014			2014			Adjustments			2014
	ExxonMobil Gasoline Stations	$	24,745	$	(148	)	$	(159	)	$	(206	)	$	24,232
	Alliance Gasoline Stations	13,921		(44		)	—			48			13,925
	Mutual Oil	625		—			—			—			625
	Newburgh	1,500		—			—			—			1,500
	Glenwood Landing and Inwood	301		(16		)	—			—			285
	Albany	47		(2		)	—			—			45
	Total environmental liabilities	$	41,139	$	(210	)	$	(159	)	$	(158	)	$	40,612
	Current portion	$	3,377										$	3,360
	Long-term portion	37,762											37,252
	Total environmental liabilities	$	41,139										$	40,612

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2014
Fair Value Measurements	'
Schedule of financial assets and financial liabilities measured at fair value on a recurring basis	'
	The following table presents those financial assets and financial liabilities measured at fair value on a recurring basis as of March 31, 2014 and December 31, 2013 (in thousands):
		Fair Value as of March 31, 2014												Fair Value as of December 31, 2013
		Total			Level 1			Level 2			Level 3			Total			Level 1			Level 2			Level 3
	Assets:
	Hedged inventories	$	248,918		$	—		$	248,918		$	—		$	452,302		$	—		$	452,302		$	—
	Fair value of forward fixed price contracts	80,488			—			70,353			10,135			46,007			—			31,931			14,076
	Swap agreements and options	58			10			48			—			116			74			42			—
	Interest rate cap	7			—			7			—			25			—			25			—
	Broker margin deposits	15,193			15,193			—			—			21,792			21,792			—			—
	Pension plan	17,666			17,666			—			—			18,267			18,267			—			—
	Total	$	362,330		$	32,869		$	319,326		$	10,135		$	538,509		$	40,133		$	484,300		$	14,076
	Liabilities:
	Obligations on forward fixed price contracts	$	(89,930	)	$	—		$	(76,605	)	$	(13,325	)	$	(38,197	)	$	—		$	(33,014	)	$	(5,183	)
	Mark to market loss related to RIN forward commitments	(122		)	—			(122		)	—			(6,166		)	—			(6,166		)	—
	Swap agreements and option contracts	(10		)	(10		)	—			—			(108		)	(74		)	(34		)	—
	Foreign currency derivatives	(74		)	—			(74		)	—			(16		)	—			(16		)	—
	Interest rate swaps	(8,785		)	—			(8,785		)	—			(9,462		)	—			(9,462		)	—
	Total liabilities	$	(98,921	)	$	(10	)	$	(85,586	)	$	(13,325	)	$	(53,949	)	$	(74	)	$	(48,692	)	$	(5,183	)
Summary of the changes in fair value of Level 3 financial assets and liabilities	'
	Fair value at December 31, 2013	$	8,894
	Change in fair value recorded in Cost of Sales	(12,084		)
	Fair value at March 31, 2014	$	(3,190	)

Changes_in_Accumulated_Other_C1

Changes in Accumulated Other Comprehensive (Income) Loss (Tables)	3 Months Ended
	Mar. 31, 2014
Changes in Accumulated Other Comprehensive (Income) Loss	'
Schedule of changes in accumulated other comprehensive (income) loss	'
	The following table presents the changes in accumulated other comprehensive (income) loss by component for the three months ended March 31, 2014 (in thousands):
		Pension			Derivatives			Total
		Plan
	Balance at December 31, 2013	$	(454	)	$	(10,856	)	$	(11,310	)
	Other comprehensive (loss) income before reclassifications of gain (loss)	(481		)	659			178
	Amount of gain (loss) reclassified from accumulated other comprehensive income	(128		)	—			(128		)
	Total comprehensive (loss) income	(609		)	659			50
	Balance at March 31, 2014	$	(1,063	)	$	(10,197	)	$	(11,260	)

Organization_and_Basis_of_Pres3

Organization and Basis of Presentation (Details)	3 Months Ended		3 Months Ended
	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Feb. 28, 2013	Feb. 01, 2013	Feb. 15, 2013
	item		Affiliates of general partner	Basin Transload LLC	Basin Transload LLC	Cascade Kelly
Organization	'	'	'	'	'	'
Number of owned, leased and/or supplied gasoline stations	900	'	'	'	'	'
Percentage of outstanding membership interests acquired	'	'	'	60.00%	60.00%	100.00%
General partner interest (as a percent)	0.83%	'	'	'	'	'
Number of common units held	27,260,747	27,260,747	11,559,252	'	'	'
Limited partner ownership interest (as a percent)	'	'	42.10%	'	'	'

Organization_and_Basis_of_Pres4

Organization and Basis of Presentation (Details 2) (Sales)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
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	55.00%	53.00%
Product | Crude oil sales and logistics revenue	'	'
Concentration of Risk	'	'
Percentage of total sales	12.00%	18.00%
Product | Distillates (home heating oil, diesel and kerosene), residual oil, natural gas and propane sales	'	'
Concentration of Risk	'	'
Percentage of total sales	33.00%	29.00%
Customer	'	'
Concentration of Risk	'	'
Number of significant customers	1	2
Customer | ExxonMobil	'	'
Concentration of Risk	'	'
Percentage of total sales	14.00%	13.00%
Customer | Phillips 66	'	'
Concentration of Risk	'	'
Percentage of total sales	'	14.00%

Business_Combinations_Details

Business Combinations (Details) (USD $)	Feb. 14, 2013	Feb. 01, 2013	Mar. 31, 2014	Mar. 31, 2013	Feb. 28, 2013	Feb. 15, 2013	Feb. 15, 2013
	8.00% senior notes due 2018	Basin Transload	Basin Transload	Basin Transload	Basin Transload	Cascade Kelly	Cascade Kelly
		bbl				bbl	8.00% senior notes due 2018
		item				ft
Acquisitions	'	'	'	'	'	'	'
Percentage of outstanding membership interests acquired from AE Holdings	'	60.00%	'	'	60.00%	100.00%	'
Number of transloading facilities operated	'	2	'	'	'	'	'
Combined rail loading capacity per day (in barrels)	'	160,000	'	'	'	'	'
Expenditures related to certain capital expansion projects	'	$91,100,000	'	'	'	'	'
Purchase price	'	'	'	'	'	94,200,000	'
Rail transloading facility, storage capacity (in barrels)	'	'	'	'	'	200,000	'
Preliminary allocation of the purchase price	'	'	'	'	'	'	'
Deepwater marine terminal, leased dock access capacity (in feet)	'	'	'	'	'	1,200	'
Intangible assets acquired	'	'	'	'	'	'	'
Amortization period	'	'	'2 years	'	'	'	'
Amortization expense	'	'	2,700,000	2,000,000	'	'	'
Estimated remaining amortization expense	'	'	'	'	'	'	'
2014 (4/1/14-12/31/14)	'	'	8,266,000	'	'	'	'
2015	'	'	2,869,000	'	'	'	'
Total	'	'	11,135,000	'	'	'	'
Stated interest rate (as a percent)	8.00%	'	'	'	'	'	8.00%
Intangibles	'	'	'	'	'	$0	'

Net_Income_Loss_Per_Limited_Pa2

Net Income (Loss) Per Limited Partner Unit (Details) (USD $)	3 Months Ended			0 Months Ended	3 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013	Apr. 23, 2014	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Mar. 31, 2013
				Subsequent event	Limited Partner Interest	Limited Partner Interest	General Partner Interest	General Partner Interest	IDRs	IDRs
				General Partner
Net Income (Loss) Per Limited Partner Unit	'	'	'	'	'	'	'	'	'	'
Repurchased units not deemed outstanding	169,816	'	169,816	'	'	'	'	'	'	'
Net Income (Loss) Per Limited Partner Unit	'	'	'	'	'	'	'	'	'	'
Net income (loss) attributable to Global Partners LP	$57,010	($22,067)	'	'	$55,502	($22,567)	$1,508	$500	'	'
Declared distribution	18,323	16,796	'	'	17,145	15,979	143	134	1,035	683
Assumed allocation of undistributed net income (loss)	38,687	-38,863	'	'	38,357	-38,546	330	-317	'	'
Assumed allocation of net income (loss)	$57,010	($22,067)	'	'	$55,502	($22,567)	$473	($183)	$1,035	$683
Denominator:	'	'	'	'	'	'	'	'	'	'
Basic weighted average limited partner units outstanding	27,261,000	27,323,000	'	'	27,261,000	27,323,000	'	'	'	'
Dilutive effect of phantom units	'	'	'	'	35,000	'	'	'	'	'
Diluted weighted average limited partner units outstanding	27,296,000	27,323,000	'	'	27,296,000	27,323,000	'	'	'	'
Basic net income (loss) per limited partner unit (in dollars per unit)	$2.04	($0.83)	'	'	$2.04	($0.83)	'	'	'	'
Diluted net income (loss) per limited partner unit (in dollars per unit)	$2.03	($0.83)	'	'	$2.03	($0.83)	'	'	'	'
Quarterly cash distribution declared (in dollars per unit)	'	'	'	$0.63	'	'	'	'	'	'

Inventories_Details

Inventories (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
Inventories	'	'
Inventories	$460,478,000	$572,806,000
Positive exchange balances on inventory exchange agreements accounted for as accounts receivable	34,000,000	48,200,000
Negative exchange balances on inventory exchange agreements accounted for as accounts payable	51,700,000	46,700,000
Distillates: home heating oil, diesel and kerosene	'	'
Inventories	'	'
Inventories	163,547,000	272,760,000
Gasoline	'	'
Inventories	'	'
Inventories	100,133,000	96,539,000
Gasoline blendstocks	'	'
Inventories	'	'
Inventories	93,352,000	54,076,000
Renewable identification numbers (RINs)	'	'
Inventories	'	'
Inventories	2,760,000	3,186,000
Crude Oil	'	'
Inventories	'	'
Inventories	52,024,000	87,022,000
Residual oil	'	'
Inventories	'	'
Inventories	37,116,000	48,793,000
Propane and other	'	'
Inventories	'	'
Inventories	3,416,000	3,443,000
Convenience store inventory	'	'
Inventories	'	'
Inventories	$8,130,000	$6,987,000

Derivative_Financial_Instrumen2

Derivative Financial Instruments (Details)	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014
In Millions, unless otherwise specified	Futures Contracts	Futures Contracts	Natural Gas Contracts	Natural Gas Contracts	Interest Rate Swaps	Interest Rate Cap	Open Forward Exchange Contracts	Open Forward Exchange Contracts
	Long	Short	Long	Short	USD ($)	USD ($)	USD ($)	CAD
	bbl	bbl	decatherm	decatherm
Volume of activity related to derivative financial instruments	'	'	'	'	'	'	'	'
Nonmonetary units	12,756,000	-15,748,000	4,537,000	-4,537,000	'	'	'	'
Monetary units	'	'	'	'	$200	$100	$15.10	16.7
Forward rate of CAD to USD	'	'	'	'	'	'	1.1053	1.1053

Derivative_Financial_Instrumen3

Derivative Financial Instruments (Details 2) (USD $)	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Mar. 31, 2013
In Thousands, unless otherwise specified	Inventories	Inventories	Inventories	Inventories	Derivatives in Fair Value Hedging Relationships	Derivatives in Fair Value Hedging Relationships	Derivatives in Fair Value Hedging Relationships	Derivatives in Fair Value Hedging Relationships
			Cost of sales	Cost of sales	Futures contracts	Futures contracts	Futures contracts	Futures contracts
							Cost of sales	Cost of sales
Fair values of derivative financial instruments	'	'	'	'	'	'	'	'
Asset Derivatives	$0	$0	'	'	$0	$0	'	'
Liability Derivatives	0	0	'	'	0	0	'	'
Amount of Gain (Loss) Recognized in Income on Derivatives	'	'	'	'	'	'	16,373	-10,384
Amount of Gain (Loss) Recognized in Income on Hedged Items	'	'	($16,209)	$10,396	'	'	'	'

Derivative_Financial_Instrumen4

Derivative Financial Instruments (Details 3) (Derivatives in Cash Flow Hedging Relationship, USD $)	12 Months Ended	3 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Dec. 31, 2013
	Zero premium interest rate collar	Interest rate swaps	Interest rate cap	Forward interest rate swap	Derivatives Designated as Hedging Instruments	Derivatives Designated as Hedging Instruments	Derivatives Designated as Hedging Instruments	Derivatives Designated as Hedging Instruments
	Credit facility	Revolving credit facility	Credit facility	Revolving credit facility	Interest rate swaps	Interest rate swaps	Interest rate cap	Interest rate cap
					Other long-term liabilities	Other long-term liabilities	Other assets	Other assets
Fair values of derivative financial instruments	'	'	'	'	'	'	'	'
Hedged borrowings	$100,000	$100,000	$100,000	$100,000	'	'	'	'
Borrowings variable interest rate	'one-month LIBOR	'one-month LIBOR	'one-month LIBOR	'one-month LIBOR	'	'	'	'
Fixed rate (as a percent)	'	3.93%	'	1.82%	'	'	'	'
Maximum cap rate (as a percent)	'	'	5.50%	'	'	'	'	'
Asset Derivatives	'	'	'	'	'	'	7	25
Liability Derivatives	'	'	'	'	$8,785	$9,462	'	'

Derivative_Financial_Instrumen5

Derivative Financial Instruments (Details 4) (Derivatives in Cash Flow Hedging Relationship, USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Gains and losses from derivatives	'	'
Amount of Gain (Loss) Recognized in Other Comprehensive Income on Derivatives	$659	$1,473
Interest rate collar	'	'
Gains and losses from derivatives	'	'
Amount of Gain (Loss) Recognized in Other Comprehensive Income on Derivatives	'	615
Reclassification of gain (loss) from other comprehensive income to earnings	'	'
Amount of gain (loss) reclassified from other comprehensive income into earnings - effective portion	0	0
Interest rate swaps	'	'
Gains and losses from derivatives	'	'
Amount of Gain (Loss) Recognized in Other Comprehensive Income on Derivatives	677	863
Reclassification of gain (loss) from other comprehensive income to earnings	'	'
Amount of gain (loss) reclassified from other comprehensive income into earnings - effective portion	0	0
Interest rate cap	'	'
Gains and losses from derivatives	'	'
Amount of Gain (Loss) Recognized in Other Comprehensive Income on Derivatives	-18	-5
Reclassification of gain (loss) from other comprehensive income to earnings	'	'
Amount of gain (loss) reclassified from other comprehensive income into earnings - effective portion	$0	$0

Derivative_Financial_Instrumen6

Derivative Financial Instruments (Details 5) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Credit Risk	'	'
Number of clearing brokers, primarily utilized	3	'
Forward | Sales commitments	'	'
Derivatives not designated as either fair value hedges or cash flow hedges	'	'
Liability Derivatives	$89,930	$38,197
Derivatives not designated as either fair value hedges or cash flow hedges | Product contracts | Maximum	'	'
Derivatives not designated as either fair value hedges or cash flow hedges	'	'
Aggregate units of products in a controlled trading program	250,000	'
Derivatives not designated as either fair value hedges or cash flow hedges | Foreign currency forward contract | Foreign Denominated Sales	'	'
Derivatives not designated as either fair value hedges or cash flow hedges	'	'
Liability Derivatives	74	16
Derivatives not designated as either fair value hedges or cash flow hedges | Forward	'	'
Derivatives not designated as either fair value hedges or cash flow hedges	'	'
Asset Derivatives	80,488	46,007
Liability Derivatives	90,004	38,213
Derivatives not designated as either fair value hedges or cash flow hedges | Forward | Purchase commitments	'	'
Derivatives not designated as either fair value hedges or cash flow hedges	'	'
Asset Derivatives	76,895	30,078
Liability Derivatives	10,171	20,618
Derivatives not designated as either fair value hedges or cash flow hedges | Forward | Purchase commitments | Gasoline and gasoline blendstocks	'	'
Derivatives not designated as either fair value hedges or cash flow hedges	'	'
Asset Derivatives	67,354	14,119
Liability Derivatives	1,950	3,625
Derivatives not designated as either fair value hedges or cash flow hedges | Forward | Purchase commitments | Distillates	'	'
Derivatives not designated as either fair value hedges or cash flow hedges	'	'
Asset Derivatives	525	2,232
Liability Derivatives	734	1,396
Derivatives not designated as either fair value hedges or cash flow hedges | Forward | Purchase commitments | Residual Oil	'	'
Derivatives not designated as either fair value hedges or cash flow hedges	'	'
Asset Derivatives	47	34
Liability Derivatives	'	990
Derivatives not designated as either fair value hedges or cash flow hedges | Forward | Purchase commitments | Crude Oil	'	'
Derivatives not designated as either fair value hedges or cash flow hedges	'	'
Asset Derivatives	8,969	13,693
Liability Derivatives	6,134	2,122
Derivatives not designated as either fair value hedges or cash flow hedges | Forward | Purchase commitments | Natural Gas	'	'
Derivatives not designated as either fair value hedges or cash flow hedges	'	'
Liability Derivatives	1,353	12,485
Derivatives not designated as either fair value hedges or cash flow hedges | Forward | Sales commitments	'	'
Derivatives not designated as either fair value hedges or cash flow hedges	'	'
Asset Derivatives	3,593	15,929
Liability Derivatives	79,759	17,579
Derivatives not designated as either fair value hedges or cash flow hedges | Forward | Sales commitments | Gasoline and gasoline blendstocks	'	'
Derivatives not designated as either fair value hedges or cash flow hedges	'	'
Asset Derivatives	672	1,486
Liability Derivatives	71,577	10,709
Derivatives not designated as either fair value hedges or cash flow hedges | Forward | Sales commitments | Distillates	'	'
Derivatives not designated as either fair value hedges or cash flow hedges	'	'
Asset Derivatives	391	797
Liability Derivatives	452	3,809
Derivatives not designated as either fair value hedges or cash flow hedges | Forward | Sales commitments | Residual Oil	'	'
Derivatives not designated as either fair value hedges or cash flow hedges	'	'
Asset Derivatives	'	655
Liability Derivatives	539	'
Derivatives not designated as either fair value hedges or cash flow hedges | Forward | Sales commitments | Crude Oil	'	'
Derivatives not designated as either fair value hedges or cash flow hedges	'	'
Asset Derivatives	1,166	383
Liability Derivatives	7,191	3,061
Derivatives not designated as either fair value hedges or cash flow hedges | Forward | Sales commitments | Natural Gas	'	'
Derivatives not designated as either fair value hedges or cash flow hedges	'	'
Asset Derivatives	$1,364	$12,608

Derivative_Financial_Instrumen7

Derivative Financial Instruments (Details 6) (Derivatives not designated as either fair value hedges or cash flow hedges, USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Derivative Financial Instruments	'	'
Amount of Gain (Loss) Recognized in Income on Derivatives	$15,486	$345
Product contracts | Cost of sales	'	'
Derivative Financial Instruments	'	'
Amount of Gain (Loss) Recognized in Income on Derivatives	15,543	666
Foreign currency derivatives | Cost of sales	'	'
Derivative Financial Instruments	'	'
Amount of Gain (Loss) Recognized in Income on Derivatives	($57)	($321)

Debt_Details

Debt (Details)

3 Months Ended

0 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2013

Feb. 14, 2013

Dec. 23, 2013

Dec. 20, 2013

Dec. 20, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Dec. 15, 2013

Mar. 31, 2014

Mar. 31, 2014

Dec. 17, 2013

Dec. 15, 2013

Mar. 31, 2014

Dec. 31, 2013

Dec. 09, 2013

USD ($)

USD ($)

USD ($)

8.00% senior notes

7.75% senior notes

Maximum

Minimum

Swing line loans

Credit Agreement

Credit Agreement

Credit Agreement

Credit Agreement

Credit Agreement

Credit Agreement

Credit Agreement

Credit Agreement

Credit Agreement

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Working capital revolving credit facility

Letter of credit

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Credit Agreement

Credit Agreement

Credit Agreement

Line of Credit

Line of Credit

Line of Credit

USD ($)

USD ($)

8.00% senior notes

8.00% senior notes

USD ($)

USD ($)

USD ($)

USD ($)

AR Buyer

Maximum

Minimum

Minimum

Accordion feature

Accordion feature

USD ($)

USD ($)

Eurocurrency/Eurodollar rate

Eurocurrency/Eurodollar rate

Eurocurrency/Eurodollar rate

Eurocurrency/Eurodollar rate

Eurocurrency/Eurodollar rate

Eurocurrency/Eurodollar rate

Cost of funds rate

Cost of funds rate

Cost of funds rate

Cost of funds rate

Cost of funds rate

Cost of funds rate

Base rate

Base rate

Base rate

Base rate

Base rate

Base rate

Swing line loans

Credit Agreement

USD ($)

USD ($)

Eurocurrency/Eurodollar rate

Eurocurrency/Eurodollar rate

Eurocurrency/Eurodollar rate

Eurocurrency/Eurodollar rate

Eurocurrency/Eurodollar rate

Eurocurrency/Eurodollar rate

Cost of funds rate

Cost of funds rate

Cost of funds rate

Cost of funds rate

Cost of funds rate

Cost of funds rate

Base rate

Base rate

Base rate

Base rate

Base rate

Base rate

Credit Agreement

CAD

USD ($)

USD ($)

Basin Transload LLC

Basin Transload LLC

Basin Transload LLC

USD ($)

USD ($)

item

USD ($)

AR Buyer

Maximum

Minimum

Maximum

Maximum

Minimum

Minimum

Maximum

Maximum

Minimum

Minimum

Maximum

Maximum

Minimum

Minimum

USD ($)

Accordion feature

Maximum

Maximum

Minimum

Minimum

Maximum

Maximum

Minimum

Minimum

Maximum

Maximum

Minimum

Minimum

Accordion feature

USD ($)

USD ($)

USD ($)

item

USD ($)

USD ($)

Maximum

Maximum

USD ($)

USD ($)

Debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total available commitments

'

'

'

'

'

'

'

$1,625,000,000

'

'

'

'

'

'

'

'

'

$1,000,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$50,000,000

'

'

$625,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

200,000,000

$1,625,000,000

$1,615,000,000

'

'

$10,000,000

Number of line of credit facilities

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of cash purchase price to be paid to the selling Loan Party for each account receivable

'

'

'

'

'

'

'

'

'

'

'

'

'

'

85.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of affiliates to whom the accounts receivable is sold, which has not yet been collected

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum aggregate amount of the accounts receivable sold to affiliate, which has not yet been collected

'

'

'

'

'

'

'

'

'

'

'

75,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Servicing obligation

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of interest rate swaps

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Additional available commitments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

300,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

300,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

300,000,000

'

'

'

'

'

'

Increased credit facility

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,925,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Request Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Variable rate basis

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'Eurocurrency rate

'Eurodollar rate

'

'

'

'

'cost of funds

'cost of funds

'

'

'

'

'base rate

'base rate

'

'

'

'

'

'

'

'

'Eurocurrency rate

'Eurodollar rate

'

'

'

'

'cost of funds

'cost of funds

'

'

'

'

'base rate

'base rate

'

'

'

'

'

'

'

'

'

'

'

Interest rate margin (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.50%

2.50%

2.00%

2.00%

'

'

2.50%

2.50%

2.00%

2.00%

'

'

1.50%

1.50%

1.00%

1.00%

'

'

'

'

'

'

3.25%

3.50%

2.25%

2.50%

'

'

3.25%

3.50%

2.25%

2.50%

'

'

2.25%

2.50%

1.25%

1.50%

'

'

'

'

'

'

'

Average interest rates (as a percent)

'

'

'

'

'

'

'

'

3.60%

'

4.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Commitment fee on the unused portion (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

0.50%

0.38%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term portion

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

131,800,000

327,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current portion

3,700,000

'

3,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

175,000,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total borrowings outstanding

'

'

'

'

'

'

'

'

741,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

434,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,700,000

3,700,000

'

Outstanding letters of credit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

280,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total remaining availability for borrowings and letters of credit

'

'

'

'

'

'

'

'

602,700,000

'

479,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate principal amount

'

'

'

70,000,000

80,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stated interest rate (as a percent)

'

'

'

8.00%

7.75%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of face amount for which debt is issued

'

'

'

97.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from issuance of debt

'

'

'

67,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of discount at issuance, which will be accreted as additional interest over the expected term of Notes

'

'

'

2,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of debt that may be purchased, redeemed or otherwise acquired in any calendar year

'

'

'

'

'

10,000,000

5,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Indebtedness allowed to be incurred

'

'

'

'

'

60,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Indebtedness allowed to be incurred as a percentage of Consolidated Net Tangible Assets

'

'

'

'

'

5.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt default

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amortization expenses

$1,283,000

$1,571,000

'

'

'

'

'

'

$1,300,000

$1,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2012

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

GPC

GPC

GPC

GPC

GPC

AE Holdings

AE Holdings

General Partner

General Partner

General Partner

General Partner

General Partner

General Partner

Second amended and restated terminal storage rental and throughput agreement

Amended and restated services agreement

Amended and restated services agreement

Shared services agreement

Shared services agreement

Second amended and restated terminal storage rental and throughput agreement

Second amended and restated terminal storage rental and throughput agreement

Second amended and restated terminal storage rental and throughput agreement

Members of Slifka family

Global Companies LLC

Global Companies LLC

Members of Slifka family

Members of Slifka family

Members of Slifka family

Minimum

Related Party Transactions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage ownership interest

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

Information on related party transaction

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Successive term after July 31, 2015 under the agreement

'

'

'

'

'

'

'

'

'

'

'

'

'1 year

'

'

Expenses incurred from transactions with related parties

'

'

'

'

'

'

'

'

'

$22,100,000

$13,800,000

'

$2,300,000

$2,300,000

'

Amount to be paid per year

'

'

'

'

'

'

'

15,000

'

'

'

'

'

'

'

Notice period to terminate the receipt of services under the agreement

'

'

'

'

'

'180 days

'

'

'180 days

'

'

'

'

'

'90 days

Income from services provided to related parties

'

'

'

'

'

24,000

24,000

'

'

'

'

'

'

'

'

Receivables from related parties

$1,638,000

$1,404,000

$438,000

$436,000

'

'

'

'

'

$1,200,000

'

$968,000

'

'

'

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. 14, 2014

Mar. 31, 2014

Dec. 31, 2013

Apr. 23, 2014

Apr. 23, 2014

Feb. 14, 2014

Feb. 14, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

item

Subsequent event

Subsequent event

Common Unitholders

General Partner

Minimum Quarterly Distribution

Minimum Quarterly Distribution

Minimum Quarterly Distribution

First Target Distribution

First Target Distribution

First Target Distribution

Second Target Distribution

Second Target Distribution

Second Target Distribution

Second Target Distribution

Third Target Distribution

Third Target Distribution

Third Target Distribution

Third Target Distribution

Thereafter

Thereafter

Thereafter

General Partner Interest

General Partner Interest

Common Unitholders

General Partner

Common Unitholders

General Partner

Minimum

Maximum

Common Unitholders

General Partner

Minimum

Maximum

Common Unitholders

General Partner

Minimum

Common Unitholders

General Partner

Annualized basis

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total Quarterly Distribution Target Amount (in dollars per unit)

'

'

'

'

'

'

'

$0.46

'

'

$0.46

'

'

$0.46

$0.54

'

'

$0.54

$0.66

'

'

$0.66

'

'

Marginal Percentage Interest in Distributions

'

'

'

'

'

'

'

'

99.17%

0.83%

'

99.17%

0.83%

'

'

86.17%

13.83%

'

'

76.17%

23.83%

'

51.17%

48.83%

Cash Distribution Payment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Per Unit Cash Distribution (in dollars per unit)

$0.61

'

$0.61

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash distribution to common unitholders

$17,874

'

'

'

'

$16,802

$140

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Incentive Distribution

$932

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution declared

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Quarterly cash distribution declared (in dollars per unit)

'

'

'

$0.63

$2.50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Segment_Reporting_Details

Segment Reporting (Details) (USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Summarized financial information for the Partnership's reportable segments	'	'	'
Sales	$5,116,928,000	$5,589,190,000	'
Product margin	172,512,000	70,854,000	'
Gross profit	158,361,000	59,072,000	'
Mark to market loss related to RIN forward commitments	100,000	32,700,000	-6,200,000
Mark to market loss value for RVO deficiency	3,900,000	2,600,000	-13,100,000
Wholesale:	'	'	'
Summarized financial information for the Partnership's reportable segments	'	'	'
Sales	3,998,556,000	4,517,988,000	'
Product margin	107,769,000	14,400,000	'
Gasoline and gasoline blendstocks	'	'	'
Summarized financial information for the Partnership's reportable segments	'	'	'
Sales	1,994,556,000	2,201,469,000	'
Product margin	49,663,000	-29,426,000	'
Crude Oil	'	'	'
Summarized financial information for the Partnership's reportable segments	'	'	'
Sales	591,229,000	983,965,000	'
Product margin	23,490,000	26,168,000	'
Other oils and related products	'	'	'
Summarized financial information for the Partnership's reportable segments	'	'	'
Sales	1,412,771,000	1,332,554,000	'
Product margin	34,616,000	17,658,000	'
GDSO	'	'	'
Summarized financial information for the Partnership's reportable segments	'	'	'
Sales	802,876,000	777,198,000	'
Product margin	52,414,000	46,029,000	'
Gasoline	'	'	'
Summarized financial information for the Partnership's reportable segments	'	'	'
Sales	768,904,000	745,590,000	'
Product margin	33,280,000	28,193,000	'
Station operations	'	'	'
Summarized financial information for the Partnership's reportable segments	'	'	'
Sales	33,972,000	31,608,000	'
Product margin	19,134,000	17,836,000	'
Commercial Segment	'	'	'
Summarized financial information for the Partnership's reportable segments	'	'	'
Sales	315,496,000	294,004,000	'
Product margin	12,329,000	10,425,000	'
Not allocated to segments	'	'	'
Summarized financial information for the Partnership's reportable segments	'	'	'
Depreciation allocated to cost of sales	-14,151,000	-11,782,000	'
Intersegment transaction	'	'	'
Summarized financial information for the Partnership's reportable segments	'	'	'
Sales	$0	'	'

Segment_Reporting_Details_2

Segment Reporting (Details 2) (USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Reconciliation of the totals reported for the reportable segments to the applicable line items in the consolidated financial statements	'	'	'
Combined gross profit	$158,361,000	$59,072,000	'
Operating costs and expenses	'	'	'
Selling, general and administrative expenses	37,298,000	25,663,000	'
Operating expenses	47,952,000	43,340,000	'
Amortization expense	4,528,000	3,774,000	'
Total costs and operating expenses	89,778,000	72,777,000	'
Operating income (loss)	68,583,000	-13,705,000	'
Interest expense	-11,107,000	-10,486,000	'
Income tax (expense) benefit	-322,000	1,875,000	'
Net income (loss)	57,154,000	-22,316,000	'
Net (income) loss attributable to noncontrolling interest	-144,000	249,000	'
Net income (loss) attributable to Global Partners LP	57,010,000	-22,067,000	'
Mark to market loss related to RIN forward commitments	100,000	32,700,000	-6,200,000
Mark to market loss value for RVO deficiency	3,900,000	2,600,000	-13,100,000
Foreign assets	0	0	'
Operating costs and expenses not allocated to operating segments	'	'	'
Operating costs and expenses	'	'	'
Selling, general and administrative expenses	37,298,000	25,663,000	'
Operating expenses	47,952,000	43,340,000	'
Amortization expense	4,528,000	3,774,000	'
Total costs and operating expenses	$89,778,000	$72,777,000	'

Segment_Reporting_Details_3

Segment Reporting (Details 3) (USD $)	Feb. 28, 2013	Feb. 01, 2013
In Millions, unless otherwise specified
Basin Transload	'	'
Segment Assets	'	'
Percentage of membership interests acquired	60.00%	60.00%
Cascade Kelly and Basin Transload	'	'
Segment Assets	'	'
Assets including goodwill acquired in connection with acquisition	240.5	'
Wholesale Segment | Cascade Kelly and Basin Transload	'	'
Segment Assets	'	'
Property and equipment	90	'

Segment_Reporting_Details_4

Segment Reporting (Details 4) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Segment assets	'	'
Total	$2,306,503	$2,427,922
Basin Transload	'	'
Segment assets	'	'
Noncontrolling interest (as a percent)	40.00%	'
Wholesale	'	'
Segment assets	'	'
Total	79,589	83,208
GDSO	'	'
Segment assets	'	'
Total	496,310	499,966
Unallocated	'	'
Segment assets	'	'
Total	$1,730,604	$1,844,748

Property_and_Equipment_Details

Property and Equipment (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Property and Equipment	'	'
Total property and equipment	$981,712	$973,958
Less accumulated depreciation	-182,588	-170,322
Total	799,124	803,636
Buildings and improvements	'	'
Property and Equipment	'	'
Total property and equipment	601,727	601,900
Land	'	'
Property and Equipment	'	'
Total property and equipment	285,971	287,044
Fixtures and equipment	'	'
Property and Equipment	'	'
Total property and equipment	20,961	19,890
Construction in process	'	'
Property and Equipment	'	'
Total property and equipment	67,206	59,277
Construction in process | Ethanol plant	'	'
Property and Equipment	'	'
Total	30,500	'
Capitalized internal use software	'	'
Property and Equipment	'	'
Total property and equipment	$5,847	$5,847

Environmental_Liabilities_Asse2

Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers (RINs) (Details) (USD $)

3 Months Ended

3 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

0 Months Ended

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2013

Dec. 31, 2012

Mar. 31, 2014

Sep. 30, 2010

Mar. 31, 2014

Dec. 31, 2012

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2012

Jun. 30, 2010

Nov. 30, 2007

31-May-07

ExxonMobil Gasoline Stations

ExxonMobil Gasoline Stations

Alliance Gasoline Stations

Mutual Oil

Mutual Oil

Mutual Oil

Newburgh

Newburgh

Glenwood Landing and Inwood

Albany

Alliance Acquisition

Newburgh Terminals Acquisition

Glenwood Landing and Inwood, New York Terminal Acquisitions

Albany and Newburgh, New York and Burlington, Vermont Terminal Acquisitions

item

item

Environmental Liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of gasoline stations acquired

'

'

'

'

'

'

'

6

'

'

'

'

'

'

'

'

'

'

Number of refined petroleum products terminals acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3

'

'

Assumed environmental liabilities, recorded on an undiscounted basis

'

'

'

$600,000

'

$30,000,000

'

'

'

'

'

'

'

'

$16,100,000

$1,500,000

$1,200,000

$8,000,000

Changes in environmental liabilities during the period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at the beginning of the period

41,139,000

'

'

'

24,745,000

'

13,921,000

'

625,000

625,000

1,500,000

1,500,000

301,000

47,000

'

'

'

'

Payments

-210,000

'

'

'

-148,000

'

-44,000

'

'

'

'

'

-16,000

-2,000

'

'

'

'

Dispositions

-159,000

'

'

'

-159,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Adjustments

-158,000

'

'

'

-206,000

'

48,000

'

'

'

'

'

'

'

'

'

'

'

Balance at the end of the period

40,612,000

'

'

'

24,232,000

'

13,925,000

'

625,000

625,000

1,500,000

1,500,000

285,000

45,000

'

'

'

'

Environmental liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current portion

3,360,000

3,377,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term portion

37,252,000

37,762,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total environmental liabilities

40,612,000

'

'

'

24,232,000

'

13,925,000

'

625,000

625,000

1,500,000

1,500,000

285,000

45,000

'

'

'

'

Asset Retirement Obligations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total assets retirement obligations

2,100,000

2,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Renewable Identification Numbers (RINs)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Settlement period of RVO

'1 year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

RIN Deficiency

-3,900,000

13,100,000

-2,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-cancellable commitments

($100,000)

$6,200,000

($32,700,000)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

LongTerm_Incentive_Plan_Detail

Long-Term Incentive Plan (Details) (USD $)	0 Months Ended	3 Months Ended	59 Months Ended
In Millions, except Share data, unless otherwise specified	Jun. 27, 2013	Mar. 31, 2014	Mar. 31, 2014	Dec. 31, 2013	Jun. 22, 2012
Long-Term Incentive Plan	'	'	'	'	'
Number of common units initially authorized for issuance under LTIP (in shares)	'	564,242	564,242	'	'
Number of common units available for issuance	'	'	'	'	4,300,000
Long-Term Incentive Plan	'	'	'	'	'
Phantom units granted (in shares)	498,112	'	'	'	'
Compensation expenses for phantom unit awards	'	$0.80	'	'	'
Repurchase Program	'	'	'	'	'
Aggregate common units authorized to be acquired (in shares)	'	742,427	742,427	'	'
Common units repurchased by General Partner (in shares)	'	'	495,414	'	'
Common units repurchased by General Partner	'	0	12.2	'	'
Repurchased units not deemed outstanding	'	169,816	169,816	169,816	'
Phantom Unit Awards	'	'	'	'	'
Long-Term Incentive Plan	'	'	'	'	'
Compensation cost related to the non-vested awards not yet recognized	'	$17	$17	'	'
All employees except one employee | July 1, 2017	'	'	'	'	'
Long-Term Incentive Plan	'	'	'	'	'
Vesting rights percentage of phantom units	'	33.33%	'	'	'
All employees except one employee | July 1, 2018	'	'	'	'	'
Long-Term Incentive Plan	'	'	'	'	'
Cumulative vesting rights percentage on the second vesting of phantom units	'	66.67%	'	'	'
All employees except one employee | July 1, 2019	'	'	'	'	'
Long-Term Incentive Plan	'	'	'	'	'
Cumulative vesting rights percentage on the third vesting of phantom units	'	100.00%	'	'	'
One employee | December 31, 2014	'	'	'	'	'
Long-Term Incentive Plan	'	'	'	'	'
Vesting rights percentage of phantom units	'	33.33%	'	'	'
One employee | December 31, 2015	'	'	'	'	'
Long-Term Incentive Plan	'	'	'	'	'
Cumulative vesting rights percentage on the second vesting of phantom units	'	66.67%	'	'	'
One employee | December 31, 2016	'	'	'	'	'
Long-Term Incentive Plan	'	'	'	'	'
Cumulative vesting rights percentage on the third vesting of phantom units	'	100.00%	'	'	'
Non-employee directors | December 31, 2014	'	'	'	'	'
Long-Term Incentive Plan	'	'	'	'	'
Vesting rights percentage of phantom units	'	33.33%	'	'	'
Non-employee directors | December 31, 2015	'	'	'	'	'
Long-Term Incentive Plan	'	'	'	'	'
Cumulative vesting rights percentage on the second vesting of phantom units	'	66.67%	'	'	'
Non-employee directors | December 31, 2016	'	'	'	'	'
Long-Term Incentive Plan	'	'	'	'	'
Cumulative vesting rights percentage on the third vesting of phantom units	'	100.00%	'	'	'

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)

3 Months Ended

In Thousands, unless otherwise specified

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Recurring basis

Total estimated fair value

Total estimated fair value

Total estimated fair value

Total estimated fair value

Total estimated fair value

Total estimated fair value

Total estimated fair value

Total estimated fair value

Total estimated fair value

Total estimated fair value

Total estimated fair value

Total estimated fair value

Total estimated fair value

Total estimated fair value

Total estimated fair value

Total estimated fair value

Level 1

Level 1

Level 1

Level 1

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 3

Level 3

Level 3

Level 3

Forward fixed price purchase and sale contracts

Forward fixed price purchase and sale contracts

Mark to market loss related to RIN forward commitments

Mark to market loss related to RIN forward commitments

Swap agreements and option contracts

Swap agreements and option contracts

Interest rate cap

Interest rate cap

Interest rate swaps

Interest rate swaps

Foreign currency derivatives

Foreign currency derivatives

Inventories

Inventories

Swap agreements and option contracts

Swap agreements and option contracts

Forward fixed price purchase and sale contracts

Forward fixed price purchase and sale contracts

Mark to market loss related to RIN forward commitments

Mark to market loss related to RIN forward commitments

Swap agreements and option contracts

Swap agreements and option contracts

Interest rate cap

Interest rate cap

Interest rate swaps

Interest rate swaps

Foreign currency derivatives

Foreign currency derivatives

Inventories

Inventories

Forward fixed price purchase and sale contracts

Forward fixed price purchase and sale contracts

Assets:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Hedged inventories

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$248,918

$452,302

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$248,918

$452,302

'

'

'

'

Derivative assets

'

'

'

80,488

46,007

'

'

58

116

7

25

'

'

'

'

'

'

'

'

10

74

'

'

70,353

31,931

'

'

48

42

7

25

'

'

'

'

'

'

'

'

10,135

14,076

Broker margin deposits

'

15,193

21,792

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15,193

21,792

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Pension plan

'

17,666

18,267

'

'

'

'

'

'

'

'

'

'

'

'

'

'

17,666

18,267

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total assets

'

362,330

538,509

'

'

'

'

'

'

'

'

'

'

'

'

'

'

32,869

40,133

'

'

319,326

484,300

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10,135

14,076

'

'

Liabilities:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative liabilities

'

'

'

-89,930

-38,197

-122

-6,166

-10

-108

'

'

-8,785

-9,462

-74

-16

'

'

'

'

-10

-74

'

'

-76,605

-33,014

-122

-6,166

'

-34

'

'

-8,785

-9,462

-74

-16

'

'

'

'

-13,325

-5,183

Total liabilities

'

-98,921

-53,949

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-10

-74

'

'

-85,586

-48,692

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-13,325

-5,183

'

'

Changes in fair value of Level 3 financial assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair value at the beginning of the period

8,894

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Change in fair value recorded in Cost of Sales

-12,084

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair value at the end of the period

($3,190)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income_Taxes_Details

Income Taxes (Details)	3 Months Ended
	Mar. 31, 2014
	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) (Violation of existing permit, USD $)	0 Months Ended
	Mar. 27, 2014
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) Loss (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Changes in Accumulated other comprehensive (income) loss	'	'
Balance at the beginning of the period	($11,310)	'
Other comprehensive (loss) income before reclassifications of gain (loss)	178	'
Amount of gain (loss) reclassified from accumulated other comprehensive income	-128	'
Total other comprehensive income	50	2,239
Balance at the end of the period	-11,260	'
Pension Plan	'	'
Changes in Accumulated other comprehensive (income) loss	'	'
Balance at the beginning of the period	-454	'
Other comprehensive (loss) income before reclassifications of gain (loss)	-481	'
Amount of gain (loss) reclassified from accumulated other comprehensive income	-128	'
Total other comprehensive income	-609	'
Balance at the end of the period	-1,063	'
Derivatives	'	'
Changes in Accumulated other comprehensive (income) loss	'	'
Balance at the beginning of the period	-10,856	'
Other comprehensive (loss) income before reclassifications of gain (loss)	659	'
Total other comprehensive income	659	'
Balance at the end of the period	($10,197)	'

Subsequent_Event_Details

Subsequent Event (Details) (Subsequent event, General Partner, USD $)	0 Months Ended
	Apr. 23, 2014
Subsequent Events	'
Quarterly cash distribution declared (in dollars per unit)	$0.63
Annualized basis	'
Subsequent Events	'
Quarterly cash distribution declared (in dollars per unit)	$2.50