Global Partners (GLP) 10-Q 9 May 17 2017 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2017	May 04, 2017
Document and Entity Information
Entity Registrant Name	GLOBAL PARTNERS LP
Entity Central Index Key	1,323,468
Document Type	10-Q
Document Period End Date	Mar. 31, 2017
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		33,995,563
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q1

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Current assets:
Cash and cash equivalents	$ 14,126	$ 10,028
Accounts receivable, net	312,314	421,360
Accounts receivable-affiliates	2,957	3,143
Inventories	433,952	521,878
Brokerage margin deposits	18,886	27,653
Derivate assets	2,720	21,382
Prepaid expenses and other current assets	71,110	70,022
Total current assets	856,065	1,075,466
Property and equipment, net	1,074,465	1,099,899
Intangible assets, net	62,443	65,013
Goodwill	292,773	294,768
Other assets	42,583	28,874
Total assets	2,328,329	2,564,020
Current liabilities:
Accounts payable	232,125	320,262
Working capital revolving credit facility-current portion	176,900	274,600
Environmental liabilities-current portion	5,339	5,341
Trustee taxes payable	98,955	101,166
Accrued expenses and other current liabilities	59,171	70,443
Derivative liabilities	4,986	27,413
Total current liabilities	577,476	799,225
Working capital revolving credit facility-less current portion	150,000	150,000
Revolving credit facility	200,700	216,700
Senior notes	659,805	659,150
Environmental liabilities-less current portion	55,105	57,724
Financing obligations	152,466	152,444
Deferred tax liabilities	65,296	66,054
Other long-term liabilities	62,173	64,882
Total liabilities	1,923,021	2,166,179
Global Partners LP equity:
Common unitholders 33,995,563 units issued and 33,554,328 outstanding at March 31, 2017 and 33,995,563 units issued and 33,543,669 outstanding at December 31, 2016)	408,187	401,044
General partner interest (0.67% interest with 230,303 equivalent units outstanding at March 31, 2017 and December 31, 2016)	(2,900)	(2,948)
Accumulated other comprehensive loss	(4,724)	(5,441)
Total Global Partners LP equity	400,563	392,655
Noncontrolling interest	4,745	5,186
Total partners' equity	405,308	397,841
Total liabilities and partners' equity	$ 2,328,329	$ 2,564,020

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Mar. 31, 2017	Dec. 31, 2016
CONSOLIDATED BALANCE SHEETS
Common unitholders, units issued	33,995,563	33,995,563
Common unitholders, units outstanding	33,554,328	33,543,669
General partner interest (as a percent)	0.67%	0.67%
General partner interest, equivalent units outstanding	230,303	230,303

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
CONSOLIDATED STATEMENTS OF OPERATIONS
Sales	$ 2,270,784	$ 1,750,812
Cost of sales	2,130,757	1,620,753
Gross profit	140,027	130,059
Costs and operating expenses:
Selling, general and administrative expenses	36,787	34,984
Operating expenses	67,213	72,236
Amortization expense	2,261	2,509
Net (gain) loss on sale and disposition of assets	(11,862)	6,105
Total costs and operating expenses	94,399	115,834
Operating income	45,628	14,225
Interest expense	(23,287)	(22,980)
Income (loss) before income tax benefit	22,341	(8,755)
Income tax benefit	164	920
Net income (loss)	22,505	(7,835)
Net loss attributable to noncontrolling interest	441	811
Net income (loss) attributable to Global Partners LP	22,946	(7,024)
Less: General partner’s interest in net income (loss), including incentive distribution rights	154	(47)
Limited partners’ interest in net income (loss)	$ 22,792	$ (6,977)
Basic net income (loss) per limited partner unit	$ 0.68	$ (0.21)
Diluted net income (loss) per limited partner unit	$ 0.68	$ (0.21)
Basic weighted average limited partner units outstanding (in units)	33,554	33,517
Diluted weighted average limited partner units outstanding (in units)	33,610	33,517

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
Net income (loss)	$ 22,505	$ (7,835)
Other comprehensive income:
Change in fair value of cash flow hedges	398	261
Change in pension liability	319	68
Total other comprehensive income	717	329
Comprehensive income (loss)	23,222	(7,506)
Comprehensive loss attributable to noncontrolling interest	441	811
Comprehensive income (loss) attributable to Global Partners LP	$ 23,663	$ (6,695)

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Cash flows from operating activities
Net income (loss)	$ 22,505	$ (7,835)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation and amortization	26,364	28,669
Amortization of deferred financing fees	1,535	1,429
Amortization of leasehold interests	310	313
Amortization of senior notes discount	356	343
Bad debt expense	752	50
Unit-based compensation expense	(117)	1,075
Write-off of financing fees		1,828
Net (gain) loss on sale and disposition of assets	(11,862)	6,105
Changes in operating assets and liabilities, excluding net assets acquired:
Accounts receivable	108,294	2,945
Accounts receivable - affiliate	186	(904)
Inventories	87,379	(13,920)
Broker margin deposits	8,767	(7,528)
Prepaid expenses, all other current assets and other assets	(16,017)	(9,952)
Accounts payable	(88,137)	(47,982)
Trustee taxes payable	(2,211)	(7,259)
Change in derivatives	(5,256)	16,714
Accrued expenses, all other current liabilities and other long-term liabilities	(15,283)	(17,607)
Net cash provided by (used in) operating activities	117,565	(53,516)
Cash flows from investing activities
Capital expenditures	(8,378)	(16,451)
Proceeds from sale of property and equipment	24,249	8,588
Net cash provided by (used in) investing activities	15,871	(7,863)
Cash flows from financing activities
Net borrowings from (payments on) working capital revolving credit facility	(97,700)	87,100
Net borrowings from (payments on) revolving credit facility	(16,000)	6,100
Noncontrolling interest capital contribution		357
Distribution to noncontrolling interest		(595)
Distributions to partners	(15,638)	(15,630)
Net cash (used in) provided by financing activities	(129,338)	77,332
Cash and cash equivalents
Increase in cash and cash equivalents	4,098	15,953
Cash and cash equivalents at beginning of year	10,028	1,116
Cash and cash equivalents at end of year	14,126	17,069
Supplemental information
Cash paid during the period for interest	$ 17,265	$ 17,232

CONSOLIDATED STATEMENTS OF PART

CONSOLIDATED STATEMENTS OF PARTNERS' EQUITY - 3 months ended Mar. 31, 2017 - USD ($) $ in Thousands	Common Unitholders	General Partner Interest	Accumulated Other Comprehensive Loss	Noncontrolling Interest	Total
Balance, beginning of period at Dec. 31, 2016	$ 401,044	$ (2,948)	$ (5,441)	$ 5,186	$ 397,841
Increase (Decrease) in Partners' Capital
Net income (loss)	22,792	154		(441)	22,505
Other comprehensive income			717		717
Unit-based compensaton	(117)				(117)
Distributions to partners	(15,723)	(106)			(15,829)
Dividends on repurchased units	191				191
Balance, end of period at Mar. 31, 2017	$ 408,187	$ (2,900)	$ (4,724)	$ 4,745	$ 405,308

Organization and Basis of Prese

Organization and Basis of Presentation	3 Months Ended
	Mar. 31, 2017
Organization and Basis of Presentation
Organization and Basis of Presentation	Note 1. Organization and Basis of Presentation Organization Global Partners LP (the “Partnership”) is a midstream logistics and marketing master limited partnership formed in March 2005 engaged in the purchasing, selling, storing and logistics of transporting petroleum and related products, including gasoline and gasoline blendstocks (such as ethanol), distillates (such as home heating oil, diesel and kerosene), residual oil, renewable fuels, crude oil and propane. 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 is one of the largest distributors of gasoline, distillates, residual oil and renewable fuels to wholesalers, retailers and commercial customers in the New England states and New York. The Partnership is also one of the largest independent owners, suppliers and operators of gasoline stations and convenience stores with locations throughout the New England states and New York. As of March 31, 2017, the Partnership had a portfolio of 1,445 owned, leased and/or supplied gasoline stations, including 243 directly operated convenience stores, in the Northeast, Maryland and Virginia. The Partnership also receives revenue from convenience store sales and gasoline station rental income. In addition, the Partnership owns transload and storage terminals in North Dakota and Oregon that extend its origin-to-destination capabilities from the mid-continent region of the United States and Canada. Global GP LLC, the Partnership’s general partner (the “General Partner”), manages the Partnership’s operations and activities and employs its officers and substantially all of its personnel, except for most of its gasoline station and convenience store employees who are employed by Global Montello Group Corp. (“GMG”), a wholly owned subsidiary of the Partnership. The General Partner, which holds a 0.67% general partner interest in the Partnership, is owned by affiliates of the Slifka family. As of March 31, 2017, affiliates of the General Partner, including its directors and executive officers and their affiliates, owned 7,433,829 common units, representing a 21.9% limited partner interest. Recent Transactions Amended and Restated Credit Agreement — On April 25, 2017, the Partnership and certain of its subsidiaries entered into a third amended and restated credit agreement with aggregate commitments of $1.3 billion and a maturity date of April 30, 2020. See Note 7 for additional information. Potential Sale of Terminal Assets —On February 2, 2017, the Partnership began soliciting proposals for the potential sale of six refined petroleum products terminals located in New England, New York and Pennsylvania. The assets consist of product terminals that represent 1.1 million barrels of aggregate storage capacity. These assets did not meet the criteria to be presented as held for sale as of March 31, 2017. Sale of Natural Gas and Electricity Brokerage Businesses — On February 1, 2017, the Partnership completed the sale of its natural gas marketing and electricity brokerage businesses for a purchase price of approximately $17.3 million, subject to customary closing adjustments. Proceeds from the sale amounted to approximately $16.3 million, and the Partnership realized a gain on the sale of $14.2 million. The sale of the natural gas marketing and electricity brokerage businesses reflects the Partnership’s ongoing program to monetize non-strategic assets not fundamental to its growth strategy. Prior to the sale, the results of natural gas marketing and electricity brokerage businesses were included in the Commercial segment. See Note 6. Basis of Presentation The accompanying consolidated financial statements as of March 31, 2017 and December 31, 2016 and for the three months ended March 31, 2017 and 2016 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, 2016 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, 2017 are not necessarily indicative of the results of operations that will be realized for the entire year ending December 31, 2017. The consolidated balance sheet at December 31, 2016 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, 2016. Noncontrolling Interest The Partnership acquired a 60% interest in Basin Transload, LLC (“Basin Transload”) on February 1, 2013. After evaluating Accounting Standards Codification (“ASC”) Topic 810, “Consolidations,” the Partnership concluded it is appropriate to consolidate the balance sheet and statements of operations of Basin Transload based on an evaluation of the outstanding voting interests. Amounts pertaining to the noncontrolling ownership interest held by third parties in the financial position and operating results of the Partnership are reported as a noncontrolling interest in the accompanying consolidated balance sheets and statements of operations. Concentration of Risk Due to the nature of the Partnership’s business and its reliance, in part, on consumer travel and spending patterns, the Partnership may experience more demand for gasoline during the late spring and summer months than during the fall and winter. Travel and recreational activities are typically higher in these months in the geographic areas in which the Partnership operates, increasing the demand for gasoline. Therefore, the Partnership’s volumes in gasoline are typically higher in the second and third quarters of the calendar year. As demand for some of the Partnership’s refined petroleum products, specifically home heating oil and residual oil for space heating purposes, is generally greater during the winter months, heating oil and residual oil volumes are generally higher during the first and fourth quarters of the calendar year. These factors may result in fluctuations in the Partnership’s quarterly operating results. The following table presents the Partnership’s product sales and other revenues as a percentage of the consolidated sales for the periods presented: Three Months Ended March 31, 2017 2016 Gasoline sales: gasoline and gasoline blendstocks (such as ethanol) 59 % 57 % Crude oil sales and crude oil logistics revenue 5 % 8 % Distillates (home heating oil, diesel and kerosene), residual oil, natural gas and propane sales 33 % 30 % Convenience store sales, rental income and sundry sales 3 % 5 % Total 100 % 100 % The following table presents the Partnership’s product margin by segment as a percentage of the consolidated product margin for the periods presented: Three Months Ended March 31, 2017 2016 Wholesale segment 32 % 25 % Gasoline Distribution and Station Operations segment 65 % 70 % Commercial segment 3 % 5 % Total 100 % 100 % See Note 15, “Segment Reporting,” for additional information on the Partnership’s operating segments. None of the Partnership’s customers accounted for greater than 10% of total sales for the three months ended March 31, 2017 and 2016.

Net (Loss) Income Per Limited P

Net (Loss) Income Per Limited Partner Unit	3 Months Ended
	Mar. 31, 2017
Net (Loss) Income Per Limited Partner Unit
Net (Loss) Income Per Limited Partner Unit	Note 2. 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 or losses is assumed to be allocated to the common unitholders, or limited partners’ interest, and to the General Partner’s general partner interest. Common units outstanding as reported in the accompanying consolidated financial statements at March 31, 2017 and December 31, 2016 excluded 441,235 and 451,894 common units, respectively, held on behalf of the Partnership pursuant to its repurchase program (see Note 12). These units are not deemed outstanding for purposes of calculating net income (loss) 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, 2017 and 2016 (in thousands, except per unit data): Three Months Ended March 31, 2017 Three Months Ended March 31, 2016 Limited General Limited General Partner Partner Partner Partner Numerator: Total Interest Interest IDRs Total Interest Interest IDRs Net income (loss) attributable to Global Partners LP $ 22,946 $ 22,792 $ 154 $ — $ (7,024) $ (6,977) $ (47) $ — Declared distribution $ 15,829 $ 15,723 $ 106 $ — $ 15,829 $ 15,723 $ 106 $ — Assumed allocation of undistributed net income (loss) 7,117 7,069 48 — (22,853) (22,700) (153) — Assumed allocation of net income (loss) $ 22,946 $ 22,792 $ 154 $ — $ (7,024) $ (6,977) $ (47) $ — Denominator: Basic weighted average limited partner units outstanding 33,554 33,517 Dilutive effect of phantom units 56 — Diluted weighted average limited partner units outstanding 33,610 33,517 Basic net income (loss) per limited partner unit $ 0.68 $ (0.21) Diluted net income (loss) per limited partner unit (1) $ 0.68 $ (0.21) (1) Basic units were used to calculate diluted net loss per limited partner unit for the three months ended March 31, 2016, as using the effects of phantom units would have an anti-dilutive effect on net loss per limited partner unit. The board of directors of the General Partner declared the following quarterly cash distribution: Per Unit Cash Distribution Declared for the Cash Distribution Declaration Date Distribution Declared Quarterly Period Ended April 28, 2017 $ 0.4625 March 31, 2017 See Note 13, “Partners’ Equity and Cash Distributions” for further information.

Inventories

Inventories	3 Months Ended
	Mar. 31, 2017
Inventories
Inventories	Note 3. Inventories The Partnership hedges substantially all of its petroleum and ethanol inventory using a variety of instruments, primarily exchange-traded futures contracts. These futures contracts are entered into when inventory is purchased and are either designated as fair value hedges against the inventory on a specific barrel basis for inventories qualifying for fair value hedge accounting or not designated and maintained as economic hedges against certain inventory of the Partnership on a specific barrel basis. Changes in fair value of these futures contracts, as well as the offsetting change in fair value on the hedged inventory, is recognized in earnings as an increase or decrease in cost of sales. All hedged inventory designated in a fair value hedge relationship is valued using the lower of cost, as determined by specific identification, or net realizable value, as determined at the product level. All petroleum and ethanol inventory not designated in a fair value hedging relationship is carried at the lower of historical cost, on a first-in, first-out basis, or net realizable value. Convenience store inventory and Renewable Identification Numbers (“RINs”) inventory are carried at the lower of historical cost or net realizable value. Inventories consisted of the following (in thousands): March 31, December 31, 2017 2016 Distillates: home heating oil, diesel and kerosene $ 157,037 $ 180,272 Gasoline 70,093 101,368 Gasoline blendstocks 49,276 54,582 Crude oil 121,577 136,113 Residual oil 18,319 29,536 Propane and other 976 3,167 Renewable identification numbers (RINs) 640 631 Convenience store inventory 16,034 16,209 Total $ 433,952 $ 521,878 In addition to its own inventory, the Partnership has exchange agreements for petroleum products and ethanol with unrelated third-party suppliers, whereby it may draw inventory from these other suppliers and suppliers may draw inventory from the Partnership. Positive exchange balances are accounted for as accounts receivable and amounted to $3.5 million and $4.0 million at March 31, 2017 and December 31, 2016, respectively. Negative exchange balances are accounted for as accounts payable and amounted to $7.4 million and $13.4 million at March 31, 2017 and December 31, 2016, respectively. Exchange transactions are valued using current carrying costs.

Goodwill

Goodwill	3 Months Ended
	Mar. 31, 2017
Goodwill and Intangible Assets
Goodwill	Note 4. Goodwill The following table presents changes in goodwill, all of which has been allocated to the Gasoline Distribution and Station Operations (“GDSO”) segment (in thousands): Balance at December 31, 2016 $ 294,768 Disposals (1) (1,995) Balance at March 31, 2017 $ 292,773 (1) Disposals represent derecognition of goodwill associated with the sale and disposition of certain assets. See Note 6.

Property and Equipment

Property and Equipment	3 Months Ended
	Mar. 31, 2017
Property and Equipment
Property and Equipment	Note 5. Property and Equipment Property and equipment consisted of the following (in thousands): March 31, December 31, 2017 2016 Buildings and improvements $ 994,236 $ 984,373 Land 411,777 418,025 Fixtures and equipment 41,304 40,354 Idle plant assets 30,500 30,500 Construction in process 33,129 42,069 Capitalized internal use software 20,097 20,097 Total property and equipment 1,531,043 1,535,418 Less accumulated depreciation 456,578 435,519 Total $ 1,074,465 $ 1,099,899 Property and equipment includes assets held for sale of $11.9 million and $17.5 million at March 31, 2017 and December 31, 2016, respectively (see Note 5). See Note 21 for assets held for sale recognized subsequent to March 31, 2017. At March 31, 2017, the Partnership had a $61.5 million remaining net book value of long-lived assets at its West Coast facility, including $30.5 million related to the Partnership’s ethanol plant acquired in 2013. In 2016, the Partnership shifted the facility from crude oil to ethanol transloading and began transloading ethanol. The Partnership would need to take certain measures to prepare the facility for ethanol production in order to place the plant into service. Therefore, the $30.5 million related to the ethanol plant was included in property and equipment and classified as idle plant assets at March 31, 2017 and December 31, 2016. If the Partnership is unable to generate cash flows to support the recoverability of the plant and facility assets, this may become an indicator of potential impairment of the West Coast facility. Associated with the fair value appraisals determined by third-party valuation specialists in support of the Partnership’s 2016 step two goodwill impairment test, the Partnership received an estimated fair value for the West Coast facility significantly in excess of the $61.5 million remaining net book value. The estimated fair value obtained was based on market comparable transactions for sale of ethanol plant assets, both active and idle, at the time of sale. While the fair value analysis was not prepared or obtained to support the recoverability of the West Coast facility or idle plant assets, the Partnership does not believe that changes in assumptions would impact the estimated fair value such that it might result in a fair value estimate of the West Coast facility that would be less than the $61.5 million net book value at March 31, 2017. The Partnership will continue to monitor the market for ethanol, the continued business development of this facility for either ethanol or crude oil transloading, and the related impact this may have on the facility’s operating cash flows and whether this would constitute an impairment indicator.

Sales and Disposition of Assets

Sales and Disposition of Assets	3 Months Ended
	Mar. 31, 2017
Sales and Disposition of Assets
Sales and Dispositions of Assets	Note 6. Sales and Disposition of Assets The following table provides the Partnership’s (gain) loss on sale and dispositions of assets for the three months ended March 31, 2017 and 2016 (in thousands): Three Months Ended March 31, 2017 2016 Sale of natural gas brokerage and electricity businesses $ (14,172) $ — Periodic divestiture of gasoline stations (180) 579 Strategic asset divestiture program - Real estate firm coordinated sale 423 — Loss on assets held for sale 2,051 5,536 Other 16 (10) Net (gain) loss on sale and disposition of assets $ (11,862) $ 6,105 Sale of Natural Gas and Electricity Brokerage Businesses On February 1, 2017, the Partnership completed the sale of its natural gas marketing and electricity brokerage businesses for a purchase price of approximately $17.3 million, subject to customary closing adjustments. Proceeds from the sale amounted to approximately $16.3 million, and the Partnership realized a gain on the sale of $14.2 million. See Note 1. Periodic Divestiture of Gasoline Stations As part of the routine course of operations in the GDSO segment, the Partnership may periodically divest certain gasoline stations. The gain or loss on the sale, representing cash proceeds less net book value of assets and recognized liabilities at disposition, net of settlement and dispositions costs, is recorded in net (gain) loss on sale and disposition of assets in the accompanying consolidated statements of operations and amounted to a $0.2 million gain and a $0.6 million loss for the three months ended March 31, 2017 and 2016 respectively. Strategic Asset Divestiture Program The Partnership identified certain non-strategic GDSO sites that are part of its Strategic Asset Divestiture Program (the “Divestiture Program”). Real Estate Firm Coordinated Sale — The Partnership has retained a real estate firm to coordinate the sale of approximately 75 non-strategic GDSO sites as of March 31, 2017. Since the Divesture Program was implemented, the Partnership completed the sale of 45 of these sites, of which 16 sites were sold during the three month ended March 31, 2017. The gain or loss on the sale, representing cash proceeds less net book value of assets and recognized liabilities at disposition, net of settlement and dispositions costs, is recorded in net (gain) loss on sale and disposition of assets in the accompanying consolidated statement of operations and amounted to a $0.4 million loss for the three months ended March 31, 2017, including the derecognition of $2.0 million of GDSO goodwill. As of March 31, 2017, the criteria to be presented as held for sale was met for 22 of the remaining sites. Through April 2017, such criteria was met for one additional site (see Note 21). Loss on Assets Held for Sale In conjunction with the periodic divestiture of gasoline stations and the sale of sites within the Divestiture Program, the Partnership may classify certain gasoline station assets as held for sale. The Partnership classified 15 sites and 17 sites as held for sale at March 31, 2017 and December 31, 2016, respectively, which are periodic divestiture gasoline station sites. The Partnership recorded impairment charges related to these assets held for sale in the amount of $0.2 million and $5.5 million for the three months ended March 31, 2017 and 2016, respectively, which are included in net (gain) loss on sale and disposition of assets in the accompanying consolidated statements of operations. Additionally, the Partnership classified 22 sites associated with the real estate firm coordinated sale discussed above as held for sale at March 31, 2017. The Partnership recorded impairment charges related to these assets held for sale in the amount of $1.9 and million and $0 for the three months ended March 31, 2017 and 2016, respectively, which are included in net (gain) loss on sale and disposition of assets in the accompanying consolidated statements of operations. Assets held for sale of $11.9 million and $17.5 million at March 31, 2017 and December 31, 2016, respectively, are included in property and equipment in the accompanying balance sheets. Assets held for sale are expected to be sold within the next 12 months. Other The Partnership recognizes gains and losses on the sale and disposition of other assets, including vehicles, fixtures and equipment, and the gain or loss on such other assets are included in other in the aforementioned table.

Debt and Financing Obligations

Debt and Financing Obligations	3 Months Ended
	Mar. 31, 2017
Debt and Financing Obligations
Debt and Financing Obligations	Note 7. Debt and Financing Obligations Credit Agreement As of March 31, 2017, certain subsidiaries of the Partnership, as borrowers, and the Partnership and certain of its subsidiaries, as guarantors, had a $1.475 billion senior secured credit facility (the “Credit Agreement”) that was to mature on April 30, 2018. On April 25, 2017, the Partnership and certain of its subsidiaries entered into a third amended and restated credit agreement with aggregate commitments of $1.3 billion and a maturity date of April 30, 2020 (see “–Third Amended and Restated Credit Agreement” below). As of March 31, 2017, the two facilities under the Credit Agreement included: · a working capital revolving credit facility to be used for working capital purposes and letters of credit in the principal amount equal to the lesser of the Partnership’s borrowing base and $900.0 million; and · a $575.0 million revolving credit facility to be used for acquisitions, joint ventures, capital expenditures, letters of credit and general corporate purposes. In addition, the Credit Agreement had an accordion feature whereby the Partnership could request on the same terms and conditions of its then-existing credit agreement, provided no Event of Default (as defined in the Credit Agreement) existed, an increase to the working capital revolving credit facility, the revolving credit facility, or both, by up to another $300.0 million. In addition, the Credit Agreement included a swing line pursuant to which Bank of America, N.A., as the swing line lender, could 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 bore interest at the Base Rate (as defined in the Credit Agreement). The swing line was a sub-portion of the working capital revolving credit facility and was not an addition to the then total available commitments of $1.475 billion. The average interest rates for the Credit Agreement were 3.4% and 3.8% for the three months ended March 31, 2017 and 2016, respectively. The decline in the average interest rates is due to the May 2016 expiration of an interest rate swap. The Partnership classifies a portion of its working capital revolving credit facility as a current liability and a portion as a long-term liability. The portion classified as a long-term liability represents the amounts expected to be outstanding during the entire year based on an analysis of historical daily borrowings under the working capital revolving credit facility, the seasonality of borrowings, forecasted future working capital requirements and forward product curves, and because the Partnership has a multi-year, long-term commitment from its bank group. Accordingly, at March 31, 2017, the Partnership estimated working capital revolving credit facility borrowings will equal or exceed $150.0 million over the next twelve months and, therefore, classified $176.9 million as the current portion at March 31, 2017, representing the amount the Partnership expects to pay down over the next twelve months. The long-term portion of the working capital revolving credit facility was $150.0 million at each of March 31, 2017 and December 31, 2016, and the current portion was $176.9 million and $274.6 million at March 31, 2017 and December 31, 2016, respectively. The decrease in total borrowings under the working capital revolving credit facility of $97.7 million from December 31, 2016 was primarily due to decreases in accounts receivable and inventories, in part due to seasonality relating to the heating season, reduced inventory volume and a decline in prices. As of March 31, 2017, the Partnership had total borrowings outstanding under the Credit Agreement of $527.6 million, including $200.7 million outstanding on the revolving credit facility. In addition, the Partnership had outstanding letters of credit of $39.1 million. Subject to borrowing base limitations, the total remaining availability for borrowings and letters of credit was $908.3 million and $764.8 million at March 31, 2017 and December 31, 2016, respectively. The Credit Agreement was secured by substantially all of the assets of the Partnership and the Partnership’s wholly owned subsidiaries and was guaranteed by the Partnership and its subsidiaries with the exception of Basin Transload. The Credit Agreement imposed financial covenants that required 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, 2017. The Credit Agreement also contained 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 limited distributions by the Partnership to its unitholders to the amount of Available Cash (as defined in the Partnership’s partnership agreement). Third Amended and Restated Credit Agreement On April 25, 2017, the Partnership, its operating company, its operating subsidiaries and GLP Finance Corp. entered into a Third Amended and Restated Credit Agreement (the “Amended Credit Agreement”), with Aggregate Commitments (as defined in the Amended Credit Agreement) available in the amount of $1.3 billion. The Amended Credit Agreement will mature on April 30, 2020. There are two facilities under the Amended Credit Agreement: · a working capital revolving credit facility to be used for working capital purposes and letters of credit in the principal amount equal to the lesser of the Partnership’s borrowing base and $850.0 million; and · a $450.0 million revolving credit facility to be used for acquisitions, joint ventures, capital expenditures, letters of credit and general corporate purposes. In addition, the Amended Credit Agreement has an accordion feature whereby the borrowers may request on the same terms and conditions then applicable to the Amended Credit Agreement, provided no Event of Default (as defined in the Amended 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 $1.6 billion. Any such request for an increase by the borrowers must be in a minimum amount of $25.0 million. In addition, the Amended Credit Agreement includes a swing line pursuant to which Bank of America, N.A., as the swing line lender, may make swing line loans in U.S. dollars in an aggregate amount equal to the lesser of (a) $75.0 million and (b) the Aggregate WC Commitments (as defined in the Amended Credit Agreement). Swing line loans will bear interest at the Base Rate (as defined in the Amended 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 $1.3 billion. Borrowings under the Amended Credit Agreement are available in U.S. dollars and Canadian dollars. The aggregate amount of loans made under the Amended 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 Amended Credit Agreement, borrowings under the working capital revolving credit facility cannot exceed the then current borrowing base. Availability under the borrowing base may be affected by events beyond the Partnership’s control, such as changes in petroleum product prices, collection cycles, counterparty performance, advance rates and limits and general economic conditions. These and other events could require the Partnership to seek waivers or amendments of covenants or alternative sources of financing or to reduce expenditures. The Partnership can provide no assurance that such waivers, amendments or alternative financing could be obtained or, if obtained, would be on terms acceptable to the Partnership. Borrowings under the working capital revolving credit facility bear interest at (1) the Eurocurrency rate plus 2.00% to 2.50%, (2) the cost of funds rate plus 2.00% to 2.50%, or (3) the base rate plus 1.00% to 1.50%, each depending on the Utilization Amount (as defined in the Amended Credit Agreement). Borrowings under the revolving credit facility bear interest at (1) the Eurocurrency rate plus 2.00% to 3.00%, which was reduced from the Eurocurrency rate plus 2.25% to 3.50%, (2) the cost of funds rate plus 2.00% to 3.00%, which was reduced from the cost of funds rate plus 2.25% to 3.50%, or (3) the base rate plus 1.00% to 2.00% which was reduced from the base rate plus 1.25% to 2.50%, each depending on the Combined Total Leverage Ratio (as defined in the Amended Credit Agreement). The Amended 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 Amended 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 Amended Credit Agreement, ranging from 0.350% to 0.50% per annum. The Amended Credit Agreement is secured by substantially all of the assets of the Partnership and the Partnership’s wholly-owned subsidiaries and is guaranteed by the Partnership and its subsidiaries, Bursaw Oil LLC, Global Partners Energy Canada ULC, Warex Terminals Corporation, Drake Petroleum Company, Inc., Puritan Oil Company, Inc. and Maryland Oil Company, Inc. The Amended 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 Amended 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 Amended Credit Agreement also added (or increased as the case may be) certain baskets that were not included in the Credit Agreement, including: (i) a $25.0 million general secured indebtedness basket, (ii) a $25.0 million general investment basket, (iii) a $75.0 million secured indebtedness basket to permit the borrowers to enter into a Contango Facility (as defined in the Amended Credit Agreement), (i v) an increase in the Sale/Leaseback Transaction (as defined in the Amended Credit Agreement) basket from $75.0 million to $100.0 million, and (v) a basket of $50.0 million in an aggregate amount over the life of the Amended Credit Agreement for the purchase of common units of the Partnership, provided that no Event of Default exists or would occur immediately following such purchase(s). In addition, the Amended Credit Agreement provides the ability for borrowers to repay certain junior indebtedness, subject to a $100.0 million cap, so long as no Event of Default has occurred or will exist immediately after making such repayment. The Amended Credit Agreement imposes financial covenants that require the borrowers 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 Amended 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 Amended Credit Agreement). In addition, the Amended Credit Agreement limits distributions by the Partnership to its unitholders to the amount of Available Cash (as defined in the Partnership’s partnership agreement). Senior Notes The Partnership had 6.25% senior notes due 2022 and 7.00% senior notes due 2023 outstanding at March 31, 2017. Please read Note 6 of Notes to Consolidated Financial Statements in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2016 for additional information on these senior notes. Financing Obligations Capitol Acquisition On June 1, 2015, the Partnership acquired retail gasoline stations and dealer supply contracts from Capitol Petroleum Group (“Capitol”). In connection with the acquisition, the Partnership assumed a financing obligation of $89.6 million associated with two sale-leaseback transactions by Capitol for 53 leased sites that did not meet the criteria for sale accounting. During the term of these leases, which expire in May 2028 and September 2029, in lieu of recognizing lease expense for the lease rental payments, the Partnership incurs interest expense associated with the financing obligation. Interest expense of approximately $2.4 million was recorded for each of the three months ended March 31, 2017 and 2016, and is included in interest expense in the accompanying statements of operations. The financing obligation will amortize through expiration of the lease based upon the lease rental payments which were $2.4 million and $2.3 million for the three months ended March 31, 2017 and 2016, respectively. The financing obligation balance outstanding at March 31, 2017 was $89.9 million associated with the Capitol acquisition. Sale Leaseback Transaction On June 29, 2016, the Partnership sold to a premier institutional real estate investor (the “Buyer”) real property assets, including the buildings, improvements and appurtenances thereto, at 30 gasoline stations and convenience stores located in Connecticut, Maine, Massachusetts, New Hampshire and Rhode Island (the “Sale Leaseback Sites”) for a purchase price of approximately $63.5 million. In connection with the sale, the Partnership entered into a Master Unitary Lease Agreement with the Buyer to lease back the real property assets sold with respect to the Sale Leaseback Sites (such Master Lease Agreement, together with the Sale Leaseback Sites, the “Sale Leaseback Transaction”). The Master Unitary Lease Agreement provides for an initial term of fifteen years that expires in 2031. The Partnership has one successive option to renew the lease for a ten-year period followed by two successive options to renew the lease for five-year periods on the same terms, covenants, conditions and rental as the primary non-revocable lease term. The Partnership does not have any residual interest nor the option to repurchase any of the sites at the end of the lease term. The proceeds from the Sale Leaseback Transaction were used to reduce indebtedness outstanding under the Partnership’s revolving credit facility. The sale did not meet the criteria for sale accounting as of March 31, 2017 due to prohibited continuing involvement. Specifically, the sale is considered a partial-sale transaction, which is a form of continuing involvement as the Partnership did not transfer to the Buyer the storage tank systems which are considered integral equipment of the Sale Leaseback Sites. Additionally, a portion of the sold sites have material sub-lease arrangements, which is also a form of continuing involvement. As the sale of the Sale-Leaseback Sites did not meet the criteria for sale accounting, the Partnership did not recognize a gain or loss on the sale of the Sale Leaseback Sites for the three months ended March 31, 2017. As a result of not meeting the criteria for sale accounting for these sites, the Sale Leaseback Transaction is accounted for as a financing arrangement. As such, the property and equipment sold and leased back by the Partnership has not been derecognized and continues to be depreciated. The Partnership recognized a corresponding financing obligation of $62.5 million equal to the $63.5 million cash proceeds received for the sale of these sites, net of $1.0 million financing fees. During the term of the lease, which expires in June 2031, in lieu of recognizing lease expense for the lease rental payments, the Partnership incurs interest expense associated with the financing obligation. Lease rental payments are recognized as both interest expense and a reduction of the principal balance associated with the financing obligation. Interest expense and lease rental payments were $1.1 million for the three months ended March 31, 2017. The financing obligation balance outstanding at March 31, 2017 was $62.5 million associated with the Sale Leaseback Transaction. Deferred Financing Fees The Partnership incurs bank fees related to its Credit Agreement and other financing arrangements. These deferred financing fees are capitalized and amortized over the life of the Credit Agreement or other financing arrangements. The Partnership had unamortized deferred financing fees of $12.5 million and $14.1 million at March 31, 2017 and December 31, 2016, respectively. Unamortized fees related to the Credit Agreement are included in other current assets and other long-term assets and amounted to $5.3 million and $6.5 million at March 31, 2017 and December 31, 2016, respectively. Unamortized fees related to the senior notes are presented as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts, and amounted to $6.3 million and $6.6 million at March 31, 2017 and December 31, 2016, respectively. Unamortized fees related to the Sale-Leaseback Transaction are presented as a direct deduction from the carrying amount of the financing obligation and amounted to $0.9 million and $1.0 million at March 31, 2017 and December 31, 2016, respectively. On February 24, 2016, the Partnership voluntarily elected to reduce its working capital revolving credit facility from $1.0 billion to $900.0 million and its revolving credit facility from $775.0 million to $575.0 million. As a result, the Partnership incurred expenses of approximately $1.8 million associated with the write-off of a portion of its deferred financing fees. These expenses are included in interest expense in the accompanying statement of operations for the three months ended March 31, 2016. Amortization expense of approximately $1.5 million and $1.4 million for the three months ended March 31, 2017 and 2016, respectively, is included in interest expense in the accompanying consolidated statements of operations.

Derivative Financial Instrument

Derivative Financial Instruments	3 Months Ended
	Mar. 31, 2017
Derivative Financial Instruments
Derivative Financial Instruments	Note 8. Derivative Financial Instruments The Partnership principally uses derivative instruments, which include regulated exchange-traded futures and options contracts (collectively, “exchange-traded derivatives”) and physical and financial forwards and over-the-counter (“OTC”) swaps (collectively, “OTC derivatives”), to reduce its exposure to unfavorable changes in commodity market prices and interest rates. The Partnership uses these exchange-traded and OTC derivatives to hedge commodity price risk associated with its inventory and undelivered forward commodity purchases and sales (“physical forward contracts”) and uses interest rate swap instruments to reduce its exposure to fluctuations in interest rates associated with the Partnership’s credit facilities. The Partnership accounts for derivative transactions in accordance with ASC Topic 815, “Derivatives and Hedging,” and recognizes derivatives instruments as either assets or liabilities in the consolidated balance sheet and measures those instruments at fair value. The changes in fair value of the derivative transactions are presented currently in earnings, unless specific hedge accounting criteria are met. The fair value of exchange-traded derivative transactions reflects amounts that would be received from or paid to the Partnership’s brokers upon liquidation of these contracts. The fair value of these exchange-traded derivative transactions are presented on a net basis, offset by the cash balances on deposit with the Partnership’s brokers, presented as brokerage margin deposits in the consolidated balance sheets. The fair value of OTC derivative transactions reflects amounts that would be received from or paid to a third party upon liquidation of these contracts under current market conditions. The fair value of these OTC derivative transactions is presented on a gross basis as derivative assets or derivative liabilities in the consolidated balance sheets, unless a legal right of offset exists. The presentation of the change in fair value of the Partnership’s exchange-traded derivatives and OTC derivative transactions depends on the intended use of the derivative and the resulting designation. The following table summarizes the notional values related to the Partnership’s derivative instruments outstanding at March 31, 2017: Units (1) Unit of Measure Exchange-Traded Derivatives Long 66,871 Thousands of barrels Short (72,498) Thousands of barrels OTC Derivatives (Petroleum/Ethanol) Long 6,928 Thousands of barrels Short (3,562) Thousands of barrels Interest Rate Swap $ 100.0 Millions of U.S. dollars (1) Number of open positions and gross notional values do not measure the Partnership’s risk of loss, quantify risk or represent assets or liabilities of the Partnership, but rather indicate the relative size of the derivative instruments and are used in the calculation of the amounts to be exchanged between counterparties upon settlements. Derivatives Accounted for as Hedges The Partnership utilizes fair value hedges and cash flow hedges to hedge commodity price risk and interest rate risk. Fair Value Hedges Derivatives designated as fair value hedges are used to hedge price risk in commodity inventories and principally include exchange-traded futures contracts that are entered into in the ordinary course of business. For a derivative instrument designated as a fair value hedge, the gain or loss is recognized in earnings in the period of change together with the offsetting change in fair value on the hedged item of the risk being hedged. Gains and losses related to fair value hedges are recognized in the consolidated statement of operations through cost of sales. These futures contracts are settled on a daily basis by the Partnership through brokerage margin accounts. The Partnership’s fair value hedges include exchange-traded futures contracts and OTC derivative contracts that are hedges against inventory with specific futures contracts matched to specific barrels. The change in fair value of these futures contracts and the change in fair value of the underlying inventory generally provide an offset to each other in the consolidated statement of operations. The following table presents the gains and losses from the Partnership’s derivative instruments involved in fair value hedging relationships recognized in the consolidated statements of operations for the three months ended March 31, 2017 and 2016 (in thousands): Statement of Gain (Loss) Three Months Ended Recognized in Income on March 31, Derivatives 2017 2016 Derivatives in fair value hedging relationship Exchange-traded futures contracts and OTC derivative contracts for petroleum commodity products Cost of sales $ 20,696 $ 27,839 Hedged items in fair value hedge relationship Physical inventory Cost of sales $ (20,845) $ (24,175) Cash Flow Hedges At March 31 2017, the Partnership had in place one interest rate swap agreement which is hedging $100.0 million of variable rate debt and continues to be accounted for as a cash flow hedge. The amount of gain (loss) recognized in other comprehensive income as effective for derivatives designated in cash flow hedging relationships was $398,000 and $28,000 for the three months ended March 31, 2017 and 2016, respectively. The amount of gain (loss) recognized in income as ineffectiveness for derivatives designated in cash flow hedging relationships was $0 for the three months ended March 31, 2017 and 2016. Derivatives Not Accounted for as Hedges The Partnership utilizes petroleum and ethanol commodity contracts, natural gas commodity contracts and foreign currency derivatives to hedge price and currency risk in certain commodity inventories and physical forward contracts. Petroleum and Ethanol Commodity Contracts The Partnership uses exchange-traded derivative contracts to hedge price risk in certain commodity inventories which do not qualify for fair value hedge accounting or are not designated by the Partnership as fair value hedges. Additionally, the Partnership uses exchange-traded derivative contracts, and occasionally financial forward and OTC swap agreements, to hedge commodity price exposure associated with its physical forward contracts which are not designated by the Partnership as cash flow hedges. These physical forward contracts, to the extent they meet the definition of a derivative, are considered OTC physical forwards and are reflected as derivative assets or derivative liabilities in the consolidated balance sheet. The related exchange-traded derivative contracts (and financial forward and OTC swaps, if applicable) are also reflected as brokerage margin deposits (and derivative assets or derivative liabilities, if applicable) in the consolidated balance sheet, thereby creating an economic hedge. Changes in fair value of these derivative instruments are recognized in the consolidated statement of operations through cost of sales. These exchange-traded derivatives are settled on a daily basis by the Partnership through brokerage margin accounts. While the Partnership seeks to maintain a position that is substantially balanced within its commodity product purchase and sale activities, it may experience net unbalanced positions for short periods of time as a result of variances in daily purchases and sales and transportation and delivery schedules as well as other logistical issues inherent in the business, such as weather conditions. In connection with managing these positions, the Partnership is aided by maintaining a constant presence in the marketplace. The Partnership also engages in a controlled trading program for up to an aggregate of 250,000 barrels of commodity products at any one point in time. Changes in fair value of these derivative instruments are recognized in the consolidated statement of operations through cost of sales. The following table presents the gains and losses from the Partnership’s derivative instruments not involved in a hedging relationship recognized in the consolidated statements of operations for the three months ended March 31, 2017 and 2016 (in thousands): Statement of Gain (Loss) Three Months Ended Derivatives not designated as Recognized in March 31, hedging instruments Income on Derivatives 2017 2016 Commodity contracts Cost of sales $ 1,554 $ (415) Forward foreign currency contracts Cost of sales — 39 Total $ 1,554 $ (376) Margin Deposits All of the Partnership’s exchange-traded derivative contracts (designated and not designated) are transacted through clearing brokers. The Partnership deposits initial margin with the clearing brokers, along with variation margin, which is paid or received on a daily basis, based upon the changes in fair value of open futures contracts and settlement of closed futures contracts. Cash balances on deposit with clearing brokers and open equity are presented on a net basis within brokerage margin deposits in the consolidated balance sheets. Commodity Contracts and Other Derivative Activity The Partnership’s commodity contracts and other derivative activity include: (i) exchange-traded derivative contracts that are hedges against inventory and either do not qualify for hedge accounting or are not designated in a hedge accounting relationship, (ii) exchange-traded derivative contracts used to economically hedge physical forward contracts, (iii) financial forward and OTC swap agreements used to economically hedge physical forward contracts and (iv) the derivative instruments under the Partnership’s controlled trading program. The Partnership does not take the normal purchase and sale exemption available under ASC 815 for its physical forward contracts. The following table presents the fair value of each classification of the Partnership’s derivative instruments and its location in the consolidated balance sheets at March 31, 2017 and December 31, 2016 (in thousands): March 31, 2017 Derivatives Derivatives Not Designated as Designated as Hedging Hedging Balance Sheet Location Instruments Instruments Total Asset Derivatives: Exchange-traded derivative contracts Broker margin deposits $ 4,006 $ 23,218 $ 27,224 Forward derivative contracts (1) Derivative assets — 2,720 2,720 Total asset derivatives $ 4,006 $ 25,938 $ 29,944 Liability Derivatives: Exchange-traded derivative contracts Broker margin deposits $ (6,282) $ (33,071) $ (39,353) Forward derivative contracts (1) Derivative liabilities — (4,986) (4,986) Interest rate swap contracts Other long-term liabilities — (773) (773) Total liability derivatives $ (6,282) $ (38,830) $ (45,112) December 31, 2016 Derivatives Derivatives Not Designated as Designated as Hedging Hedging Balance Sheet Location Instruments Instruments Total Asset Derivatives: Exchange-traded derivative contracts Broker margin deposits $ — $ 60,018 $ 60,018 Forward derivative contracts (1) Derivative assets — 21,382 21,382 Total asset derivatives $ — $ 81,400 $ 81,400 Liability Derivatives: Exchange-traded derivative contracts Broker margin deposits $ (33,877) $ (96,831) $ (130,708) Forward derivative contracts (1) Derivative liabilities — (27,413) (27,413) Interest rate swap contracts Other long-term liabilities — (1,170) (1,170) Total liability derivatives $ (33,877) $ (125,414) $ (159,291) (1) Forward derivative contracts include the Partnership’s petroleum and ethanol physical and financial forwards and OTC swaps. Credit Risk The Partnership’s derivative financial instruments do not contain credit risk related to other contingent features that could cause accelerated payments when these financial instruments are in net liability positions. The Partnership is exposed to credit loss in the event of nonperformance by counterparties to the Partnership’s exchange-traded and OTC derivative contracts, but the Partnership has no current reason to expect any material nonperformance by any of these counterparties. Exchange-traded derivative contracts, the primary derivative instrument utilized by the Partnership, are traded on regulated exchanges, greatly reducing potential credit risks. The Partnership utilizes primarily three clearing brokers, all major financial institutions, for all New York Mercantile Exchange (“NYMEX”), Chicago Mercantile Exchange (“CME”) and Intercontinental Exchange (“ICE”) derivative transactions and the right of offset exists with these financial institutions under master netting agreements. Accordingly, the fair value of the Partnership’s exchange-traded derivative instruments is presented on a net basis in the consolidated balance sheets. Exposure on OTC derivatives is limited to the amount of the recorded fair value as of the balance sheet dates.

Fair Value Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2017
Fair Value Measurements
Fair Value Measurements	Note 9. Fair Value Measurements The following tables present, by level within the fair value hierarchy, the Partnership’s financial assets and liabilities that were measured at fair value on a recurring basis as of March 31, 2017 and December 31, 2016 (in thousands): Fair Value at March 31, 2017 Cash Collateral Level 1 Level 2 Level 3 Netting Total Assets: Forward derivative contracts (1) $ — $ 2,199 $ 313 $ — $ 2,512 Swap agreements and options — 208 — — 208 Exchange-traded/cleared derivative instruments (2) (12,128) — — 31,014 18,886 Pension plans 17,199 — — — 17,199 Total assets $ 5,071 $ 2,407 $ 313 $ 31,014 $ 38,805 Liabilities: Forward derivative contracts (1) $ — $ (4,438) $ (427) $ — $ (4,865) Swap agreements and options — (121) — — (121) Interest rate swaps — (773) — — (773) Total liabilities $ — $ (5,332) $ (427) $ — $ (5,759) Fair Value at December 31, 2016 Cash Collateral Level 1 Level 2 Level 3 Netting Total Assets: Forward derivative contracts (1) $ — $ 18,972 $ 1,683 $ — $ 20,655 Swap agreements and options — 727 — — 727 Exchange-traded/cleared derivative instruments (2) (70,690) — — 98,344 27,654 Pension plans 16,777 — — — 16,777 Total assets $ (53,913) $ 19,699 $ 1,683 $ 98,344 $ 65,813 Liabilities: Forward derivative contracts (1) $ — $ (25,097) $ (2,054) $ — $ (27,151) Swap agreements and options — (262) — — (262) Interest rate swaps — (1,170) — — (1,170) Total liabilities $ — $ (26,529) $ (2,054) $ — $ (28,583) (1) Forward derivative contracts include the Partnership’s petroleum and ethanol physical and financial forwards and OTC swaps. (2) Amount includes the effect of cash balances on deposit with clearing brokers. This table excludes cash on hand and assets and liabilities that are measured at historical cost or any basis other than fair value. The carrying amounts of certain of the Partnership’s financial instruments, including cash equivalents, accounts receivable, accounts payable and other accrued liabilities approximate fair value due to their short maturities. The carrying value of the credit facility approximates fair value due to the variable rate nature of these financial instruments. The carrying value of the inventory qualifying for fair value hedge accounting approximates fair value due to adjustments for changes in fair value of the hedged item. The fair values of the derivatives used by the Partnership are disclosed in Note 8. The determination of the fair values above incorporates factors including not only the credit standing of the counterparties involved, but also the impact of the Partnership’s nonperformance risks on its liabilities. The Partnership estimates the fair values of its 6.25% senior notes and 7.00% senior notes using a combination of quoted market prices for similar financing arrangements and expected future payments discounted at risk-adjusted rates, which are considered Level 2 inputs. The fair values of the 6.25% senior notes and 7.00% senior notes, estimated by observing market trading prices of the 6.25% senior notes and 7.00% senior notes, respectively, were as follows (in thousands): March 31, 2017 December 31, 2016 Face Fair Face Fair Value Value Value Value 6.25% senior notes $ 375,000 $ 367,500 $ 375,000 $ 361,163 7.00% senior notes $ 300,000 $ 297,000 $ 300,000 $ 289,500 Level 3 Information The values of the Level 3 derivative contracts were calculated using market approaches based on a combination of observable and unobservable market inputs, including published and quoted NYMEX, CME, ICE, New York Harbor and third-party pricing information for a component of the underlying instruments as well as internally developed assumptions where there is little, if any, published or quoted prices or market activity. The unobservable inputs used in the measurement of the Level 3 derivative contracts include estimates for location basis, transportation and throughput costs net of an estimated margin for current market participants. The estimates for these inputs for crude oil were $0.20 to $4.90 per barrel and $4.05 to $6.50 per barrel as of March 31, 2017 and December 31, 2016, respectively. The estimates for these inputs for propane were $0 to $9.24 per barrel and $4.20 to $10.50 per barrel as of March 31, 2017 and December 31, 2016, respectively. Gains and losses recognized in earnings (or changes in net assets) are disclosed in Note 8. Sensitivity of the fair value measurement to changes in the significant unobservable inputs is as follows: Significant Impact on Fair Value Unobservable Input Position Change to Input Measurement Location basis Long Increase (decrease) Gain (loss) Location basis Short Increase (decrease) Loss (gain) Transportation Long Increase (decrease) Gain (loss) Transportation Short Increase (decrease) Loss (gain) Throughput costs Long Increase (decrease) Gain (loss) Throughput costs Short Increase (decrease) Loss (gain) The following table presents a reconciliation of changes in fair value of the Partnership’s derivative contracts classified as Level 3 in the fair value hierarchy at March 31, 2017 (in thousands): Fair value at December 31, 2016 $ (371) Derivatives entered into during the period (192) Derivatives sold during the period 183 Realized gains (losses) recorded in cost of sales 648 Unrealized gains (losses) recorded in cost of sales (382) Fair value at March 31, 2017 $ (114) The Partnership’s policy is to recognize transfers between levels with the fair value hierarchy as of the beginning of the reporting period. The Partnership also excludes any activity for derivative instruments that were not classified as Level 3 at either the beginning or end of the reporting period. Non-Recurring Fair Value Measures Certain nonfinancial assets and liabilities are measured at fair value on a non-recurring basis and are subject to fair value adjustments in certain circumstances, such as acquired assets and liabilities, losses related to firm non-cancellable purchase commitments or long-lived assets subject to impairment. For assets and liabilities measured on a non-recurring basis during the period, accounting guidance requires quantitative disclosures about the fair value measurements separately for each major category. See Note 6 for a discussion of the Partnership’s losses on impairment of assets and Note 5 for assets held for sale.

Environmental Liabilities, Asse

Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers	3 Months Ended
	Mar. 31, 2017
Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers (RINs)
Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers (RINs)	Note 10. Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers Environmental Liabilities The following table presents a summary roll forward of the Partnership’s environmental liabilities at March 31, 2017 (in thousands): Balance at Other Balance at December 31, Payments in Dispositions Adjustments March 31, Environmental Liability Related to: 2016 2017 2017 2017 2017 Retail gasoline stations $ 58,456 $ (813) $ (1,050) $ (725) $ 55,868 Terminals 4,609 (33) — — 4,576 Total environmental liabilities $ 63,065 $ (846) $ (1,050) $ (725) $ 60,444 Current portion $ 5,341 $ 5,339 Long-term portion 57,724 55,105 Total environmental liabilities $ 63,065 $ 60,444 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 divestitures of sites and the possibility of existing legal claims giving rise to additional claims. Dispositions generally represent relief of legal obligations through the sale of the related property with no retained obligation. Other adjustments generally represent changes in estimates for existing obligations or obligations associated with new sites. Therefore, although the Partnership believes that these environmental liabilities are adequate, no assurances can be made that any costs incurred in excess of these environmental liabilities or outside of indemnifications or not otherwise covered by insurance would not have a material adverse effect on the Partnership’s financial condition, results of operations or cash flows. Asset Retirement Obligations The Partnership is required to account for the legal obligations associated with the long-lived assets that result from the acquisition, construction, development or operation of long-lived assets. Such asset retirement obligations specifically pertain to the treatment of underground gasoline storage tanks (“USTs”) that exist in those states which statutorily require removal of the USTs at a certain point in time. Specifically, the Partnership’s retirement obligations consist of the estimated costs of removal and disposals of USTs. The liability for an asset retirement obligation is recognized on a discounted basis in the year in which it is incurred, and the discount period applied is based on statutory requirements for UST removal or policy. The associated asset retirement costs are capitalized as part of the carrying cost of the asset. The Partnership had approximately $7.8 million and $8.3 million in total asset retirement obligations at March 31, 2017 and December 31, 2016, respectively, which are included in other long-term liabilities in the accompanying balance sheets. Renewable Identification Numbers (RINs) A RIN is a serial number assigned to a batch of renewable fuel for the purpose of tracking its production, use and trading as required by the U.S. Environmental Protection Agency’s (“EPA”) Renewable Fuel Standard that originated with the Energy Policy Act of 2005 and modified by the Energy Independence and Security Act of 2007. To evidence that the required volume of renewable fuel is blended with gasoline and diesel motor vehicle fuels, obligated parties must retire sufficient RINs to cover their Renewable Volume Obligation (“RVO”). The Partnership’s EPA obligations relative to renewable fuel reporting are largely limited to the foreign gasoline and diesel that the Partnership may choose to import and a small amount of blending operations at certain facilities. As a wholesaler of transportation fuels through its terminals, the Partnership separates RINs from renewable fuel through blending with gasoline and can use those separated RINs to settle its RVO. While the annual compliance period for the RVO is a calendar year and the settlement of the RVO typically occurs by March 31 of the following year, the settlement of the RVO can occur, under certain EPA deferral actions, more than one year after the close of the compliance period. The Partnership’s Wholesale segment’s operating results may be sensitive to the timing associated with its RIN position relative to its RVO at a point in time, and the Partnership may recognize a mark-to-market liability for a shortfall in RINs at the end of each reporting period. To the extent that the Partnership does not have a sufficient number of RINs to satisfy the RVO as of the balance sheet date, the Partnership charges cost of sales for such deficiency based on the market price of the RINs as of the balance sheet date and records a liability representing the Partnership’s obligation to purchase RINs. The Partnership’s RVO deficiency was immaterial at March 31, 2017 and $0.2 million at December 31, 2016. The Partnership may enter into RIN forward purchase and sales commitments. Total losses from firm non-cancellable commitments at March 31, 2017 and December 31, 2016 were immaterial.

Related Party Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2017
Related Party Transactions
Related Party Transactions	Note 11. Related Party Transactions The Partnership is a party to a Second Amended and Restated Services Agreement with Global Petroleum Corp. (“GPC”), an affiliate of the Partnership that is 100% owned by members of the Slifka family, pursuant to which the Partnership provides GPC with certain tax, accounting, treasury, legal, information technology, human resources and financial operations support services for which GPC pays the Partnership a monthly services fee at an agreed amount subject to the approval by the Conflicts Committee of the board of directors of the General Partner. The Second Amended and Restated Services Agreement is for an indefinite term and any party may terminate some or all of the services upon ninety (90) days’ advanced written notice. As of March 31, 2017, no such notice of termination was given by GPC. The General Partner employs substantially all of the Partnership’s employees, except for most of its gasoline station and convenience store employees, who are employed by GMG. The Partnership reimburses the General Partner for expenses incurred in connection with these employees. These expenses, including payroll, payroll taxes and bonus accruals, were $24.6 million and $25.7 million for the three months ended March 31, 2017 and 2016, respectively. The Partnership also reimburses the General Partner for its contributions under the General Partner’s 401(k) Savings and Profit Sharing Plans and the General Partner’s qualified and non-qualified pension plans. The table below presents receivables from GPC and the General Partner (in thousands): March 31, December 31, 2017 2016 Receivables from GPC $ 72 $ 6 Receivables from the General Partner (1) 2,885 3,137 Total $ 2,957 $ 3,143 (1) Receivables from the General Partner reflect the Partnership’s prepayment of payroll taxes and payroll accruals to the General Partner.

Long-Term Incentive Plan

Long-Term Incentive Plan	3 Months Ended
	Mar. 31, 2017
Long-Term Incentive Plan
Long-Term Incentive Plan	Note 12. Long-Term Incentive Plan The Partnership has a Long Term Incentive Plan, as amended (the “LTIP”), whereby a total of 4,300,000 common units were authorized for delivery with respect to awards under the LTIP. The LTIP provides for awards to employees, consultants and directors of the General Partner and employees and consultants of affiliates of the Partnership who perform services for the Partnership. The LTIP allows for the award of options, unit appreciation rights, restricted units, phantom units, distribution equivalent rights, unit awards and substitute awards. Awards granted pursuant to the LTIP vest pursuant to the terms of the grant agreements. Please read Note 15 of Notes to Consolidated Financial Statements in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2016 for additional information on the LTIP. The following table presents a summary of the status of the non-vested phantom units: Weighted Number of Average Non-vested Grant Date Units Fair Value ($) Outstanding non—vested units at December 31, 2016 571,554 38.56 Vested (10,659) 35.94 Forfeited (51,203) 38.19 Outstanding non—vested units at March 31, 2017 509,692 38.66 The Partnership recorded total compensation expense related to the outstanding awards of $1.1 million for each of the three months ended March 31, 2017 and 2016, which is included in selling, general and administrative expenses in the accompanying consolidated statements of operations. During the quarter ended March 31, 2017, a total of 51,203 phantom units were forfeited, the majority of which are related to phantom unit awards granted in 2013. As the Partnership’s assumption for forfeitures at the time of grant was zero based on service history, the Partnership reversed compensation expenses related to the forfeitures in the amount of $1.2 million which is included in selling, general and administrative expenses in the accompanying consolidated statement of operations for the three months ended March 31, 2017. The total compensation cost related to the non-vested awards not yet recognized at March 31, 2017 was approximately $8.1 million and is expected to be recognized ratably over the remaining requisite service periods. Repurchase Program In May 2009, the board of directors of the General Partner authorized the repurchase of the Partnership’s common units (the “Repurchase Program”) for the purpose of meeting the General Partner’s anticipated obligations to deliver common units under the LTIP and meeting the General Partner’s obligations under existing employment agreements and other employment related obligations of the General Partner (collectively, the “General Partner’s Obligations”). The General Partner is authorized to acquire up to 1,242,427 of its common units in the aggregate over an extended period of time, consistent with the General Partner’s Obligations. Common units may be repurchased from time to time in open market transactions, including block purchases, or in privately negotiated transactions. Such authorized unit repurchases may be modified, suspended or terminated at any time and are subject to price and economic and market conditions, applicable legal requirements and available liquidity. Since the Repurchase Program was implemented, the General Partner repurchased 838,505 common units pursuant to the Repurchase Program for approximately $24.8 million, none of which were purchased during the three months ended March 31, 2017 and 2016.

Partners' Equity and Cash Distr

Partners' Equity and Cash Distributions	3 Months Ended
	Mar. 31, 2017
Partners' Equity and Cash Distribution
Partners' Equity and Cash Distributions	Note 13. Partners’ Equity and Cash Distributions Partners’ Equity Partners’ equity at March 31, 2017 consisted of 33,995,563 common units issued, including 7,433,829 common units held by affiliates of the General Partner, including directors and executive officers, collectively representing a 99.33% limited partner interest in the Partnership, and 230,303 general partner units representing a 0.67% general partner interest in the Partnership. There have been no changes to partners’ equity during the three months ended March 31, 2017. Cash Distributions The Partnership intends to make cash distributions to unitholders on a quarterly basis, although there is no assurance as to the future cash distributions since they are dependent upon future earnings, capital requirements, financial condition and other factors. The Amended Credit Agreement prohibits the Partnership from making cash distributions if any potential default or Event of Default, as defined in the Amended Credit Agreement, occurs or would result from the cash distribution. The indentures governing the Partnership’s outstanding senior notes also limit the Partnership’s ability to make distributions to its unitholders in certain circumstances. Within 45 days after the end of each quarter, the Partnership will distribute all of its Available Cash (as defined in its partnership agreement) to unitholders of record on the applicable record date. The amount of Available Cash is all cash on hand on the date of determination of Available Cash for the quarter, less the amount of cash reserves established by the General Partner to provide for the proper conduct of the Partnership’s business, to comply with applicable law, any of the Partnership’s debt instruments, or other agreements or to provide funds for distributions to unitholders and the General Partner for any one or more of the next four quarters. The Partnership will make distributions of Available Cash from distributable cash flow for any quarter in the following manner: 99.33% to the common unitholders, pro rata, and 0.67% to the General Partner, until the Partnership distributes for each outstanding common unit an amount equal to the minimum quarterly distribution for that quarter; and thereafter, cash in excess of the minimum quarterly distribution is distributed to the unitholders and the General Partner based on the percentages as provided below. As holder of the IDRs, the General Partner is entitled to incentive distributions if the amount that the Partnership distributes with respect to any quarter exceeds specified target levels shown below: Marginal Percentage Total Quarterly Distribution Interest in Distributions Target Amount Unitholders General Partner First Target Distribution up to $0.4625 99.33 % 0.67 % Second Target Distribution above $0.4625 up to $0.5375 86.33 % 13.67 % Third Target Distribution above $0.5375 up to $0.6625 76.33 % 23.67 % Thereafter above $0.6625 51.33 % 48.67 % The Partnership paid the following cash distribution during 2017 (in thousands, except per unit data): Earned for the Per Unit Cash Distribution Quarter Cash Common General Incentive Total Cash Payment Date Ended Distribution Units Partner Distribution Distribution 2/14/2017 12/31/16 $ $ 15,723 $ 106 $ — $ 15,829 In addition, on April 28, 2017, the board of directors of the General Partner declared a quarterly cash distribution of $0.4625 per unit ($1.85 per unit on an annualized basis) on all of its outstanding common units for the period from January 1, 2017 through March 31, 2017. On May 15, 2017, the Partnership will pay this cash distribution to its unitholders of record as of the close of business on May 10, 2017.

Unitholders' Equity

Unitholders' Equity	3 Months Ended
	Mar. 31, 2017
Unitholders' Equity
Unitholders' Equity	Note 14. Unitholders’ Equity At-the-Market Offering Program On May 19, 2015, the Partnership entered into an equity distribution agreement pursuant to which the Partnership may sell from time to time through its sales agents, following a standard due diligence effort, the Partnership’s common units having an aggregate offering price of up to $50.0 million. Sales of the common units, if any, will be made by any method permitted by law deemed to be an “at-the-market” offering, including ordinary brokers’ transactions through the facilities of the New York Stock Exchange, to or through a market maker, or directly on or through an electronic communication network, a “dark pool” or any similar market venue, at market prices, in block transactions, or as otherwise agreed upon by the Partnership and one or more of its sales agents. The Partnership may also sell common units to one or more of its sales agents as principal for its own account at a price to be agreed upon at the time of sale. Any sale of common units to a sales agent as principal would be pursuant to the terms of a separate agreement between the Partnership and such sales agent. The Partnership intends to use the net proceeds from any sales pursuant to the at-the-market offering program, after deducting the sales agents’ commissions and the Partnership’s offering expenses, for general partnership purposes, which may include, among other things, repayment of indebtedness, acquisitions and capital expenditures. The sales agents and/or affiliates of each of the sales agents have, from time to time, performed, and may in the future perform, various financial advisory and commercial and investment banking services for the Partnership and its affiliates, for which they have received and in the future will receive customary compensation and expense reimbursement. Affiliates of the sales agents are lenders under the Partnership’s credit facility and, accordingly, may receive a portion of the net proceeds from this offering if and to the extent any proceeds are used to reduce outstanding borrowings under the Partnership’s credit facility. No common units have been sold by the Partnership pursuant to the at-the-market offering program since inception.

Segment Reporting

Segment Reporting	3 Months Ended
	Mar. 31, 2017
Segment Reporting
Segment Reporting	Note 15. Segment Reporting Summarized financial information for the Partnership’s reportable segments is presented in the table below (in thousands): Three Months Ended March 31, 2017 2016 Wholesale Segment: Sales Gasoline and gasoline blendstocks $ 505,704 $ 342,729 Crude oil (1) 103,528 148,502 Other oils and related products (2) 616,567 419,009 Total $ 1,225,799 $ 910,240 Product margin Gasoline and gasoline blendstocks $ 15,385 $ 16,362 Crude oil (1) 6,892 (2,373) Other oils and related products (2) 29,873 25,249 Total $ 52,150 $ 39,238 Gasoline Distribution and Station Operations Segment: Sales Gasoline $ 767,636 $ 616,103 Station operations (3) 75,596 85,185 Total $ 843,232 $ 701,288 Product margin Gasoline $ 67,155 $ 65,387 Station operations (3) 38,895 42,925 Total $ 106,050 $ 108,312 Commercial Segment: Sales $ 201,753 $ 139,284 Product margin $ 4,189 $ 6,910 Combined sales and Product margin: Sales $ 2,270,784 $ 1,750,812 Product margin (4) $ 162,389 $ 154,460 Depreciation allocated to cost of sales (22,362) (24,401) Combined gross profit $ 140,027 $ 130,059 (1) Crude oil consists of the Partnership’s crude oil sales and revenue from its logistics activities. (2) Other oils and related products primarily consist of distillates, residual oil and propane. (3) Station operations primarily consist of convenience store sales and rental income. (4) Product margin is a non-GAAP financial measure used by management and external users of the Partnership’s consolidated financial statements to assess its business. The table above includes a reconciliation of product margin on a combined basis to gross profit, a directly comparable GAAP measure. Approximately 113 million gallons and 111 million gallons of the GDSO segment’s sales for the three months ended March 31, 2017 and 2016, respectively, were supplied from petroleum products and renewable fuels sourced by the Wholesale segment. Except for natural gas, predominantly all of the Commercial segment’s sales are sourced by the Wholesale segment. These intra-segment sales are not reflected as sales in the Wholesale segment as they are eliminated. A reconciliation of the totals reported for the reportable segments to the applicable line items in the consolidated financial statements is as follows (in thousands): Three Months Ended March 31, 2017 2016 Combined gross profit $ 140,027 $ 130,059 Operating costs and expenses not allocated to operating segments: Selling, general and administrative expenses 36,787 34,984 Operating expenses 67,213 72,236 Amortization expense 2,261 2,509 Net (gain) loss on sale and disposition of assets (11,862) 6,105 Total operating costs and expenses 94,399 115,834 Operating income 45,628 14,225 Interest expense (23,287) (22,980) Income tax benefit 164 920 Net income (loss) 22,505 (7,835) Net loss attributable to noncontrolling interest 441 811 Net income (loss) attributable to Global Partners LP $ 22,946 $ (7,024) The Partnership’s foreign assets and foreign sales were immaterial as of and for the three months ended March 31, 2017 and 2016. Segment Assets The Partnership’s terminal assets are allocated to the Wholesale and Commercial segments, and its retail gasoline stations are allocated to the GDSO segment. Due to the commingled nature and uses of the remainder of the Partnership’s assets, it is not reasonably possible for the Partnership to allocate these assets among its reportable segments. The table below presents total assets by reportable segment at March 31, 2017 and December 31, 2016 (in thousands): Wholesale Commercial GDSO Unallocated Total March 31, 2017 $ 729,855 $ 125 $ 1,253,019 $ 345,330 $ 2,328,329 December 31, 2016 $ 830,662 $ 134 $ 1,294,568 $ 438,656 $ 2,564,020

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2017
Income Taxes
Income Taxes	Note 16. Income Taxes Section 7704 of the Internal Revenue Code provides that publicly-traded partnerships are, as a general rule, taxed as corporations. However, an exception, referred to as the “Qualifying Income Exception,” exists under Section 7704(c) with respect to publicly-traded partnerships of which 90% or more of the gross income for every taxable year consists of “qualifying income.” Qualifying income includes income and gains derived from the transportation, storage and marketing of refined petroleum products, crude oil and ethanol to resellers and refiners. Other types of qualifying income include interest (other than from a financial business), dividends, gains from the sale of real property and gains from the sale or other disposition of capital assets held for the production of income that otherwise constitutes qualifying income. Substantially all of the Partnership’s income is “qualifying income” for federal income tax purposes and, therefore, is not subject to federal income taxes at the partnership level. Accordingly, no provision has been made for income taxes on the qualifying income in the Partnership’s financial statements. Net income for financial statement purposes may differ significantly from taxable income reportable to unitholders as a result of differences between the tax basis and financial reporting basis of assets and liabilities and the taxable income allocation requirements under the Partnership’s agreement of limited partnership. Individual unitholders have different investment basis depending upon the timing and price at which they acquired their common units. Further, each unitholder’s tax accounting, which is partially dependent upon the unitholder’s tax position, differs from the accounting followed in the Partnership’s consolidated financial statements. Accordingly, the aggregate difference in the basis of the Partnership’s net assets for financial and tax reporting purposes cannot be readily determined because information regarding each unitholder’s tax attributes in the Partnership is not available to the Partnership. One of the Partnership’s wholly owned subsidiaries, GMG, is a taxable entity for federal and state income tax purposes. Current and deferred income taxes are recognized on the separate earnings of GMG. The after-tax earnings of GMG are included in the earnings of the Partnership. Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes for GMG. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. The Partnership calculates its current and deferred tax provision based on estimates and assumptions that could differ from actual results reflected in income tax returns filed in subsequent years. Adjustments based on filed returns are recorded when identified. On July 1, 2015 the Partnership commenced business in Canada through its wholly owned Canadian subsidiary, Global Partners Energy Canada ULC (“GPEC”). GPEC predominantly consists of sourcing crude oil and other petroleum based products for sale to the Partnership and customers in Canada. GPEC is a taxable entity for Canadian corporate income and branch taxes. In its first year of operations, GPEC realized a pre-tax loss generating a net operating loss that might be used to offset future taxable income when GPEC operates at a profit. The Partnership recognizes deferred tax assets to the extent that the recoverability of these assets satisfies the “more likely than not” recognition criteria in accordance with the accounting guidance regarding income taxes. Based upon projections of future taxable income, limited capital assets and market conditions, the Partnership has provided a full valuation allowance against the GPEC deferred tax asset. The Partnership recognizes deferred tax assets to the extent that the recoverability of these assets satisfies the “more likely than not” recognition criteria in accordance with the accounting guidance regarding income taxes. Based upon projections of future taxable income, the Partnership believes that the recorded deferred tax assets will be realized. The Partnership computed its tax provision for the three months ended March 31, 2017 based upon the year-to-date effective tax rate as opposed to an estimated annual effective tax rate. The Partnership concluded that the year-to-date effective tax rate is the most appropriate method to use for the three months ended March 31, 2017, given a reliable estimate of the annual effective tax rate cannot be made. Unrecognized tax benefits represent uncertain tax positions for which reserves have been established. As of March 31, 2017 and December 31, 2016, the Partnership had $1.4 million of unrecognized tax benefits, of which all would favorably impact the effective tax rate if recognized. GMG files income tax returns in the United States and various state jurisdictions. With few exceptions, the Partnership is subject to income tax examination by tax authorities for all years dated back to 2013.

Changes in Accumulated Other Co

Changes in Accumulated Other Comprehensive Loss	3 Months Ended
	Mar. 31, 2017
Changes in Accumulated Other Comprehensive Loss
Changes in Accumulated Other Comprehensive Loss	Note 17. Changes in Accumulated Other Comprehensive Loss The following table presents the changes in accumulated other comprehensive loss by component for the three months ended March 31, 2017 (in thousands): Pension Three Months Ended March 31, 2017 Plan Derivatives Total Balance at December 31, 2016 $ (4,269) $ (1,172) $ (5,441) Other comprehensive income before reclassifications of gain (loss) 346 398 744 Amount of (loss) gain reclassified from accumulated other comprehensive income (27) — (27) Total comprehensive income 319 398 717 Balance at March 31, 2017 $ (3,950) $ (774) $ (4,724) Amounts are presented prior to the income tax effect on other comprehensive income. Given the Partnership’s partnership status for federal income tax purposes, the effective tax rate is immaterial.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	3 Months Ended
	Mar. 31, 2017
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Note 18. Supplemental Cash Flow Information The following table presents cash flow supplemental information for the three months ended March 31, 2017 and 2016 (in thousands): Three Months Ended March 31, 2017 2016 Borrowings from working capital revolving credit facility $ 303,600 $ 418,200 Payments on working capital revolving credit facility (401,300) (331,100) Net (payments on) borrowings from working capital revolving credit facility $ (97,700) $ 87,100 Borrowings from revolving credit facility $ — $ 15,000 Payments on revolving credit facility (16,000) (8,900) Net (payments on) borrowings from revolving credit facility $ (16,000) $ 6,100

Legal Proceedings

Legal Proceedings	3 Months Ended
	Mar. 31, 2017
Legal Proceedings
Legal Proceedings	Note 19. 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 10 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 The Partnership determined that gasoline loaded from certain loading bays at one of its terminals did not contain the necessary additives as a result of an IT-related configuration error. The error was corrected and all gasoline being sold at the terminal now contains the appropriate additives. Based upon current information, the Partnership believes approximately 14 million gallons of gasoline were impacted. The Partnership has notified the EPA of this error. As a result of this error, the Partnership could be subject to fines, penalties and other related claims, including customer claims. In February 2016, the Partnership received a request for information from the EPA seeking certain information regarding its Albany terminal in order to assess its compliance with the Clean Air Act (the “CAA”). The information requested generally related to crude oil received by, stored at and shipped from the Partnership’s petroleum product transloading facility in Albany, New York (the “Albany Terminal”), including its composition, control devices for emissions and various permitting-related considerations. The Albany Terminal is a 63-acre licensed, permitted and operational stationary bulk petroleum storage and transfer terminal that currently consists of petroleum product storage tanks, along with truck, rail and marine loading facilities, for the storage, blending and distribution of various petroleum and related products, including gasoline, ethanol, distillates, heating and crude oils. No violations were alleged in the request for information. The Partnership submitted responses and documentation, in March and April 2016, to the EPA in accordance with the EPA request. On August 2, 2016, the Partnership received a Notice of Violation (“NOV”) from the EPA, alleging that permits for the Albany Terminal, issued by the New York State Department of Environmental Conservation (“NYSDEC”) between August 9, 2011 and November 7, 2012, violated the CAA and the federally enforceable New York State Implementation Plan (“SIP”) by increasing throughput of crude oil at the Albany Terminal without complying with the New Source Review (“NSR”) requirements of the SIP. The applicable permits issued by the NYSDEC to the Partnership in 2011 and 2012 specifically authorize the Partnership to increase the throughput of crude oil at the Albany Terminal. According to the allegations in the NOV, the NYSDEC permits should have been regulated as a major modification under the NSR program, requiring additional emission control measures and compliance with other NSR requirements. The NYSDEC has not alleged that the Partnership’s permits were subject to the NSR program. The CAA authorizes the EPA to take enforcement action in response to violations of the New York SIP seeking compliance and penalties. The Partnership believes that the permits issued by the NYSDEC comply with the CAA and applicable State air permitting requirements and that no material violation of law has occurred. The Partnership disputes the claims alleged in the NOV and responded to the EPA in September, 2016. The Partnership has met with the EPA and provided additional information at the agency’s request. On December 16, 2016, the EPA proposed a Settlement Agreement in a letter to the Partnership relating to the allegations in the NOV. On January 17, 2017, the Partnership responded to the EPA indicating that the EPA had failed to explain or provide support for its allegations and that the EPA should better explain its positions and the evidence on which it was relying. The Partnership has signed a tolling agreement with respect to this matter through June 30, 2017. To-date, the EPA has not taken any further action with respect to the NOV. By letter dated October 5, 2015, the Partnership received a notice of intent to sue (the “October NOI”), which supersedes and replaces a prior notice of intent to sue that the Partnership received on September 1, 2015 (the “September NOI”) from Earthjustice, an environmental advocacy organization on behalf of the County of Albany, New York, a public housing development owned and operated by the Albany Housing Authority and certain environmental organizations, related to alleged violations of the CAA, particularly with respect to crude oil operations at the Albany Terminal. The October NOI revises the superseded and replaced the September NOI to add two additional environmental advocacy organizations and to revise the relief sought and the description of the alleged CAA violations. On February 3, 2016, Earthjustice and the other entities identified in the October NOI filed suit against the Partnership in federal court in Albany under the citizen suit provisions of the CAA. In summary, this lawsuit alleges that certain of the Partnership’s operations at the Albany Terminal are in violation of the CAA. The plaintiffs seek, among other things, relief that would compel the Partnership both to apply for what the plaintiffs contend is the applicable permit under the CAA, and to install additional pollution controls. In addition, the plaintiffs seek to prohibit the Albany Terminal from receiving, storing, handling, and marine loading certain types of Bakken crude oil and to require payment of a civil penalty of $37,500 for each day the Partnership as operated the Albany Terminal in violation of the CAA. The Partnership believes that it has meritorious defenses against all allegations. On February 26, 2016, the Partnership filed a motion to dismiss the CAA action. No decision has yet been issued by the Court and all discovery and other litigation activity is stayed pending a decision by the Court on the motion to dismiss. By letter dated January 25, 2017, the Partnership received a notice of intent to sue (the “2017 NOI”) from Earthjustice related to alleged violations of the CAA; specifically alleging that the Partnership was operating the Albany Terminal without a valid CAA Title V Permit. On February 9, 2017, the Partnership responded to Earthjustice advising that the 2017 NOI was without factual or legal merit and that the Partnership would move to dismiss any action commenced by Earthjustice. At this time, there has been no further action taken by Earthjustice. Neither the EPA nor the NYSDEC has followed up on the NOI. The Albany Terminal is currently operating pursuant to its Title V Permit. The Partnership believes that it has meritorious defenses against all allegations. On May 29, 2015 and in connection with a commercial dispute with Tethys Trading Company LLC (“Tethys”), the Partnership received a notice from Tethys alleging a default under, and purporting to terminate, the Partnership’s contract with Tethys for crude oil services at the Partnership’s Oregon facility. However, the Partnership does not believe Tethys had the right to terminate the contract, and the Partnership will continue to investigate and determine the appropriate action to take to enforce its rights under the agreement. On March 26, 2015, the Partnership received a Notice of Non-Compliance (“NON”) from the Massachusetts Department of Environmental Protection (“DEP”) with respect to the Revere terminal (the “Revere Terminal”) located in Boston Harbor in Revere, Massachusetts, alleging certain violations of the National Pollutant Discharge Elimination System Permit (“NPDES Permit”) related to storm water discharges. The NON required the Partnership to submit a plan to remedy the reported violations of the NPDES Permit. The Partnership has responded to the NON with a plan and has implemented modifications to the storm water management system at the Revere Terminal in accordance with the plan. The Partnership has requested that the DEP acknowledge completion of the required modifications to the storm water management system in satisfaction of the NON. While no response has yet been received, the Partnership believes that compliance with the NON has been achieved, and implementation of the plan will have no material impact on its operations. The Partnership received letters from the EPA dated November 2, 2011 and March 29, 2012, containing requirements and testing orders (collectively, the “Requests for Information”) for information under the CAA. The Requests for Information were part of an EPA investigation to determine whether the Partnership has violated sections of the CAA at certain of its terminal locations in New England with respect to residual oil and asphalt. On June 6, 2014, a NOV was received from the EPA, alleging certain violations of its Air Emissions License issued by the Maine Department of Environmental Protection, based upon the test results at the South Portland, Maine terminal. The Partnership met with and provided additional information to the EPA with respect to the alleged violations. On April 7, 2015, the EPA issued a Supplemental Notice of Violation (the “Supplemental NOV”) modifying the allegations of violations of the terminal’s Air Emissions License. The Partnership has responded to the Supplemental NOV and is engaged in further negotiations with the EPA. A tolling agreement was executed with the United States on December 1, 2015, which has currently been extended through June 30, 2017. While the Partnership does not believe that a material violation has occurred, and it contests the allegations presented in the NOV and Supplemental NOV, the Partnership does not believe any adverse determination in connection with the NOV would have a material impact on its operations.

New Accounting Standards

New Accounting Standards	3 Months Ended
	Mar. 31, 2017
New Accounting Standards
New Accounting Standards	Note 20. New Accounting Standards Except as disclosed below, there have been no developments to recently issued accounting standards, including the expected dates of adoption and estimated effects on the Partnership’s consolidated financial statements, from those disclosed in the Partnership’s 2016 Annual Report on Form 10-K, except for the following: Accounting Standards or Updates Recently Adopted In January 2017, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2017-04, “Intangibles-Goodwill and Other.” This standard eliminates step two from the goodwill impairment test, and instead requires an entity to recognize a goodwill impairment charge for the amount by which the goodwill carrying amount exceeds the reporting unit’s fair value. This standard is effective for interim and annual goodwill impairment tests in fiscal years beginning after December 15, 2019, and early adoption is permitted. This standard must be applied on a prospective basis. The Partnership adopted this standard on January 1, 2017. The adoption of this standard did not have a material impact on the Partnership’s consolidated financial statements. In March 2016, the FASB issued ASU 2016-09, “Compensation-Stock Compensation: Improvements to Employee Share-Based Payment Accounting.” This standard simplifies several aspects of the accounting for share-based payment award transactions, including accounting for income taxes and classification of excess tax benefits on the statement of cash flows, forfeitures and minimum statutory tax withholding requirements. This standard is effective for annual periods beginning after December 15, 2016 and interim periods within those annual periods. Early adoption is permitted for any interim or annual period. The Partnership adopted this standard on January 1, 2017. The adoption of this standard did not have a material impact on the Partnership’s consolidated financial statements. In March 2016, the FASB issued ASU 2016-05, “Derivatives and Hedging: Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships.” This standard clarifies that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge accounting criteria continue to be met. This standard is effective for fiscal years beginning after December 15, 2016 and interim periods within those fiscal years. Early adoption is permitted, including adoption in an interim period. The Partnership adopted this standard on January 1, 2017. The adoption of this standard did not have a material impact on the Partnership’s consolidated financial statements. In July 2015, the FASB issued ASU 2015-11, Accounting Standards or Updates Not Yet Effective In January 2017, the FASB issued ASU 2017-01, “Business Combinations: Clarifying the Definition of a Business.” This standard clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. This standard is effective for annual periods beginning after December 15, 2017 and interim periods within those annual periods. The Partnership is assessing the impact this standard will have on its consolidated financial statements. In January 2016, the FASB issued ASU 2016-01, “Financial Instruments - Recognition and Measurement of Financial Assets and Financial Liabilities”. This standard revises the classification and measurement of investments in certain equity investments and the presentation of certain fair value changes for certain financial liabilities measured at fair value. This standard also requires the change in fair value of many equity investments to be recognized in net income. This standard is effective for interim and annual periods beginning after December 15, 2017, with early adoption permitted. The adoption of this standard is not expected to have a material impact on the Partnership’s consolidated financial statements. In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”) and has modified the standard thereafter. This standard, as amended, replaces existing revenue recognition rules with a comprehensive revenue measurement and recognition standard and expanded disclosure requirements. ASU 2014-09, as amended, becomes effective for annual reporting periods beginning after December 15, 2017, at which point the Partnership plans to adopt the standard. The Partnership is evaluating the impact this standard will have on its consolidated financial statements. To perform the evaluation, the Partnership established a cross-functional implementation team consisting of representatives from across all of the Partnership’s operating segments. Based on initial evaluation efforts performed, the Partnership expects that a portion of its current and prospective revenue will be outside the scope of the standard. Of the Partnership’s revenue recognized for the year ended December 31, 2016, approximately 40% originated as forward physical contracts (within the Wholesale and Commercial segments) which are accounted for as derivatives and are outside the scope of ASU 2014-09. The FASB allows two adoption methods under ASU 2014-09. Under one method, an entity will apply the rules to contracts in all reporting periods presented, subject to certain allowable exceptions. Under the other method, an entity will apply the rules to all contracts existing as of January 1, 2018, recognizing in beginning retained earnings an adjustment for the cumulative effect of the change and providing additional disclosures comparing results to previous rules (“modified retrospective method”). The Partnership will continue to evaluate the available adoption methods.

Subsequent Events

Subsequent Events	3 Months Ended
	Mar. 31, 2017
Subsequent Event Abstract
Subsequent Events	Note 21. Subsequent Events Amendment to Credit Agreement —On April 25, 2017, the Partnership and certain of its subsidiaries entered into a third amended and restated credit agreement with aggregate commitments of $1.3 billion and a maturity date of April 30, 2020. See Note 7 for additional information. Distribution —On April 28, 2017, the board of directors of the General Partner declared a quarterly cash distribution of $0.4625 per unit ($1.85 per unit on an annualized basis) for the period from January 1, 2017 through March 31, 2017. On May 15, 2017, the Partnership will pay this cash distribution to its unitholders of record as of the close of business on May 10, 2017. Sale of Gasoline Stations —Beginning in April 2016, the Partnership retained a real estate firm to coordinate the sales of approximately 75 non-strategic GDSO sites. As of March 31, 2017, the Partnership completed the sale of 45 of these sites, and the criteria to be presented as held for sale was met for 22 of the remaining sites (see Note 6). Through April 30, 2017, the criteria to be presented as held for sale was met for one additional site with a net book value of $0.1 million at March 31, 2017. Assets held for sale are expected to be sold within the next 12 months.

Supplemental Guarantor Condense

Supplemental Guarantor Condensed Consolidating Financial Statements	3 Months Ended
	Mar. 31, 2017
Supplemental Guarantor Condensed Consolidating Financial Statements
Supplemental Guarantor Condensed Consolidating Financial Statements	Note 22. Supplemental Guarantor Condensed Consolidating Financial Statements The Partnership’s wholly owned subsidiaries, other than GLP Finance, are guarantors of senior notes issued by the Partnership and GLP Finance. As such, the Partnership is subject to the requirements of Rule 3-10 of Regulation S-X of the SEC regarding financial statements of guarantors and issuers of registered guaranteed securities. The Partnership presents condensed consolidating financial information for its subsidiaries within the notes to consolidated financial statements in accordance with the criteria established for parent companies in the SEC’s Regulation S-X, Rule 3-10(d). The following condensed consolidating financial information presents the Condensed Consolidating Balance Sheets as of March 31, 2017 and December 31, 2016, the Condensed Consolidating Statements of Operations for the three months ended March 31, 2017 and 2016 and the Condensed Consolidating Statements of Cash Flows for the three months ended March 31, 2017 and 2016 of the Partnership’s 100% owned guarantor subsidiaries, the non-guarantor subsidiary and the eliminations necessary to arrive at the information for the Partnership on a consolidated basis. The principal elimination entries eliminate investments in subsidiaries and intercompany balances and transactions. Condensed Consolidating Balance Sheet March 31, 2017 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ 13,042 $ 1,084 $ — $ 14,126 Accounts receivable, net 312,072 171 71 312,314 Accounts receivable - affiliates 2,957 71 (71) 2,957 Inventories 433,952 — — 433,952 Brokerage margin deposits 18,886 — — 18,886 Derivative assets 2,720 — — 2,720 Prepaid expenses and other current assets 70,841 269 — 71,110 Total current assets 854,470 1,595 — 856,065 Property and equipment, net 1,063,816 10,649 — 1,074,465 Intangible assets, net 62,443 — — 62,443 Goodwill 292,773 — — 292,773 Other assets 42,583 — — 42,583 Total assets $ 2,316,085 $ 12,244 $ — $ 2,328,329 Liabilities and partners' equity Current liabilities: Accounts payable $ 231,925 $ 200 $ — $ 232,125 Accounts payable - affiliates (36) 36 — — Working capital revolving credit facility - current portion 176,900 — — 176,900 Environmental liabilities - current portion 5,339 — — 5,339 Trustee taxes payable 98,955 — — 98,955 Accrued expenses and other current liabilities 59,101 70 — 59,171 Derivative liabilities 4,986 — — 4,986 Total current liabilities 577,170 306 — 577,476 Working capital revolving credit facility - less current portion 150,000 — — 150,000 Revolving credit facility 200,700 — — 200,700 Senior notes 659,805 — — 659,805 Environmental liabilities - less current portion 55,105 — — 55,105 Financing obligations 152,466 — — 152,466 Deferred tax liabilities 65,296 — — 65,296 Other long-term liabilities 62,173 — — 62,173 Total liabilities 1,922,715 306 — 1,923,021 Partners' equity Global Partners LP equity 393,370 7,193 — 400,563 Noncontrolling interest — 4,745 — 4,745 Total partners' equity 393,370 11,938 — 405,308 Total liabilities and partners' equity $ 2,316,085 $ 12,244 $ — $ 2,328,329 Condensed Consolidating Balance Sheet December 31, 2016 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ 9,373 $ 655 $ — $ 10,028 Accounts receivable, net 420,897 213 250 421,360 Accounts receivable - affiliates 2,865 528 (250) 3,143 Inventories 521,878 — — 521,878 Brokerage margin deposits 27,653 — — 27,653 Derivative assets 21,382 — — 21,382 Prepaid expenses and other current assets 69,872 150 — 70,022 Total current assets 1,073,920 1,546 — 1,075,466 Property and equipment, net 1,087,964 11,935 — 1,099,899 Intangible assets, net 65,013 — — 65,013 Goodwill 294,768 — — 294,768 Other assets 28,874 — — 28,874 Total assets $ 2,550,539 $ 13,481 $ — $ 2,564,020 Liabilities and partners' equity Current liabilities: Accounts payable $ 320,003 $ 259 $ — $ 320,262 Working capital revolving credit facility - current portion 274,600 — — 274,600 Environmental liabilities - current portion 5,341 — — 5,341 Trustee taxes payable 101,166 — — 101,166 Accrued expenses and other current liabilities 70,262 181 — 70,443 Derivative liabilities 27,413 — — 27,413 Total current liabilities 798,785 440 — 799,225 Working capital revolving credit facility - less current portion 150,000 — — 150,000 Revolving credit facility 216,700 — — 216,700 Senior notes 659,150 — — 659,150 Environmental liabilities - less current portion 57,724 — — 57,724 Financing obligations 152,444 — — 152,444 Deferred tax liabilities 66,054 — — 66,054 Other long-term liabilities 64,882 — — 64,882 Total liabilities 2,165,739 440 — 2,166,179 Partners' equity Global Partners LP equity 384,800 7,855 — 392,655 Noncontrolling interest — 5,186 — 5,186 Total partners' equity 384,800 13,041 — 397,841 Total liabilities and partners' equity $ 2,550,539 $ 13,481 $ — $ 2,564,020 Condensed Consolidating Statement of Operations Three Months Ended March 31, 2017 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Eliminations Consolidated Sales $ 2,270,121 $ 669 $ (6) $ 2,270,784 Cost of sales 2,129,652 1,111 (6) 2,130,757 Gross profit 140,469 (442) — 140,027 Costs and operating expenses: Selling, general and administrative expenses 36,673 114 — 36,787 Operating expenses 66,649 564 — 67,213 Amortization expense 2,261 — — 2,261 Net (gain) loss on sale and disposition of assets (11,845) (17) — (11,862) Total costs and operating expenses 93,738 661 — 94,399 Operating income (loss) 46,731 (1,103) — 45,628 Interest expense (23,287) — — (23,287) Income (loss) before income tax benefit 23,444 (1,103) — 22,341 Income tax benefit 164 — — 164 Net income (loss) 23,608 (1,103) — 22,505 Net loss attributable to noncontrolling interest — 441 — 441 Net income (loss) attributable to Global Partners LP 23,608 (662) — 22,946 Less: General partners' interest in net income, including incentive distribution rights 154 — — 154 Limited partners' interest in net income (loss) $ 23,454 $ (662) $ — $ 22,792 Condensed Consolidating Statement of Operations Three Months Ended March 31, 2016 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Eliminations Consolidated Sales $ 1,750,281 $ 2,633 $ (2,102) $ 1,750,812 Cost of sales 1,620,015 2,840 (2,102) 1,620,753 Gross profit 130,266 (207) — 130,059 Costs and operating expenses: Selling, general and administrative expenses 34,751 233 — 34,984 Operating expenses 70,649 1,587 — 72,236 Amortization expense 2,509 — — 2,509 Net loss on sale and disposition of assets 6,105 — — 6,105 Total costs and operating expenses 114,014 1,820 — 115,834 Operating income (loss) 16,252 (2,027) — 14,225 Interest expense (22,980) — — (22,980) Loss before income tax benefit (6,728) (2,027) — (8,755) Income tax benefit 920 — — 920 Net loss (5,808) (2,027) — (7,835) Net loss attributable to noncontrolling interest — 811 — 811 Net loss attributable to Global Partners LP (5,808) (1,216) — (7,024) Less: General partners' interest in net loss, including incentive distribution rights (47) — — (47) Limited partners' interest in net loss $ (5,761) $ (1,216) $ — $ (6,977) Condensed Consolidating Statement Cash Flows Three Months Ended March 31, 2017 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Consolidated Cash flows from operating activities Net cash provided by operating activities $ 117,156 $ 409 $ 117,565 Cash flows from investing activities Capital expenditures (8,378) — (8,378) Proceeds from sale of property and equipment 24,229 20 24,249 Net cash provided by investing activities 15,851 20 15,871 Cash flows from financing activities Net payments on working capital revolving credit facility (97,700) — (97,700) Net payments on revolving credit facility (16,000) — (16,000) Distributions to partners (15,638) — (15,638) Net cash used in financing activities (129,338) — (129,338) Cash and cash equivalents Increase in cash and cash equivalents 3,669 429 4,098 Cash and cash equivalents at beginning of period 9,373 655 10,028 Cash and cash equivalents at end of period $ 13,042 $ 1,084 $ 14,126 Condensed Consolidating Statement Cash Flows Three Months Ended March 31, 2016 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Consolidated Cash flows from operating activities Net cash used in operating activities $ (53,341) $ (175) $ (53,516) Cash flows from investing activities Capital expenditures (16,451) — (16,451) Proceeds from sale of property and equipment 8,588 — 8,588 Net cash used in investing activities (7,863) — (7,863) Cash flows from financing activities Net borrowings from working capital revolving credit facility 87,100 — 87,100 Net borrowings from revolving credit facility 6,100 — 6,100 Noncontrolling interest capital contribution 952 (595) 357 Distribution to noncontrolling interest (595) — (595) Distributions to partners (15,630) — (15,630) Net cash provided by (used in) financing activities 77,927 (595) 77,332 Cash and cash equivalents Increase (decrease) in cash and cash equivalents 16,723 (770) 15,953 Cash and cash equivalents at beginning of period (3,574) 4,690 1,116 Cash and cash equivalents at end of period $ 13,149 $ 3,920 $ 17,069 Placeholder-please do not delete

Organization and Basis of Pre30

Organization and Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 2017
Summary of Significant Accounting Policies
Basis of Presentation	Basis of Presentation The accompanying consolidated financial statements as of March 31, 2017 and December 31, 2016 and for the three months ended March 31, 2017 and 2016 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, 2016 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, 2017 are not necessarily indicative of the results of operations that will be realized for the entire year ending December 31, 2017. The consolidated balance sheet at December 31, 2016 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, 2016.
Noncontrolling Interest	Noncontrolling Interest The Partnership acquired a 60% interest in Basin Transload, LLC (“Basin Transload”) on February 1, 2013. After evaluating Accounting Standards Codification (“ASC”) Topic 810, “Consolidations,” the Partnership concluded it is appropriate to consolidate the balance sheet and statements of operations of Basin Transload based on an evaluation of the outstanding voting interests. Amounts pertaining to the noncontrolling ownership interest held by third parties in the financial position and operating results of the Partnership are reported as a noncontrolling interest in the accompanying consolidated balance sheets and statements of operations.
Concentration of Risk	Concentration of Risk Due to the nature of the Partnership’s business and its reliance, in part, on consumer travel and spending patterns, the Partnership may experience more demand for gasoline during the late spring and summer months than during the fall and winter. Travel and recreational activities are typically higher in these months in the geographic areas in which the Partnership operates, increasing the demand for gasoline. Therefore, the Partnership’s volumes in gasoline are typically higher in the second and third quarters of the calendar year. As demand for some of the Partnership’s refined petroleum products, specifically home heating oil and residual oil for space heating purposes, is generally greater during the winter months, heating oil and residual oil volumes are generally higher during the first and fourth quarters of the calendar year. These factors may result in fluctuations in the Partnership’s quarterly operating results. The following table presents the Partnership’s product sales and other revenues as a percentage of the consolidated sales for the periods presented: Three Months Ended March 31, 2017 2016 Gasoline sales: gasoline and gasoline blendstocks (such as ethanol) 59 % 57 % Crude oil sales and crude oil logistics revenue 5 % 8 % Distillates (home heating oil, diesel and kerosene), residual oil, natural gas and propane sales 33 % 30 % Convenience store sales, rental income and sundry sales 3 % 5 % Total 100 % 100 % The following table presents the Partnership’s product margin by segment as a percentage of the consolidated product margin for the periods presented: Three Months Ended March 31, 2017 2016 Wholesale segment 32 % 25 % Gasoline Distribution and Station Operations segment 65 % 70 % Commercial segment 3 % 5 % Total 100 % 100 % See Note 15, “Segment Reporting,” for additional information on the Partnership’s operating segments. None of the Partnership’s customers accounted for greater than 10% of total sales for the three months ended March 31, 2017 and 2016.

Organization and Basis of Pre31

Organization and Basis of Presentation (Tables)	3 Months Ended
	Mar. 31, 2017
Product Margin [Member]
Schedule of revenues and product margin as a percentage of the consolidated total	Three Months Ended March 31, 2017 2016 Wholesale segment 32 % 25 % Gasoline Distribution and Station Operations segment 65 % 70 % Commercial segment 3 % 5 % Total 100 % 100 %
Sales Revenue, Product Line [Member]
Schedule of revenues and product margin as a percentage of the consolidated total	Three Months Ended March 31, 2017 2016 Gasoline sales: gasoline and gasoline blendstocks (such as ethanol) 59 % 57 % Crude oil sales and crude oil logistics revenue 5 % 8 % Distillates (home heating oil, diesel and kerosene), residual oil, natural gas and propane sales 33 % 30 % Convenience store sales, rental income and sundry sales 3 % 5 % Total 100 % 100 %

Net Income (Loss) Per Limited P

Net Income (Loss) Per Limited Partner Unit (Tables)	3 Months Ended
	Mar. 31, 2017
Net (Loss) Income Per Limited Partner Unit
Schedule of reconciliation of net income and the assumed allocation of net income (loss) to the limited partners' interest for purposes of computing net income per limited partner unit (in thousands, except per unit data)	Three Months Ended March 31, 2017 Three Months Ended March 31, 2016 Limited General Limited General Partner Partner Partner Partner Numerator: Total Interest Interest IDRs Total Interest Interest IDRs Net income (loss) attributable to Global Partners LP $ 22,946 $ 22,792 $ 154 $ — $ (7,024) $ (6,977) $ (47) $ — Declared distribution $ 15,829 $ 15,723 $ 106 $ — $ 15,829 $ 15,723 $ 106 $ — Assumed allocation of undistributed net income (loss) 7,117 7,069 48 — (22,853) (22,700) (153) — Assumed allocation of net income (loss) $ 22,946 $ 22,792 $ 154 $ — $ (7,024) $ (6,977) $ (47) $ — Denominator: Basic weighted average limited partner units outstanding 33,554 33,517 Dilutive effect of phantom units 56 — Diluted weighted average limited partner units outstanding 33,610 33,517 Basic net income (loss) per limited partner unit $ 0.68 $ (0.21) Diluted net income (loss) per limited partner unit (1) $ 0.68 $ (0.21) (1) Basic units were used to calculate diluted net loss per limited partner unit for the three months ended March 31, 2016, as using the effects of phantom units would have an anti-dilutive effect on net loss per limited partner unit.
Schedule of quarterly cash distributions made to general partners	Per Unit Cash Distribution Declared for the Cash Distribution Declaration Date Distribution Declared Quarterly Period Ended April 28, 2017 $ 0.4625 March 31, 2017

Inventories (Tables)

Inventories (Tables)	3 Months Ended
	Mar. 31, 2017
Inventories
Schedule of inventories (in thousands)	March 31, December 31, 2017 2016 Distillates: home heating oil, diesel and kerosene $ 157,037 $ 180,272 Gasoline 70,093 101,368 Gasoline blendstocks 49,276 54,582 Crude oil 121,577 136,113 Residual oil 18,319 29,536 Propane and other 976 3,167 Renewable identification numbers (RINs) 640 631 Convenience store inventory 16,034 16,209 Total $ 433,952 $ 521,878

Goodwill (Tables)

Goodwill (Tables)	3 Months Ended
	Mar. 31, 2017
Goodwill and Intangible Assets
Changes in Goodwill by Segment (in thousands)	Balance at December 31, 2016 $ 294,768 Disposals (1) (1,995) Balance at March 31, 2017 $ 292,773 (1) Disposals represent derecognition of goodwill associated with the sale and disposition of certain assets. See Note 6.

Property and Equipment (Tables)

Property and Equipment (Tables)	3 Months Ended
	Mar. 31, 2017
Property and Equipment
Schedule of components of property and equipment (in thousands)	March 31, December 31, 2017 2016 Buildings and improvements $ 994,236 $ 984,373 Land 411,777 418,025 Fixtures and equipment 41,304 40,354 Idle plant assets 30,500 30,500 Construction in process 33,129 42,069 Capitalized internal use software 20,097 20,097 Total property and equipment 1,531,043 1,535,418 Less accumulated depreciation 456,578 435,519 Total $ 1,074,465 $ 1,099,899

Sales and Disposition of Asse36

Sales and Disposition of Assets (Tables)	3 Months Ended
	Mar. 31, 2017
Sales and Disposition of Assets
Schedule of (Gain) Loss on Sale and Dispositions of Assets	Three Months Ended March 31, 2017 2016 Sale of natural gas brokerage and electricity businesses $ (14,172) $ — Periodic divestiture of gasoline stations (180) 579 Strategic asset divestiture program - Real estate firm coordinated sale 423 — Loss on assets held for sale 2,051 5,536 Other 16 (10) Net (gain) loss on sale and disposition of assets $ (11,862) $ 6,105

Derivative Financial Instrume37

Derivative Financial Instruments (Tables)	3 Months Ended
	Mar. 31, 2017
Derivative Financial Instruments
Schedule of notional values of derivative instruments	Units (1) Unit of Measure Exchange-Traded Derivatives Long 66,871 Thousands of barrels Short (72,498) Thousands of barrels OTC Derivatives (Petroleum/Ethanol) Long 6,928 Thousands of barrels Short (3,562) Thousands of barrels Interest Rate Swap $ 100.0 Millions of U.S. dollars (1) Number of open positions and gross notional values do not measure the Partnership’s risk of loss, quantify risk or represent assets or liabilities of the Partnership, but rather indicate the relative size of the derivative instruments and are used in the calculation of the amounts to be exchanged between counterparties upon settlements.
Summary of derivatives not designated as either fair value hedges or cash flow hedges and their respective fair values and location	Statement of Gain (Loss) Three Months Ended Derivatives not designated as Recognized in March 31, hedging instruments Income on Derivatives 2017 2016 Commodity contracts Cost of sales $ 1,554 $ (415) Forward foreign currency contracts Cost of sales — 39 Total $ 1,554 $ (376)
Schedule of fair values of derivative instruments and location in consolidated balance sheets (in thousands)	March 31, 2017 Derivatives Derivatives Not Designated as Designated as Hedging Hedging Balance Sheet Location Instruments Instruments Total Asset Derivatives: Exchange-traded derivative contracts Broker margin deposits $ 4,006 $ 23,218 $ 27,224 Forward derivative contracts (1) Derivative assets — 2,720 2,720 Total asset derivatives $ 4,006 $ 25,938 $ 29,944 Liability Derivatives: Exchange-traded derivative contracts Broker margin deposits $ (6,282) $ (33,071) $ (39,353) Forward derivative contracts (1) Derivative liabilities — (4,986) (4,986) Interest rate swap contracts Other long-term liabilities — (773) (773) Total liability derivatives $ (6,282) $ (38,830) $ (45,112) December 31, 2016 Derivatives Derivatives Not Designated as Designated as Hedging Hedging Balance Sheet Location Instruments Instruments Total Asset Derivatives: Exchange-traded derivative contracts Broker margin deposits $ — $ 60,018 $ 60,018 Forward derivative contracts (1) Derivative assets — 21,382 21,382 Total asset derivatives $ — $ 81,400 $ 81,400 Liability Derivatives: Exchange-traded derivative contracts Broker margin deposits $ (33,877) $ (96,831) $ (130,708) Forward derivative contracts (1) Derivative liabilities — (27,413) (27,413) Interest rate swap contracts Other long-term liabilities — (1,170) (1,170) Total liability derivatives $ (33,877) $ (125,414) $ (159,291) (1) Forward derivative contracts include the Partnership’s petroleum and ethanol physical and financial forwards and OTC swaps.
Fair Value Hedge
Derivative Financial Instruments
Schedule of net gains and losses from derivatives recognized in consolidated statements of operations (in thousands)	Statement of Gain (Loss) Three Months Ended Recognized in Income on March 31, Derivatives 2017 2016 Derivatives in fair value hedging relationship Exchange-traded futures contracts and OTC derivative contracts for petroleum commodity products Cost of sales $ 20,696 $ 27,839 Hedged items in fair value hedge relationship Physical inventory Cost of sales $ (20,845) $ (24,175)

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2017
Fair Value Measurements
Schedule of financial assets and financial liabilities measured at fair value on a recurring basis (in thousands)	Fair Value at March 31, 2017 Cash Collateral Level 1 Level 2 Level 3 Netting Total Assets: Forward derivative contracts (1) $ — $ 2,199 $ 313 $ — $ 2,512 Swap agreements and options — 208 — — 208 Exchange-traded/cleared derivative instruments (2) (12,128) — — 31,014 18,886 Pension plans 17,199 — — — 17,199 Total assets $ 5,071 $ 2,407 $ 313 $ 31,014 $ 38,805 Liabilities: Forward derivative contracts (1) $ — $ (4,438) $ (427) $ — $ (4,865) Swap agreements and options — (121) — — (121) Interest rate swaps — (773) — — (773) Total liabilities $ — $ (5,332) $ (427) $ — $ (5,759) Fair Value at December 31, 2016 Cash Collateral Level 1 Level 2 Level 3 Netting Total Assets: Forward derivative contracts (1) $ — $ 18,972 $ 1,683 $ — $ 20,655 Swap agreements and options — 727 — — 727 Exchange-traded/cleared derivative instruments (2) (70,690) — — 98,344 27,654 Pension plans 16,777 — — — 16,777 Total assets $ (53,913) $ 19,699 $ 1,683 $ 98,344 $ 65,813 Liabilities: Forward derivative contracts (1) $ — $ (25,097) $ (2,054) $ — $ (27,151) Swap agreements and options — (262) — — (262) Interest rate swaps — (1,170) — — (1,170) Total liabilities $ — $ (26,529) $ (2,054) $ — $ (28,583) (1) Forward derivative contracts include the Partnership’s petroleum and ethanol physical and financial forwards and OTC swaps. (2) Amount includes the effect of cash balances on deposit with clearing brokers.
Carrying value and fair value of the Partnership’s senior notes (in thousands)	March 31, 2017 December 31, 2016 Face Fair Face Fair Value Value Value Value 6.25% senior notes $ 375,000 $ 367,500 $ 375,000 $ 361,163 7.00% senior notes $ 300,000 $ 297,000 $ 300,000 $ 289,500
Schedule of sensitivity of fair value measurement to changes in significant unobservable inputs	Significant Impact on Fair Value Unobservable Input Position Change to Input Measurement Location basis Long Increase (decrease) Gain (loss) Location basis Short Increase (decrease) Loss (gain) Transportation Long Increase (decrease) Gain (loss) Transportation Short Increase (decrease) Loss (gain) Throughput costs Long Increase (decrease) Gain (loss) Throughput costs Short Increase (decrease) Loss (gain)
Summary of the changes in fair value of Level 3 financial assets and liabilities (in thousands)	Fair value at December 31, 2016 $ (371) Derivatives entered into during the period (192) Derivatives sold during the period 183 Realized gains (losses) recorded in cost of sales 648 Unrealized gains (losses) recorded in cost of sales (382) Fair value at March 31, 2017 $ (114)

Environmental Liabilities, As39

Environmental Liabilities, Asset Retirement Obligations and RINs (Tables)	3 Months Ended
	Mar. 31, 2017
Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers (RINs)
Summary roll forward of the environmental liabilities (in thousands)	Balance at Other Balance at December 31, Payments in Dispositions Adjustments March 31, Environmental Liability Related to: 2016 2017 2017 2017 2017 Retail gasoline stations $ 58,456 $ (813) $ (1,050) $ (725) $ 55,868 Terminals 4,609 (33) — — 4,576 Total environmental liabilities $ 63,065 $ (846) $ (1,050) $ (725) $ 60,444 Current portion $ 5,341 $ 5,339 Long-term portion 57,724 55,105 Total environmental liabilities $ 63,065 $ 60,444

Related Party Transactions (Tab

Related Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2017
Related Party Transactions
Schedule of receivables from related parties (in thousands)	The table below presents receivables from GPC and the General Partner (in thousands): March 31, December 31, 2017 2016 Receivables from GPC $ 72 $ 6 Receivables from the General Partner (1) 2,885 3,137 Total $ 2,957 $ 3,143 (1) Receivables from the General Partner reflect the Partnership’s prepayment of payroll taxes and payroll accruals to the General Partner.

Long-Term Incentive Plan (Table

Long-Term Incentive Plan (Tables)	3 Months Ended
	Mar. 31, 2017
Long-Term Incentive Plan
Summary of the status of the non-vested phantom units	Weighted Number of Average Non-vested Grant Date Units Fair Value ($) Outstanding non—vested units at December 31, 2016 571,554 38.56 Vested (10,659) 35.94 Forfeited (51,203) 38.19 Outstanding non—vested units at March 31, 2017 509,692 38.66

Partners' Equity and Cash Dis42

Partners' Equity and Cash Distributions (Tables)	3 Months Ended
	Mar. 31, 2017
Partners' Equity and Cash Distribution
Schedule of quarterly cash distributions to the unitholders and the General Partner based on target levels	Marginal Percentage Total Quarterly Distribution Interest in Distributions Target Amount Unitholders General Partner First Target Distribution up to $0.4625 99.33 % 0.67 % Second Target Distribution above $0.4625 up to $0.5375 86.33 % 13.67 % Third Target Distribution above $0.5375 up to $0.6625 76.33 % 23.67 % Thereafter above $0.6625 51.33 % 48.67 %
Schedule of cash distributions made by the Partnership (in thousands, except per unit data)	Earned for the Per Unit Cash Distribution Quarter Cash Common General Incentive Total Cash Payment Date Ended Distribution Units Partner Distribution Distribution 2/14/2017 12/31/16 $ $ 15,723 $ 106 $ — $ 15,829

Segment Reporting (Tables)

Segment Reporting (Tables)	3 Months Ended
	Mar. 31, 2017
Segment Reporting
Summary of financial information for the reportable segments (in thousands)	Summarized financial information for the Partnership’s reportable segments is presented in the table below (in thousands): Three Months Ended March 31, 2017 2016 Wholesale Segment: Sales Gasoline and gasoline blendstocks $ 505,704 $ 342,729 Crude oil (1) 103,528 148,502 Other oils and related products (2) 616,567 419,009 Total $ 1,225,799 $ 910,240 Product margin Gasoline and gasoline blendstocks $ 15,385 $ 16,362 Crude oil (1) 6,892 (2,373) Other oils and related products (2) 29,873 25,249 Total $ 52,150 $ 39,238 Gasoline Distribution and Station Operations Segment: Sales Gasoline $ 767,636 $ 616,103 Station operations (3) 75,596 85,185 Total $ 843,232 $ 701,288 Product margin Gasoline $ 67,155 $ 65,387 Station operations (3) 38,895 42,925 Total $ 106,050 $ 108,312 Commercial Segment: Sales $ 201,753 $ 139,284 Product margin $ 4,189 $ 6,910 Combined sales and Product margin: Sales $ 2,270,784 $ 1,750,812 Product margin (4) $ 162,389 $ 154,460 Depreciation allocated to cost of sales (22,362) (24,401) Combined gross profit $ 140,027 $ 130,059 (1) Crude oil consists of the Partnership’s crude oil sales and revenue from its logistics activities. (2) Other oils and related products primarily consist of distillates, residual oil and propane. (3) Station operations primarily consist of convenience store sales and rental income. (4) Product margin is a non-GAAP financial measure used by management and external users of the Partnership’s consolidated financial statements to assess its business. The table above includes a reconciliation of product margin on a combined basis to gross profit, a directly comparable GAAP measure.
Schedule of reconciliation of the totals reported for the reportable segments to the applicable line items in the consolidated financial statements (in thousands)	Three Months Ended March 31, 2017 2016 Combined gross profit $ 140,027 $ 130,059 Operating costs and expenses not allocated to operating segments: Selling, general and administrative expenses 36,787 34,984 Operating expenses 67,213 72,236 Amortization expense 2,261 2,509 Net (gain) loss on sale and disposition of assets (11,862) 6,105 Total operating costs and expenses 94,399 115,834 Operating income 45,628 14,225 Interest expense (23,287) (22,980) Income tax benefit 164 920 Net income (loss) 22,505 (7,835) Net loss attributable to noncontrolling interest 441 811 Net income (loss) attributable to Global Partners LP $ 22,946 $ (7,024)
Schedule of total assets by reportable segment (in thousands)	Wholesale Commercial GDSO Unallocated Total March 31, 2017 $ 729,855 $ 125 $ 1,253,019 $ 345,330 $ 2,328,329 December 31, 2016 $ 830,662 $ 134 $ 1,294,568 $ 438,656 $ 2,564,020

Changes in Accumulated Other 44

Changes in Accumulated Other Comprehensive Loss (Tables)	3 Months Ended
	Mar. 31, 2017
Changes in Accumulated Other Comprehensive Loss
Schedule of changes in accumulated other comprehensive loss (in thousands)	The following table presents the changes in accumulated other comprehensive loss by component for the three months ended March 31, 2017 (in thousands): Pension Three Months Ended March 31, 2017 Plan Derivatives Total Balance at December 31, 2016 $ (4,269) $ (1,172) $ (5,441) Other comprehensive income before reclassifications of gain (loss) 346 398 744 Amount of (loss) gain reclassified from accumulated other comprehensive income (27) — (27) Total comprehensive income 319 398 717 Balance at March 31, 2017 $ (3,950) $ (774) $ (4,724)

Supplemental Cash Flow Inform45

Supplemental Cash Flow Information (Tables)	3 Months Ended
	Mar. 31, 2017
Supplemental Cash Flow Elements [Abstract]
Schedule of cash flow supplemental information	Three Months Ended March 31, 2017 2016 Borrowings from working capital revolving credit facility $ 303,600 $ 418,200 Payments on working capital revolving credit facility (401,300) (331,100) Net (payments on) borrowings from working capital revolving credit facility $ (97,700) $ 87,100 Borrowings from revolving credit facility $ — $ 15,000 Payments on revolving credit facility (16,000) (8,900) Net (payments on) borrowings from revolving credit facility $ (16,000) $ 6,100

Supplemental Guarantor Conden46

Supplemental Guarantor Condensed Consolidating Financial Information (Tables)	3 Months Ended
	Mar. 31, 2017
Supplemental Guarantor Condensed Consolidating Financial Statements
Schedule of condensed consolidating balance sheets	Condensed Consolidating Balance Sheet March 31, 2017 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ 13,042 $ 1,084 $ — $ 14,126 Accounts receivable, net 312,072 171 71 312,314 Accounts receivable - affiliates 2,957 71 (71) 2,957 Inventories 433,952 — — 433,952 Brokerage margin deposits 18,886 — — 18,886 Derivative assets 2,720 — — 2,720 Prepaid expenses and other current assets 70,841 269 — 71,110 Total current assets 854,470 1,595 — 856,065 Property and equipment, net 1,063,816 10,649 — 1,074,465 Intangible assets, net 62,443 — — 62,443 Goodwill 292,773 — — 292,773 Other assets 42,583 — — 42,583 Total assets $ 2,316,085 $ 12,244 $ — $ 2,328,329 Liabilities and partners' equity Current liabilities: Accounts payable $ 231,925 $ 200 $ — $ 232,125 Accounts payable - affiliates (36) 36 — — Working capital revolving credit facility - current portion 176,900 — — 176,900 Environmental liabilities - current portion 5,339 — — 5,339 Trustee taxes payable 98,955 — — 98,955 Accrued expenses and other current liabilities 59,101 70 — 59,171 Derivative liabilities 4,986 — — 4,986 Total current liabilities 577,170 306 — 577,476 Working capital revolving credit facility - less current portion 150,000 — — 150,000 Revolving credit facility 200,700 — — 200,700 Senior notes 659,805 — — 659,805 Environmental liabilities - less current portion 55,105 — — 55,105 Financing obligations 152,466 — — 152,466 Deferred tax liabilities 65,296 — — 65,296 Other long-term liabilities 62,173 — — 62,173 Total liabilities 1,922,715 306 — 1,923,021 Partners' equity Global Partners LP equity 393,370 7,193 — 400,563 Noncontrolling interest — 4,745 — 4,745 Total partners' equity 393,370 11,938 — 405,308 Total liabilities and partners' equity $ 2,316,085 $ 12,244 $ — $ 2,328,329 Condensed Consolidating Balance Sheet December 31, 2016 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ 9,373 $ 655 $ — $ 10,028 Accounts receivable, net 420,897 213 250 421,360 Accounts receivable - affiliates 2,865 528 (250) 3,143 Inventories 521,878 — — 521,878 Brokerage margin deposits 27,653 — — 27,653 Derivative assets 21,382 — — 21,382 Prepaid expenses and other current assets 69,872 150 — 70,022 Total current assets 1,073,920 1,546 — 1,075,466 Property and equipment, net 1,087,964 11,935 — 1,099,899 Intangible assets, net 65,013 — — 65,013 Goodwill 294,768 — — 294,768 Other assets 28,874 — — 28,874 Total assets $ 2,550,539 $ 13,481 $ — $ 2,564,020 Liabilities and partners' equity Current liabilities: Accounts payable $ 320,003 $ 259 $ — $ 320,262 Working capital revolving credit facility - current portion 274,600 — — 274,600 Environmental liabilities - current portion 5,341 — — 5,341 Trustee taxes payable 101,166 — — 101,166 Accrued expenses and other current liabilities 70,262 181 — 70,443 Derivative liabilities 27,413 — — 27,413 Total current liabilities 798,785 440 — 799,225 Working capital revolving credit facility - less current portion 150,000 — — 150,000 Revolving credit facility 216,700 — — 216,700 Senior notes 659,150 — — 659,150 Environmental liabilities - less current portion 57,724 — — 57,724 Financing obligations 152,444 — — 152,444 Deferred tax liabilities 66,054 — — 66,054 Other long-term liabilities 64,882 — — 64,882 Total liabilities 2,165,739 440 — 2,166,179 Partners' equity Global Partners LP equity 384,800 7,855 — 392,655 Noncontrolling interest — 5,186 — 5,186 Total partners' equity 384,800 13,041 — 397,841 Total liabilities and partners' equity $ 2,550,539 $ 13,481 $ — $ 2,564,020
Schedule of condensed consolidating statements of income	Condensed Consolidating Statement of Operations Three Months Ended March 31, 2017 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Eliminations Consolidated Sales $ 2,270,121 $ 669 $ (6) $ 2,270,784 Cost of sales 2,129,652 1,111 (6) 2,130,757 Gross profit 140,469 (442) — 140,027 Costs and operating expenses: Selling, general and administrative expenses 36,673 114 — 36,787 Operating expenses 66,649 564 — 67,213 Amortization expense 2,261 — — 2,261 Net (gain) loss on sale and disposition of assets (11,845) (17) — (11,862) Total costs and operating expenses 93,738 661 — 94,399 Operating income (loss) 46,731 (1,103) — 45,628 Interest expense (23,287) — — (23,287) Income (loss) before income tax benefit 23,444 (1,103) — 22,341 Income tax benefit 164 — — 164 Net income (loss) 23,608 (1,103) — 22,505 Net loss attributable to noncontrolling interest — 441 — 441 Net income (loss) attributable to Global Partners LP 23,608 (662) — 22,946 Less: General partners' interest in net income, including incentive distribution rights 154 — — 154 Limited partners' interest in net income (loss) $ 23,454 $ (662) $ — $ 22,792 Condensed Consolidating Statement of Operations Three Months Ended March 31, 2016 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Eliminations Consolidated Sales $ 1,750,281 $ 2,633 $ (2,102) $ 1,750,812 Cost of sales 1,620,015 2,840 (2,102) 1,620,753 Gross profit 130,266 (207) — 130,059 Costs and operating expenses: Selling, general and administrative expenses 34,751 233 — 34,984 Operating expenses 70,649 1,587 — 72,236 Amortization expense 2,509 — — 2,509 Net loss on sale and disposition of assets 6,105 — — 6,105 Total costs and operating expenses 114,014 1,820 — 115,834 Operating income (loss) 16,252 (2,027) — 14,225 Interest expense (22,980) — — (22,980) Loss before income tax benefit (6,728) (2,027) — (8,755) Income tax benefit 920 — — 920 Net loss (5,808) (2,027) — (7,835) Net loss attributable to noncontrolling interest — 811 — 811 Net loss attributable to Global Partners LP (5,808) (1,216) — (7,024) Less: General partners' interest in net loss, including incentive distribution rights (47) — — (47) Limited partners' interest in net loss $ (5,761) $ (1,216) $ — $ (6,977)
Schedule of condensed consolidating statements of cash flows	Condensed Consolidating Statement Cash Flows Three Months Ended March 31, 2017 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Consolidated Cash flows from operating activities Net cash provided by operating activities $ 117,156 $ 409 $ 117,565 Cash flows from investing activities Capital expenditures (8,378) — (8,378) Proceeds from sale of property and equipment 24,229 20 24,249 Net cash provided by investing activities 15,851 20 15,871 Cash flows from financing activities Net payments on working capital revolving credit facility (97,700) — (97,700) Net payments on revolving credit facility (16,000) — (16,000) Distributions to partners (15,638) — (15,638) Net cash used in financing activities (129,338) — (129,338) Cash and cash equivalents Increase in cash and cash equivalents 3,669 429 4,098 Cash and cash equivalents at beginning of period 9,373 655 10,028 Cash and cash equivalents at end of period $ 13,042 $ 1,084 $ 14,126 Condensed Consolidating Statement Cash Flows Three Months Ended March 31, 2016 (In thousands) (Issuer) Non- Guarantor Guarantor Subsidiaries Subsidiary Consolidated Cash flows from operating activities Net cash used in operating activities $ (53,341) $ (175) $ (53,516) Cash flows from investing activities Capital expenditures (16,451) — (16,451) Proceeds from sale of property and equipment 8,588 — 8,588 Net cash used in investing activities (7,863) — (7,863) Cash flows from financing activities Net borrowings from working capital revolving credit facility 87,100 — 87,100 Net borrowings from revolving credit facility 6,100 — 6,100 Noncontrolling interest capital contribution 952 (595) 357 Distribution to noncontrolling interest (595) — (595) Distributions to partners (15,630) — (15,630) Net cash provided by (used in) financing activities 77,927 (595) 77,332 Cash and cash equivalents Increase (decrease) in cash and cash equivalents 16,723 (770) 15,953 Cash and cash equivalents at beginning of period (3,574) 4,690 1,116 Cash and cash equivalents at end of period $ 13,149 $ 3,920 $ 17,069

Organization and Basis of Pre47

Organization and Basis of Presentation (Details) $ in Thousands	Feb. 02, 2017location	Feb. 02, 2017MMBbls	Feb. 02, 2017bbl	Feb. 01, 2017USD ($)	Mar. 31, 2017USD ($)itemshares	Mar. 31, 2016USD ($)	Apr. 25, 2017USD ($)	Dec. 31, 2016shares	Feb. 01, 2013
Organization
Number of owned, leased and/or supplied gasoline stations | item					1,445
Number of convenience stores | item					243
Number of common units held | shares					33,554,328			33,543,669
Number of sites in sales portfolio | location	6
Aggregate storage capacity (in million barrels)		1.1	1.1
Cash price					$ 24,249	$ 8,588
Percentage of outstanding membership interests acquired									60.00%
General partner units
Organization
General partner interest (as a percent)					0.67%
Affiliates of general partner
Organization
General partner interest (as a percent)					21.90%
Number of common units held | shares					7,433,829
Limited partner ownership interest (as a percent)					21.90%
Third Amended and Restated Credit Agreement [Member] | Subsequent event
Organization
Total available commitments							$ 1,300,000
Sale of Natural Gas Brokerage And Electricity Businesses [Member]
Organization
Gross proceeds				$ 17,300
Proceeds from sale of business				16,300
Sale of Natural Gas Brokerage And Electricity Businesses [Member] | Commercial Segment
Organization
Gross proceeds				17,300
Proceeds from sale of business				16,300
Realized gain on sale				$ 14,200
Basin Transload LLC
Organization
Percentage of outstanding membership interests acquired									60.00%

Organization and Basis of Pre48

Organization and Basis of Presentation - Risk, Impairment, etc.(Details) - customer	3 Months Ended		12 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Concentration of Risk
Number of significant customers	0	0
Sales Revenue | Product
Concentration of Risk
Percentage of consolidated total	100.00%		100.00%
Sales Revenue | Product | Gasoline sales: gasoline and gasoline blendstocks (such as ethanol)
Concentration of Risk
Percentage of consolidated total	59.00%		57.00%
Sales Revenue | Product | Crude oil sales and crude oil logistics revenue
Concentration of Risk
Percentage of consolidated total	5.00%		8.00%
Sales Revenue | Product | Distillates (home heating oil, diesel and kerosene), residual oil, natural gas and propane sales
Concentration of Risk
Percentage of consolidated total	33.00%		30.00%
Sales Revenue | Product | Convenience store sales, rental income and sundry sales
Concentration of Risk
Percentage of consolidated total	3.00%		5.00%
Product Margin [Member]
Concentration of Risk
Percentage of consolidated total	100.00%		100.00%
Product Margin [Member] | Wholesale Segment
Concentration of Risk
Percentage of consolidated total	32.00%		25.00%
Product Margin [Member] | Gasoline Distribution and Station Operations
Concentration of Risk
Percentage of consolidated total	65.00%		70.00%
Product Margin [Member] | Commercial Segment
Concentration of Risk
Percentage of consolidated total	3.00%		5.00%

Net Income (Loss) Per Limited49

Net Income (Loss) Per Limited Partner Unit (Details) - USD ($) $ / shares in Units, $ in Thousands	Apr. 28, 2017	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Net Income Per Limited Partner Unit
Repurchased units not deemed outstanding		441,235		451,894
Net income (loss) attributable to Global Partners LP		$ 22,946	$ (7,024)
Declared distribution		15,829	15,829
Assumed allocation of undistributed net income (loss)		7,117	(22,853)
Assumed allocation of net income (loss)		$ 22,946	$ (7,024)
Denominator:
Basic weighted average limited partner units outstanding		33,554,000	33,517,000
Diluted weighted average limited partner units outstanding		33,610,000	33,517,000
Basic net income (loss) per limited partner unit		$ 0.68	$ (0.21)
Diluted net income (loss) per limited partner unit		$ 0.68	$ (0.21)
Subsequent event
Denominator:
Quarterly cash distribution declared (in dollars per unit)	$ 0.4625
Common units
Net Income Per Limited Partner Unit
Net income (loss) attributable to Global Partners LP		$ 22,792	$ (6,977)
Declared distribution		15,723	15,723
Assumed allocation of undistributed net income (loss)		7,069	(22,700)
Assumed allocation of net income (loss)		$ 22,792	$ (6,977)
Denominator:
Basic weighted average limited partner units outstanding		33,554,000	33,517,000
Dilutive effect of phantom units		56,000
Diluted weighted average limited partner units outstanding		33,610,000	33,517,000
Basic net income (loss) per limited partner unit		$ 0.68	$ (0.21)
Diluted net income (loss) per limited partner unit		$ 0.68	$ (0.21)
General partner units
Net Income Per Limited Partner Unit
Net income (loss) attributable to Global Partners LP		$ 154	$ (47)
Declared distribution		106	106
Assumed allocation of undistributed net income (loss)		48	(153)
Assumed allocation of net income (loss)		$ 154	$ (47)

Inventories (Details)

Inventories (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Inventories
Inventories	$ 433,952	$ 521,878
Positive exchange balances on inventory exchange agreements accounted for as accounts receivable	3,500	4,000
Negative exchange balances on inventory exchange agreements accounted for as accounts payable	7,400	13,400
Distillates: home heating oil, diesel and kerosene
Inventories
Inventories	157,037	180,272
Gasoline
Inventories
Inventories	70,093	101,368
Gasoline blendstocks
Inventories
Inventories	49,276	54,582
Crude Oil
Inventories
Inventories	121,577	136,113
Residual oil
Inventories
Inventories	18,319	29,536
Propane and other
Inventories
Inventories	976	3,167
Renewable identification numbers (RINs)
Inventories
Inventories	640	631
Convenience store inventory
Inventories
Inventories	$ 16,034	$ 16,209

Goodwill (Details)

Goodwill (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2017USD ($)
Roll forward of the Partnership's goodwill
Goodwill, Beginning Balance	$ 294,768
Goodwill, Ending Balance	292,773
Gasoline Distribution and Station Operations
Roll forward of the Partnership's goodwill
Goodwill, Beginning Balance	294,768
Disposals	(1,995)
Goodwill, Ending Balance	$ 292,773

Property and Equipment (Details

Property and Equipment (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Property and Equipment
Total property and equipment	$ 1,531,043	$ 1,535,418
Less accumulated depreciation	456,578	435,519
Total	1,074,465	1,099,899
West Coast Of USA [Member]
Property and Equipment
Long-lived assets subject to impairment	61,500
Buildings, docks, terminal facilities and improvements
Property and Equipment
Total property and equipment	994,236	984,373
Land
Property and Equipment
Total property and equipment	411,777	418,025
Fixtures and equipment
Property and Equipment
Total property and equipment	41,304	40,354
Idle Plant Assets [Member]
Property and Equipment
Total property and equipment	30,500	30,500
Construction in process
Property and Equipment
Total property and equipment	33,129	42,069
Capitalized internal use software
Property and Equipment
Total property and equipment	$ 20,097	$ 20,097

Sales and Disposition of Asse53

Sales and Disposition of Assets (Details) $ in Thousands	Mar. 31, 2017USD ($)locationitem	Feb. 02, 2017location	Feb. 01, 2017USD ($)	Mar. 31, 2017USD ($)locationitem	Mar. 31, 2016USD ($)	Apr. 30, 2017item	Dec. 31, 2016USD ($)location
Sales and Disposition of Assets
Other				$ 16	$ (10)
Net (gain) loss on sale and disposition of assets				$ (11,862)	6,105
Number of sites in sales portfolio | location		6
Sites held for sale, expected period				12 months
Property and Equipment [Member]
Sales and Disposition of Assets
Assets held for sale	$ 11,900			$ 11,900			$ 17,500
Gasoline Distribution and Station Operations
Sales and Disposition of Assets
Goodwill derecognized				1,995
Loss on sale and disposition of assets and impairment charges
Sales and Disposition of Assets
Loss on assets held-for-sale				200
Disposal Group, Held-for-sale, Not Discontinued Operations [Member]
Sales and Disposition of Assets
Loss on assets held-for-sale				2,051	5,536
Sale of Natural Gas Brokerage And Electricity Businesses [Member]
Sales and Disposition of Assets
Proceeds before adjustments			$ 17,300
Proceeds from sale of business			16,300
Sale of Natural Gas Brokerage And Electricity Businesses [Member] | Commercial Segment
Sales and Disposition of Assets
Proceeds before adjustments			17,300
Proceeds from sale of business			$ 16,300
Sale of Natural Gas Brokerage And Electricity Businesses [Member] | Disposal Group, Held-for-sale, Not Discontinued Operations [Member] | Loss on sale and disposition of assets and impairment charges | Commercial Segment
Sales and Disposition of Assets
(Gain) loss on sale and divestitures				(14,172)
Periodic Divestiture Of Gasoline Stations (Member) | Loss on sale and disposition of assets and impairment charges
Sales and Disposition of Assets
Loss on assets held-for-sale					5,500
Periodic Divestiture Of Gasoline Stations (Member) | Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Loss on sale and disposition of assets and impairment charges | Gasoline Distribution and Station Operations
Sales and Disposition of Assets
(Gain) loss on sale and divestitures				$ (180)	579
Periodic Divestiture Of Gasoline Stations (Member) | Disposal Group, Held-for-sale, Not Discontinued Operations [Member]
Sales and Disposition of Assets
Number of sites classified as held for sale | location	15			15			17
Real Estate Firm Coordinated Sale [Member] | Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member]
Sales and Disposition of Assets
Number of locations divested | location				45
Number of sites classified as held for sale | item	16			16
Real Estate Firm Coordinated Sale [Member] | Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Gasoline Distribution and Station Operations
Sales and Disposition of Assets
Goodwill derecognized				$ 2,000
Real Estate Firm Coordinated Sale [Member] | Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Loss on sale and disposition of assets and impairment charges
Sales and Disposition of Assets
Loss on assets held-for-sale				1,900
Real Estate Firm Coordinated Sale [Member] | Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Loss on sale and disposition of assets and impairment charges | Gasoline Distribution and Station Operations
Sales and Disposition of Assets
Loss on strategic asset sale				$ (423)
Real Estate Firm Coordinated Sale [Member] | Disposal Group, Held-for-sale, Not Discontinued Operations [Member] | Gasoline Distribution and Station Operations
Sales and Disposition of Assets
Number of sites in sales portfolio | location	75			75
Number of sites classified as held for sale | location	22			22
Real Estate Firm Coordinated Sale [Member] | Disposal Group, Held-for-sale, Not Discontinued Operations [Member] | Loss on sale and disposition of assets and impairment charges
Sales and Disposition of Assets
Loss on assets held-for-sale					$ 0
Subsequent event | Real Estate Firm Coordinated Sale [Member] | Disposal Group, Held-for-sale, Not Discontinued Operations [Member]
Sales and Disposition of Assets
Number of additional sites classified as held for sale | item						1

Debt and Financing Obligations

Debt and Financing Obligations (Details) $ in Thousands	Apr. 25, 2017USD ($)item	Mar. 31, 2017USD ($)item	Mar. 31, 2016	Dec. 31, 2016USD ($)	Feb. 24, 2016USD ($)	Feb. 23, 2016USD ($)
Debt and Financing Obligations
Working capital revolving credit facility-current portion		$ 176,900		$ 274,600
Credit Agreement Maturing 2018 [Member]
Debt and Financing Obligations
Average interest rates (as a percent)		3.40%	3.80%
Total borrowings outstanding		$ 527,600
Total remaining availability for borrowings and letters of credit		908,300		764,800,000
Credit Agreement Maturing 2018 [Member] | Subsequent event
Debt and Financing Obligations
Total available commitments	$ 1,600,000
All Revolving credit facilities
Debt and Financing Obligations
Total available commitments		$ 1,475,000
Number of line of credit facilities | item		2
Working Capital Facility [Member]
Debt and Financing Obligations
Total available commitments		$ 900,000,000			$ 900,000	$ 1,000,000
Estimated borrowings in next year		150,000
Long-term portion		150,000		150,000
Working capital revolving credit facility-current portion		176,900		274,600
Reduction of debt outstanding				97,700
Working Capital Facility [Member] | Subsequent event
Debt and Financing Obligations
Total available commitments	850,000
Credit Facility Swingline Feature [Member]
Debt and Financing Obligations
Total available commitments		50,000
Credit Facility Swingline Feature [Member] | Subsequent event
Debt and Financing Obligations
Total available commitments	75,000
Revolving Credit Facility [Member]
Debt and Financing Obligations
Total available commitments		575,000			$ 575,000	$ 775,000
Total borrowings outstanding		200,700
Revolving Credit Facility [Member] | Subsequent event
Debt and Financing Obligations
Total available commitments	450,000
Credit Facility Accordion Feature [Member]
Debt and Financing Obligations
Total available commitments		300,000
Credit Facility Accordion Feature [Member] | Subsequent event
Debt and Financing Obligations
Total available commitments	300,000
Letter of credit
Debt and Financing Obligations
Outstanding letters of credit		39,100
Third Amended and Restated Credit Agreement [Member] | Subsequent event
Debt and Financing Obligations
Total available commitments	$ 1,300,000
Number of line of credit facilities | item	2
Debt instrument, minimum amount	$ 25,000
Cap on repayment of junior indebtedness	100,000
Maximum outstanding loans in Canadian Dollars	200,000
General Secured Indebtedness Basket [Member] | Subsequent event
Debt and Financing Obligations
Total available commitments	25,000
General Investment Basket [Member] | Subsequent event
Debt and Financing Obligations
Total available commitments	25,000
Secured Indebtedness [Member] | Subsequent event
Debt and Financing Obligations
Total available commitments	75,000
Sale/Leaseback Transaction [Member]
Debt and Financing Obligations
Total available commitments		75,000
Sale/Leaseback Transaction [Member] | Subsequent event
Debt and Financing Obligations
Total available commitments	100,000
Basket For Purchase of Common Units Of Partnership [Member] | Subsequent event
Debt and Financing Obligations
Total available commitments	$ 50,000
Senior Notes 6.25 Percent Due 2022
Debt and Financing Obligations
Aggregate principal amount		$ 375,000		$ 375,000
Stated interest rate (as a percent)		6.25%		6.25%
Senior Notes 7.00 Percent Due 2023 [Member]
Debt and Financing Obligations
Aggregate principal amount		$ 300,000		$ 300,000
Stated interest rate (as a percent)		7.00%
Maximum | Credit Agreement Maturing 2018 [Member] | Subsequent event
Debt and Financing Obligations
Commitment fee on the unused portion (as a percent)	0.50%
Minimum | Credit Agreement Maturing 2018 [Member] | Subsequent event
Debt and Financing Obligations
Commitment fee on the unused portion (as a percent)	0.35%
Eurocurrency/Eurodollar rate | Maximum | Working Capital Facility [Member] | Subsequent event
Debt and Financing Obligations
Interest rate margin (as a percent)	2.50%
Eurocurrency/Eurodollar rate | Maximum | Revolving Credit Facility [Member]
Debt and Financing Obligations
Interest rate margin (as a percent)		3.50%
Eurocurrency/Eurodollar rate | Maximum | Revolving Credit Facility [Member] | Subsequent event
Debt and Financing Obligations
Interest rate margin (as a percent)	3.00%
Eurocurrency/Eurodollar rate | Minimum | Working Capital Facility [Member] | Subsequent event
Debt and Financing Obligations
Interest rate margin (as a percent)	2.00%
Eurocurrency/Eurodollar rate | Minimum | Revolving Credit Facility [Member]
Debt and Financing Obligations
Interest rate margin (as a percent)		2.25%
Eurocurrency/Eurodollar rate | Minimum | Revolving Credit Facility [Member] | Subsequent event
Debt and Financing Obligations
Interest rate margin (as a percent)	2.00%
Cost of funds rate | Maximum | Working Capital Facility [Member] | Subsequent event
Debt and Financing Obligations
Interest rate margin (as a percent)	2.50%
Cost of funds rate | Maximum | Revolving Credit Facility [Member]
Debt and Financing Obligations
Interest rate margin (as a percent)		3.50%
Cost of funds rate | Maximum | Revolving Credit Facility [Member] | Subsequent event
Debt and Financing Obligations
Interest rate margin (as a percent)	3.00%
Cost of funds rate | Minimum | Working Capital Facility [Member] | Subsequent event
Debt and Financing Obligations
Interest rate margin (as a percent)	2.00%
Cost of funds rate | Minimum | Revolving Credit Facility [Member]
Debt and Financing Obligations
Interest rate margin (as a percent)		2.25%
Cost of funds rate | Minimum | Revolving Credit Facility [Member] | Subsequent event
Debt and Financing Obligations
Interest rate margin (as a percent)	2.00%
Base rate | Maximum | Working Capital Facility [Member] | Subsequent event
Debt and Financing Obligations
Interest rate margin (as a percent)	1.50%
Base rate | Maximum | Revolving Credit Facility [Member]
Debt and Financing Obligations
Interest rate margin (as a percent)		2.50%
Base rate | Maximum | Revolving Credit Facility [Member] | Subsequent event
Debt and Financing Obligations
Interest rate margin (as a percent)	2.00%
Base rate | Minimum | Working Capital Facility [Member] | Subsequent event
Debt and Financing Obligations
Interest rate margin (as a percent)	1.00%
Base rate | Minimum | Revolving Credit Facility [Member]
Debt and Financing Obligations
Interest rate margin (as a percent)		1.25%
Base rate | Minimum | Revolving Credit Facility [Member] | Subsequent event
Debt and Financing Obligations
Interest rate margin (as a percent)	1.00%

Debt and Financing Obligation55

Debt and Financing Obligations - Financing Obligations (Details) $ in Thousands	Jun. 29, 2016USD ($)locationitem	Jun. 01, 2015USD ($)item	Mar. 31, 2017USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2016USD ($)	Feb. 24, 2016USD ($)	Feb. 23, 2016USD ($)
Financing Obligations
Financing obligations			$ 152,466		$ 152,444
Unamortized fees			12,500		14,100
Write-off of a portion of the original issue discount and deferred financing fees				$ 1,828
Amortization expenses			1,535	1,429
Disposal Group, Disposed of by Means Other than Sale, Not Discontinued Operations [Member] | Sale Leaseback Sites [Member]
Financing Obligations
Financing obligations	$ 62,500		62,500
Number of sites under financing obligation | location	30
Interest expense for sale-leaseback properties			1,100
Sale leaseback, gross proceeds	$ 63,500
Initial lease term	15 years
Number of 5-year options | item	2
Number of 10-year options | item	1
Sale leaseback financing fees	$ 1,000
Unamortized fees			900		1,000
Capitol Petroleum Group
Financing Obligations
Financing obligations		$ 89,600	89,900
Number of sale-leaseback transactions | item		2
Number of sites under financing obligation | item		53
Lease rental payments			2,400	2,300
Long-Term Debt Caption [Member]
Financing Obligations
Unamortized fees			6,300		6,600
Interest Expense [Member]
Financing Obligations
Amortization expenses			1,500	1,400
Interest Expense [Member] | Capitol Petroleum Group
Financing Obligations
Interest expense for sale-leaseback properties			2,400	2,400
Credit Agreement Maturing 2018 [Member] | Other Assets, Current and Noncurrent [Member]
Financing Obligations
Unamortized fees			5,300		$ 6,500
All Revolving credit facilities
Financing Obligations
Total available commitments			1,475,000
Working Capital Facility [Member]
Financing Obligations
Total available commitments			900,000,000			$ 900,000	$ 1,000,000
Working Capital Facility [Member] | Interest Expense [Member]
Financing Obligations
Write-off of a portion of the original issue discount and deferred financing fees				$ 1,800
Revolving Credit Facility [Member]
Financing Obligations
Total available commitments			$ 575,000			$ 575,000	$ 775,000

Derivative Financial Instrume56

Derivative Financial Instruments (Details) $ in Millions	Mar. 31, 2017USD ($)item
Exchange-Traded Derivatives | Long [Member]
Volume of activity related to derivative financial instruments
Nonmonetary units	66,871
Exchange-Traded Derivatives | Short [Member]
Volume of activity related to derivative financial instruments
Nonmonetary units	72,498
OTC Derivatives (Petroleum/Ethanol) | Long [Member]
Volume of activity related to derivative financial instruments
Nonmonetary units	6,928
OTC Derivatives (Petroleum/Ethanol) | Short [Member]
Volume of activity related to derivative financial instruments
Nonmonetary units	3,562
Interest Rate Swaps
Volume of activity related to derivative financial instruments
Monetary units | $	$ 100

Derivative Financial Instrume57

Derivative Financial Instruments - FV Hedges (Details) - Fair Value Hedge - Cost of sales - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Futures contracts
Fair values of derivative financial instruments
Amount of Gain (Loss) Recognized in Income on Derivatives	$ 20,696	$ 27,839
Inventories
Fair values of derivative financial instruments
Amount of Gain (Loss) Recognized in Income on Hedged Items	$ (20,845)	$ (24,175)

Derivative Financial Instrume58

Derivative Financial Instruments - CF Hedges (Details) $ in Thousands	Mar. 31, 2017USD ($)DerivativeInstrument	Dec. 31, 2016USD ($)
Senior Notes 6.25 Percent Due 2022
Fair values of derivative financial instruments
Aggregate principal amount	$ 375,000	$ 375,000
Stated interest rate (as a percent)	6.25%	6.25%
Cash Flow Hedges
Fair values of derivative financial instruments
Hedged borrowings	$ 100,000
Cash Flow Hedges | Interest Rate Swaps
Fair values of derivative financial instruments
Number of agreements in place | DerivativeInstrument	1

Derivative Financial Instrume59

Derivative Financial Instruments - CF Hedges Gain, Loss (Details) - Cash Flow Hedges - Derivatives designated as hedging instruments - USD ($)	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Gains and losses from derivatives
Amount of Gain (Loss) Recognized in Other Comprehensive Income on Derivatives	$ 398,000	$ 28,000
Gain (Loss) on Interest Rate Cash Flow Hedge Ineffectiveness	$ 0	$ 0

Derivative Financial Instrume60

Derivative Financial Instruments - Not Designated (Details) - Derivatives not designated as hedging instruments $ in Thousands	3 Months Ended
	Mar. 31, 2017USD ($)item	Mar. 31, 2016USD ($)
Derivative Financial Instruments
Amount of Gain (Loss) Recognized in Income on Derivatives	$ 1,554	$ (376)
Commodity product | Cost of sales
Derivative Financial Instruments
Amount of Gain (Loss) Recognized in Income on Derivatives	$ 1,554	(415)
Commodity product | Maximum
Derivative Financial Instruments
Aggregate units of products in a controlled trading program | item	250,000
Foreign Exchange | Cost of sales
Derivative Financial Instruments
Amount of Gain (Loss) Recognized in Income on Derivatives		$ 39

Derivative Financial Instrume61

Derivative Financial Instruments - Fair Value (Details) $ in Thousands	Mar. 31, 2017USD ($)item	Dec. 31, 2016USD ($)
Fair values of derivative financial instruments
Asset Derivatives	$ 29,944	$ 81,400
Liability Derivatives	$ (45,112)	(159,291)
Credit Risk
Number of clearing brokers, primarily utilized | item	3
Exchange-Traded Derivatives | Broker margin deposits
Fair values of derivative financial instruments
Asset Derivatives	$ 27,224	60,018
Liability Derivatives	(39,353)	(130,708)
Forward derivative contracts | Derivative assets
Fair values of derivative financial instruments
Asset Derivatives	2,720	21,382
Forward derivative contracts | Derivative liabilities
Fair values of derivative financial instruments
Liability Derivatives	(4,986)	(27,413)
Interest Rate Cap | Other long-term liabilities
Fair values of derivative financial instruments
Liability Derivatives	(773)
Interest Rate Swaps | Other long-term liabilities
Fair values of derivative financial instruments
Liability Derivatives		(1,170)
Derivatives designated as hedging instruments
Fair values of derivative financial instruments
Asset Derivatives	4,006
Liability Derivatives	(6,282)	(33,877)
Derivatives designated as hedging instruments | Exchange-Traded Derivatives | Broker margin deposits
Fair values of derivative financial instruments
Asset Derivatives	4,006
Liability Derivatives	(6,282)	(33,877)
Derivatives not designated as hedging instruments
Fair values of derivative financial instruments
Asset Derivatives	25,938	81,400
Liability Derivatives	(38,830)	(125,414)
Derivatives not designated as hedging instruments | Exchange-Traded Derivatives | Broker margin deposits
Fair values of derivative financial instruments
Asset Derivatives	23,218	60,018
Liability Derivatives	(33,071)	(96,831)
Derivatives not designated as hedging instruments | Forward derivative contracts | Derivative assets
Fair values of derivative financial instruments
Asset Derivatives	2,720	21,382
Derivatives not designated as hedging instruments | Forward derivative contracts | Derivative liabilities
Fair values of derivative financial instruments
Liability Derivatives	(4,986)	(27,413)
Derivatives not designated as hedging instruments | Interest Rate Cap | Other long-term liabilities
Fair values of derivative financial instruments
Liability Derivatives	$ (773)
Derivatives not designated as hedging instruments | Interest Rate Swaps | Other long-term liabilities
Fair values of derivative financial instruments
Liability Derivatives		$ (1,170)

Fair Value Measurements (Detail

Fair Value Measurements (Details) $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2017USD ($)$ / item	Dec. 31, 2016USD ($)$ / item
Senior Notes 6.25 Percent Due 2022
Liabilities:
Stated interest rate (as a percent)	6.25%	6.25%
Face value of debt instrument	$ 375,000	$ 375,000
Fair value of debt instrument	$ 367,500	361,163
Senior Notes 7.00 Percent Due 2023 [Member]
Liabilities:
Stated interest rate (as a percent)	7.00%
Face value of debt instrument	$ 300,000	300,000
Fair value of debt instrument	297,000	289,500
Level 3
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, beginning of period	(371)
Purchases	(192)
Sales	183
Recognized gains (losses) recorded in cost of sales	648
Unrecognized gains (losses) recorded in cost of sales	(382)
Fair Value, end of period	$ (114)	$ (371)
Minimum | Level 3
Liabilities:
Estimated margin, crude oil (in dollars per barrel) | $ / item	0.20	4.05
Estimated margin, propane (in dollars per barrel) | $ / item	0	4.20
Maximum | Level 3
Liabilities:
Estimated margin, crude oil (in dollars per barrel) | $ / item	4.90	6.50
Estimated margin, propane (in dollars per barrel) | $ / item	9.24	10.50
Recurring basis
Assets:
Cash collateral netting	$ 31,014	$ 98,344
Recurring basis | Exchange-Traded Derivatives
Assets:
Cash collateral netting	31,014	98,344
Recurring basis | Total estimated fair value
Assets:
Pension plans	17,199	16,777
Total assets	38,805	65,813
Liabilities:
Total liabilities	(5,759)	(28,583)
Recurring basis | Total estimated fair value | Forward derivative contracts
Assets:
Derivative assets	2,512	20,655
Liabilities:
Derivative liabilities	(4,865)	(27,151)
Recurring basis | Total estimated fair value | Swap agreements and option contracts
Assets:
Derivative assets	208
Liabilities:
Derivative liabilities	(121)	(262)
Recurring basis | Total estimated fair value | Foreign Currency Derivatives
Assets:
Derivative assets		727
Recurring basis | Total estimated fair value | Interest Rate Swaps
Liabilities:
Derivative liabilities	(773)	(1,170)
Recurring basis | Total estimated fair value | Exchange-Traded Derivatives
Assets:
Exchange-traded/cleared derivative instruments	18,886	27,654
Recurring basis | Total estimated fair value | Level 1
Assets:
Pension plans	17,199	16,777
Total pre-netting liabilities	5,071	(53,913)
Recurring basis | Total estimated fair value | Level 1 | Exchange-Traded Derivatives
Assets:
Exchange-traded/cleared derivative instruments	(12,128)	(70,690)
Recurring basis | Total estimated fair value | Level 2
Assets:
Total assets	2,407	19,699
Liabilities:
Total liabilities	(5,332)	(26,529)
Recurring basis | Total estimated fair value | Level 2 | Forward derivative contracts
Assets:
Derivative assets	2,199	18,972
Liabilities:
Derivative liabilities	(4,438)	(25,097)
Recurring basis | Total estimated fair value | Level 2 | Swap agreements and option contracts
Assets:
Derivative assets	208
Liabilities:
Derivative liabilities	(121)	(262)
Recurring basis | Total estimated fair value | Level 2 | Foreign Currency Derivatives
Assets:
Derivative assets		727
Recurring basis | Total estimated fair value | Level 2 | Interest Rate Swaps
Liabilities:
Derivative liabilities	(773)	(1,170)
Recurring basis | Total estimated fair value | Level 3
Assets:
Total assets	313	1,683
Liabilities:
Total liabilities	(427)	(2,054)
Recurring basis | Total estimated fair value | Level 3 | Forward derivative contracts
Assets:
Derivative assets	313	1,683
Liabilities:
Derivative liabilities	$ (427)	$ (2,054)

Environmental Liabilities, As63

Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2017	Dec. 31, 2016
Changes in environmental liabilities during the period
Balance at the beginning of the period	$ 63,065
Payments	(846)
Dispositions	(1,050)
Other adjustments	(725)
Balance at the end of the period	60,444
Environmental liabilities
Current portion		$ 5,339	$ 5,341
Long-term portion		55,105	57,724
Total environmental liabilities	$ 63,065	60,444	63,065
Renewable Identification Numbers (RINs)
Settlement period of RVO	1 year
RIN Deficiency			200
Other long-term liabilities
Asset Retirement Obligations
Total assets retirement obligations		7,800	8,300
Retail Gasoline Stations
Changes in environmental liabilities during the period
Balance at the beginning of the period	$ 58,456
Payments	(813)
Dispositions	(1,050)
Other adjustments	(725)
Balance at the end of the period	55,868
Environmental liabilities
Total environmental liabilities	58,456	55,868	58,456
Terminals
Changes in environmental liabilities during the period
Balance at the beginning of the period	4,609
Payments	(33)
Balance at the end of the period	4,576
Environmental liabilities
Total environmental liabilities	$ 4,609	$ 4,576	$ 4,609

Related-Party Transactions (Det

Related-Party Transactions (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Information on related party transaction
Receivables from related parties	$ 2,957		$ 3,143
GPC
Information on related party transaction
Receivables from related parties	$ 72		6
GPC | Terminal Storage Rental and Throughput Agreement [Member]
Related Party Transactions
Equity Method Investment, Ownership Percentage	100.00%
GPC | GPC Amended and Restated Services Agreement [Member]
Information on related party transaction
Notice period to terminate the receipt of services under the agreement	90 days
General partner units
Information on related party transaction
Expenses incurred from transactions with related parties	$ 24,600	$ 25,700
Receivables from related parties	$ 2,885		$ 3,137

Long-Term Incentive Plan (Detai

Long-Term Incentive Plan (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		80 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2015
Long-Term Incentive Plan
Number of common units initially authorized for issuance under LTIP (in shares)	4,300,000
Number of Non-vested Units
Outstanding non-vested units at the beginning of the period (in shares)	571,554
Vested (in shares)	(10,659)
Forfeited (in shares)	(51,203)
Outstanding non-vested units at the end of the period (in shares)	509,692
Weighted Average Grant Date Fair Value
Outstanding non-vested units at the beginning of the period (in dollars per share)	$ 38.56
Vested (in dollars per share)	35.94
Forfeited (in dollars per share)	38.19
Outstanding non-vested units at the end of the period (in dollars per share)	$ 38.66
Repurchase Program
Aggregate common units authorized to be acquired (in shares)	1,242,427
Common units repurchased by General Partner (in shares)			838,505
Common units repurchased by General Partner	$ 0	$ 0	$ 24,800
Phantom Unit Awards [Member]
Long-Term Incentive Plan
Unrecognized compensation cost related to the non-vested awards	8,100
Phantom Unit Awards [Member] | Selling, general and administrative expenses
Long-Term Incentive Plan
Compensation expenses	1,100	$ 1,100
Reversal of stock based compensation	$ 1,200

Partners' Equity and Cash Dis66

Partners' Equity and Cash Distributions (Details) $ / shares in Units, $ in Thousands	Apr. 28, 2017$ / shares	Feb. 14, 2017USD ($)$ / shares	Mar. 31, 2017item$ / sharesshares
Increase (Decrease) in Partners' Capital [Roll Forward]
Period of distribution of available cash after end of each quarter			45 days
Number of quarters of cash reserves to provide funds for distributions to unitholders and General Partner | item			4
Cash Distribution Payment
Per Unit Cash Distribution (in dollars per unit)		$ 0.4625
Cash distribution | $		$ 15,829
Affiliates of general partner
Partners' Equity and Cash Distributions
Limited partner ownership interest (as a percent)			21.90%
General partner interest (as a percent)			21.90%
Subsequent event
Distribution declared
Quarterly cash distribution declared (in dollars per unit)	$ 0.4625
Subsequent event | Annualized basis
Distribution declared
Quarterly cash distribution declared (in dollars per unit)	$ 1.85
Common units
Partners' Equity and Cash Distributions
Limited partner ownership interest (as a percent)			99.33%
Increase (Decrease) in Partners' Capital [Roll Forward]
Units, ending balance | shares			33,995,563
Cash Distribution Payment
Cash distribution | $		15,723
Common units | Affiliates of general partner
Increase (Decrease) in Partners' Capital [Roll Forward]
Units, ending balance | shares			7,433,829
General partner units
Partners' Equity and Cash Distributions
General partner interest (as a percent)			0.67%
Increase (Decrease) in Partners' Capital [Roll Forward]
Units, ending balance | shares			230,303
Cash Distribution Payment
Cash distribution | $		$ 106
First Target Distribution | Maximum
Increase (Decrease) in Partners' Capital [Roll Forward]
Total Quarterly Distribution Target Amount (in dollars per unit)			$ 0.4625
First Target Distribution | Common units
Increase (Decrease) in Partners' Capital [Roll Forward]
Marginal Percentage Interest in Distributions			99.33%
First Target Distribution | General partner units
Increase (Decrease) in Partners' Capital [Roll Forward]
Marginal Percentage Interest in Distributions			0.67%
Second Target Distribution | Minimum
Increase (Decrease) in Partners' Capital [Roll Forward]
Total Quarterly Distribution Target Amount (in dollars per unit)			$ 0.4625
Second Target Distribution | Maximum
Increase (Decrease) in Partners' Capital [Roll Forward]
Total Quarterly Distribution Target Amount (in dollars per unit)			$ 0.5375
Second Target Distribution | Common units
Increase (Decrease) in Partners' Capital [Roll Forward]
Marginal Percentage Interest in Distributions			86.33%
Second Target Distribution | General partner units
Increase (Decrease) in Partners' Capital [Roll Forward]
Marginal Percentage Interest in Distributions			13.67%
Third Target Distribution | Minimum
Increase (Decrease) in Partners' Capital [Roll Forward]
Total Quarterly Distribution Target Amount (in dollars per unit)			$ 0.5375
Third Target Distribution | Maximum
Increase (Decrease) in Partners' Capital [Roll Forward]
Total Quarterly Distribution Target Amount (in dollars per unit)			$ 0.6625
Third Target Distribution | Common units
Increase (Decrease) in Partners' Capital [Roll Forward]
Marginal Percentage Interest in Distributions			76.33%
Third Target Distribution | General partner units
Increase (Decrease) in Partners' Capital [Roll Forward]
Marginal Percentage Interest in Distributions			23.67%
Thereafter | Minimum
Increase (Decrease) in Partners' Capital [Roll Forward]
Total Quarterly Distribution Target Amount (in dollars per unit)			$ 0.6625
Thereafter | Common units
Increase (Decrease) in Partners' Capital [Roll Forward]
Marginal Percentage Interest in Distributions			51.33%
Thereafter | General partner units
Increase (Decrease) in Partners' Capital [Roll Forward]
Marginal Percentage Interest in Distributions			48.67%

Unitholders' Equity (Details)

Unitholders' Equity (Details) - Common units - At The Market Offering Program - USD ($) $ in Millions	May 19, 2015	Mar. 31, 2017
Aggregate offering price	$ 50
Number of common units sold		0

Segment Reporting (Details)

Segment Reporting (Details) $ in Thousands, gal in Millions	3 Months Ended
	Mar. 31, 2017USD ($)gal	Mar. 31, 2016USD ($)gal
Summarized financial information for the Partnership's reportable segments
Sales	$ 2,270,784	$ 1,750,812
Product margin	162,389	154,460
Depreciation allocated to cost of sales	(22,362)	(24,401)
Gross profit	140,027	130,059
Wholesale Segment
Summarized financial information for the Partnership's reportable segments
Sales	1,225,799	910,240
Product margin	52,150	39,238
Gasoline sales: gasoline and gasoline blendstocks (such as ethanol)
Summarized financial information for the Partnership's reportable segments
Sales	505,704	342,729
Product margin	15,385	16,362
Crude Oil
Summarized financial information for the Partnership's reportable segments
Sales	103,528	148,502
Product margin	6,892	(2,373)
Other oils and related products
Summarized financial information for the Partnership's reportable segments
Sales	616,567	419,009
Product margin	29,873	25,249
Gasoline Distribution and Station Operations
Summarized financial information for the Partnership's reportable segments
Sales	843,232	701,288
Product margin	$ 106,050	$ 108,312
Sales volume supplied by Wholesale to GDSO (in gallons) | gal	113	111
Gasoline
Summarized financial information for the Partnership's reportable segments
Sales	$ 767,636	$ 616,103
Product margin	67,155	65,387
Station operations
Summarized financial information for the Partnership's reportable segments
Sales	75,596	85,185
Product margin	38,895	42,925
Commercial Segment
Summarized financial information for the Partnership's reportable segments
Sales	201,753	139,284
Product margin	$ 4,189	$ 6,910
Intersegment transaction | Gasoline Distribution and Station Operations
Summarized financial information for the Partnership's reportable segments
Sales volume supplied by Wholesale to GDSO (in gallons) | gal	113	111

Segment Reporting - Reconciliat

Segment Reporting - Reconciliation (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Reconciliation of the totals reported for the reportable segments to the applicable line items in the consolidated financial statements
Combined gross profit	$ 140,027	$ 130,059
Operating costs and expenses
Selling, general and administrative expenses	36,787	34,984
Operating expenses	67,213	72,236
Amortization expense	2,261	2,509
Net (gain) loss on sale and disposition of assets	(11,862)	6,105
Total costs and operating expenses	94,399	115,834
Operating income	45,628	14,225
Interest expense	(23,287)	(22,980)
Income tax benefit	164	920
Net income (loss)	22,505	(7,835)
Net loss attributable to noncontrolling interest	441	811
Net income (loss) attributable to Global Partners LP	22,946	(7,024)
Operating costs and expenses not allocated to operating segments
Operating costs and expenses
Selling, general and administrative expenses	36,787	34,984
Operating expenses	67,213	72,236
Amortization expense	2,261	2,509
Net (gain) loss on sale and disposition of assets	(11,862)	6,105
Total costs and operating expenses	$ 94,399	$ 115,834

Segment Reporting - Assets (Det

Segment Reporting - Assets (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Segment assets
Total	$ 2,328,329	$ 2,564,020
Wholesale Segment
Segment assets
Total	729,855	830,662
Commercial Segment
Segment assets
Total	125	134
Gasoline Distribution and Station Operations
Segment assets
Total	1,253,019	1,294,568
Unallocated
Segment assets
Total	$ 345,330	$ 438,656

Income Taxes (Details)

Income Taxes (Details)	3 Months Ended
	Mar. 31, 2017USD ($)item	Mar. 31, 2016USD ($)	Dec. 31, 2016USD ($)
Income Tax Contingency [Line Items]
Income tax provision	$ (164,000)	$ (920,000)
Number of wholly owned subsidiaries which are taxable for federal and state income tax purposes | item	1
Unrecognized tax benefits	$ 1,400,000		$ 1,400,000
Portion of unrecognized tax benefits that would impact the effective tax rate if recognized	1,400,000		$ 1,400,000
Parent Company [Member]
Income Tax Contingency [Line Items]
Income tax provision	$ 0

Changes in Accumulated Other 72

Changes in Accumulated Other Comprehensive Loss (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2017USD ($)
Changes in Accumulated Other Comprehensive Loss
Balance, beginning of period	$ 397,841
Balance, end of period	405,308
Derivatives
Changes in Accumulated Other Comprehensive Loss
Balance, beginning of period	(1,172)
Other comprehensive income before reclassifications of gain (loss)	398
Total other comprehensive income	398
Balance, end of period	(774)
Accumulated Other Comprehensive Loss
Changes in Accumulated Other Comprehensive Loss
Balance, beginning of period	(5,441)
Other comprehensive income before reclassifications of gain (loss)	744
Amount of (loss) gain reclassified from accumulated other comprehensive income	(27)
Total other comprehensive income	717
Balance, end of period	(4,724)
Pension Plan
Changes in Accumulated Other Comprehensive Loss
Balance, beginning of period	(4,269)
Other comprehensive income before reclassifications of gain (loss)	346
Amount of (loss) gain reclassified from accumulated other comprehensive income	(27)
Total other comprehensive income	319
Balance, end of period	$ (3,950)

Supplemental Cash Flow Inform73

Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Supplemental Cash Flow Elements [Abstract]
Borrowing from working capital revolving credit facility	$ 303,600	$ 418,200
Payment on working capital revolving credit facility	(401,300)	(331,100)
Net (payments on) borrowings from working capital revolving credit facility	(97,700)	87,100
Borrowings from revolving credit facility		15,000
Payments on revolving credit facility	(16,000)	(8,900)
Net (payments on) borrowings from revolving credit facility	$ (16,000)	$ 6,100

Legal Proceedings (Details)

Legal Proceedings (Details)	Feb. 03, 2016USD ($)	Oct. 05, 2015item	Mar. 31, 2017agal
Alleged Violations of Clean Air Act at Albany Terminal [Member]
Other legal proceedings
Terminal area (in acres) | a			63
Number of plaintiffs added | item		2
Damages sought | $	$ 37,500
Damages from Product Defects [Member]
Other legal proceedings
Quantity of product affected (in gallons) | gal			14

New Accounting Standards (Detai

New Accounting Standards (Details)	12 Months Ended
	Dec. 31, 2016
New Accounting Standards
Percentage of physical contracts	40.00%

Subsequent Events (Details)

Subsequent Events (Details) $ / shares in Units, $ in Millions	Apr. 28, 2017$ / shares	Mar. 31, 2017USD ($)locationitem	Feb. 02, 2017location	Feb. 02, 2017MMBbls	Feb. 02, 2017bbl	Mar. 31, 2017USD ($)locationitem	Apr. 30, 2017item	Apr. 25, 2017USD ($)
Subsequent Events
Number of sites in sales portfolio			6
Aggregate storage capacity (in million barrels)				1.1	1.1
Sites held for sale, expected period						12 months
Disposal Group, Held-for-sale, Not Discontinued Operations [Member] | Real Estate Firm Coordinated Sale [Member]
Subsequent Events
Net book value of assets held for sale | $		$ 0.1				$ 0.1
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Real Estate Firm Coordinated Sale [Member]
Subsequent Events
Number of locations divested						45
Number of sites classified as held for sale | item		16				16
Gasoline Distribution and Station Operations | Disposal Group, Held-for-sale, Not Discontinued Operations [Member] | Real Estate Firm Coordinated Sale [Member]
Subsequent Events
Number of sites in sales portfolio		75				75
Number of sites classified as held for sale		22				22
Subsequent event
Subsequent Events
Distribution Made to Limited Liability Company (LLC) Member, Distributions Declared, Per Unit | $ / shares	$ 0.4625
Subsequent event | Disposal Group, Held-for-sale, Not Discontinued Operations [Member] | Real Estate Firm Coordinated Sale [Member]
Subsequent Events
Number of additional sites classified as held for sale | item							1
Subsequent event | Annualized basis
Subsequent Events
Distribution Made to Limited Liability Company (LLC) Member, Distributions Declared, Per Unit | $ / shares	$ 1.85
Subsequent event | Third Amended and Restated Credit Agreement [Member]
Subsequent Events
Total available commitments | $								$ 1,300

Supp Guarantor Cond Cons Fin St

Supp Guarantor Cond Cons Fin Stmts - B/S (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016	Dec. 31, 2015
Ownership interest (as a percent)	100.00%	100.00%
Current assets:
Cash and cash equivalents	$ 14,126	$ 17,069	$ 10,028	$ 1,116
Accounts receivable, net	312,314		421,360
Accounts receivable-affiliates	2,957		3,143
Inventories	433,952		521,878
Brokerage margin deposits	18,886		27,653
Derivate assets	2,720		21,382
Prepaid expenses and other current assets	71,110		70,022
Total current assets	856,065		1,075,466
Property and equipment, net	1,074,465		1,099,899
Intangible assets, net	62,443		65,013
Goodwill	292,773		294,768
Other assets	42,583		28,874
Total assets	2,328,329		2,564,020
Current liabilities:
Accounts payable	232,125		320,262
Working capital revolving credit facility-current portion	176,900		274,600
Environmental liabilities-current portion	5,339		5,341
Trustee taxes payable	98,955		101,166
Accrued expenses and other current liabilities	59,171		70,443
Derivative liabilities	4,986		27,413
Total current liabilities	577,476		799,225
Working capital revolving credit facility-less current portion	150,000		150,000
Revolving credit facility	200,700		216,700
Senior notes	659,805		659,150
Environmental liabilities-less current portion	55,105		57,724
Financing obligations	152,466		152,444
Deferred tax liabilities	65,296		66,054
Other long-term liabilities	62,173		64,882
Total liabilities	1,923,021		2,166,179
Partners' equity
Total Global Partners LP equity	400,563		392,655
Noncontrolling interest	4,745		5,186
Total partners' equity	405,308		397,841
Total liabilities and partners' equity	2,328,329		2,564,020
Eliminations
Current assets:
Accounts receivable, net	71		250
Accounts receivable-affiliates	(71)		(250)
(Issuer) Guarantor Subsidiaries
Current assets:
Cash and cash equivalents	13,042	13,149	9,373	(3,574)
Accounts receivable, net	312,072		420,897
Accounts receivable-affiliates	2,957		2,865
Inventories	433,952		521,878
Brokerage margin deposits	18,886		27,653
Derivate assets	2,720		21,382
Prepaid expenses and other current assets	70,841		69,872
Total current assets	854,470		1,073,920
Property and equipment, net	1,063,816		1,087,964
Intangible assets, net	62,443		65,013
Goodwill	292,773		294,768
Other assets	42,583		28,874
Total assets	2,316,085		2,550,539
Current liabilities:
Accounts payable	231,925		320,003
Accounts payable - affiliates	(36)
Working capital revolving credit facility-current portion	176,900		274,600
Environmental liabilities-current portion	5,339		5,341
Trustee taxes payable	98,955		101,166
Accrued expenses and other current liabilities	59,101		70,262
Derivative liabilities	4,986		27,413
Total current liabilities	577,170		798,785
Working capital revolving credit facility-less current portion	150,000		150,000
Revolving credit facility	200,700		216,700
Senior notes	659,805		659,150
Environmental liabilities-less current portion	55,105		57,724
Financing obligations	152,466		152,444
Deferred tax liabilities	65,296		66,054
Other long-term liabilities	62,173		64,882
Total liabilities	1,922,715		2,165,739
Partners' equity
Total Global Partners LP equity	393,370		384,800
Total partners' equity	393,370		384,800
Total liabilities and partners' equity	2,316,085		2,550,539
Non-Guarantor Subsidiary
Current assets:
Cash and cash equivalents	1,084	$ 3,920	655	$ 4,690
Accounts receivable, net	171		213
Accounts receivable-affiliates	71		528
Prepaid expenses and other current assets	269		150
Total current assets	1,595		1,546
Property and equipment, net	10,649		11,935
Total assets	12,244		13,481
Current liabilities:
Accounts payable	200		259
Accounts payable - affiliates	36
Accrued expenses and other current liabilities	70		181
Total current liabilities	306		440
Total liabilities	306		440
Partners' equity
Total Global Partners LP equity	7,193		7,855
Noncontrolling interest	4,745		5,186
Total partners' equity	11,938		13,041
Total liabilities and partners' equity	$ 12,244		$ 13,481

Supp Guarantor Cond Cons Fin 78

Supp Guarantor Cond Cons Fin Stmts - I/S (Details) - USD ($)	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Sales	$ 2,270,784,000	$ 1,750,812,000
Cost of sales	2,130,757,000	1,620,753,000
Gross profit	140,027,000	130,059,000
Costs and operating expenses:
Selling, general and administrative expenses	36,787,000	34,984,000
Operating expenses	67,213,000	72,236,000
Amortization expense	2,261,000	2,509,000
Net (gain) loss on sale and disposition of assets	(11,862,000)	6,105,000
Total costs and operating expenses	94,399,000	115,834,000
Operating income	45,628,000	14,225,000
Interest expense	(23,287,000)	(22,980,000)
Income (loss) before income tax benefit	22,341,000	(8,755,000)
Income tax benefit	164,000	920,000
Net income (loss)	22,505,000	(7,835,000)
Net income attributable to noncontrolling interest	441,000	811,000
Net income (loss) attributable to Global Partners LP	22,946,000	(7,024,000)
Less: General partner’s interest in net income (loss), including incentive distribution rights	154,000	(47,000)
Limited partners' interest in net income (loss)	22,792,000	(6,977,000)
Eliminations
Sales	(6,000)	(2,102,000)
Cost of sales	(6,000)	(2,102,000)
(Issuer) Guarantor Subsidiaries
Sales	2,270,121,000	1,750,281,000
Cost of sales	2,129,652,000	1,620,015,000
Gross profit	140,469,000	130,266,000
Costs and operating expenses:
Selling, general and administrative expenses	36,673,000	34,751,000
Operating expenses	66,649,000	70,649,000
Amortization expense	2,261,000	2,509,000
Net (gain) loss on sale and disposition of assets	(11,845,000)	6,105,000
Total costs and operating expenses	93,738,000	114,014,000
Operating income	46,731,000	16,252,000
Interest expense	(23,287,000)	(22,980,000)
Income (loss) before income tax benefit	23,444,000	(6,728,000)
Income tax benefit	164,000	920,000
Net income (loss)	23,608,000	(5,808,000)
Net income (loss) attributable to Global Partners LP	23,608,000	(5,808,000)
Less: General partner’s interest in net income (loss), including incentive distribution rights	154,000	(47,000)
Limited partners' interest in net income (loss)	23,454,000	(5,761,000)
Non-Guarantor Subsidiary
Sales	669,000	2,633,000
Cost of sales	1,111,000	2,840,000
Gross profit	(442,000)	(207,000)
Costs and operating expenses:
Selling, general and administrative expenses	114,000	233,000
Operating expenses	564,000	1,587,000
Net (gain) loss on sale and disposition of assets	(17,000)
Total costs and operating expenses	661,000	1,820,000
Operating income	(1,103,000)	(2,027,000)
Income (loss) before income tax benefit	(1,103,000)	(2,027,000)
Net income (loss)	(1,103,000)	(2,027,000)
Net income attributable to noncontrolling interest	441,000	811,000
Net income (loss) attributable to Global Partners LP	(662,000)	(1,216,000)
Limited partners' interest in net income (loss)	(662,000)	$ (1,216,000)
Parent Company [Member]
Costs and operating expenses:
Income tax benefit	$ 0

Supp Guarantor Cond Cons Fin 79

Supp Guarantor Cond Cons Fin Stmts - SCF (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Cash flows from operating activities
Net cash provided by (used in) operating activities	$ 117,565	$ (53,516)
Cash flows from investing activities
Capital expenditures	(8,378)	(16,451)
Proceeds from sale of property and equipment	24,249	8,588
Net cash provided by (used in) investing activities	15,871	(7,863)
Cash flows from financing activities
Net borrowings from (payments on) working capital revolving credit facility	(97,700)	87,100
Net borrowings from (payments on) revolving credit facility	(16,000)	6,100
Noncontrolling interest capital contribution		357
Distribution to noncontrolling interest		(595)
Distributions to partners	(15,638)	(15,630)
Net cash (used in) provided by financing activities	(129,338)	77,332
Cash and cash equivalents
Increase in cash and cash equivalents	4,098	15,953
Cash and cash equivalents at beginning of year	10,028	1,116
Cash and cash equivalents at end of year	14,126	17,069
(Issuer) Guarantor Subsidiaries
Cash flows from operating activities
Net cash provided by (used in) operating activities	117,156	(53,341)
Cash flows from investing activities
Capital expenditures	(8,378)	(16,451)
Proceeds from sale of property and equipment	24,229	8,588
Net cash provided by (used in) investing activities	15,851	(7,863)
Cash flows from financing activities
Net borrowings from (payments on) working capital revolving credit facility	(97,700)	87,100
Net borrowings from (payments on) revolving credit facility	(16,000)	6,100
Noncontrolling interest capital contribution		952
Distribution to noncontrolling interest		(595)
Distributions to partners	(15,638)	(15,630)
Net cash (used in) provided by financing activities	(129,338)	77,927
Cash and cash equivalents
Increase in cash and cash equivalents	3,669	16,723
Cash and cash equivalents at beginning of year	9,373	(3,574)
Cash and cash equivalents at end of year	13,042	13,149
Non-Guarantor Subsidiary
Cash flows from operating activities
Net cash provided by (used in) operating activities	409	(175)
Cash flows from investing activities
Proceeds from sale of property and equipment	20
Net cash provided by (used in) investing activities	20
Cash flows from financing activities
Noncontrolling interest capital contribution		(595)
Net cash (used in) provided by financing activities		(595)
Cash and cash equivalents
Increase in cash and cash equivalents	429	(770)
Cash and cash equivalents at beginning of year	655	4,690
Cash and cash equivalents at end of year	$ 1,084	$ 3,920