Sprague Resources (SRLP) 10-Q 7 May 15 2015 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2015	4-May-15
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	31-Mar-15
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Trading Symbol	SRLP
Entity Registrant Name	Sprague Resources LP
Entity Central Index Key	1525287
Current Fiscal Year End Date	-19
Entity Filer Category	Accelerated Filer
Common Units [Member]
Document Information [Line Items]
Entity Common Stock, Shares Outstanding		11,004,292
Subordinated Units [Member]
Document Information [Line Items]
Entity Common Stock, Shares Outstanding		10,071,970

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Mar. 31, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$21,609,000	$4,080,000
Accounts receivable, net	342,174,000	289,424,000
Inventories	217,912,000	390,555,000
Fair value of derivative assets	169,298,000	229,890,000
Deferred income taxes	961,000	895,000
Other current assets	50,115,000	52,416,000
Total current assets	802,069,000	967,260,000
Property, plant and equipment, net	251,336,000	250,126,000
Assets held for sale	68,000	1,321,000
Intangibles, net	25,585,000	27,626,000
Other assets, net	26,322,000	30,219,000
Goodwill	63,288,000	63,288,000
Total assets	1,168,668,000	1,339,840,000
Current liabilities:
Accounts payable	124,972,000	198,609,000
Accrued liabilities	56,510,000	63,816,000
Fair value of derivative liabilities	55,685,000	89,176,000
Current portion of long-term debt	258,678,000	397,214,000
Current portion of capital leases	1,004,000	1,313,000
Total current liabilities	508,818,000	765,468,000
Commitments and contingencies (Note 9)
Long-term debt	469,708,000	418,356,000
Long-term capital leases	4,245,000	5,424,000
Other liabilities	18,157,000	17,884,000
Deferred income taxes	15,190,000	15,826,000
Total liabilities	1,016,966,000	1,223,946,000
Unitholders' equity:
Accumulated other comprehensive loss, net of tax	-11,735,000	-9,833,000
Total unitholders' equity	151,702,000	115,894,000
Total liabilities and unitholders' equity	1,168,668,000	1,339,840,000
Common Unitholders - Public [Member]
Unitholders' equity:
Partners' equity	186,997,000	171,055,000
Common Unitholders - Affiliated [Member]
Unitholders' equity:
Partners' equity	-1,908,000	-5,566,000
Subordinated Unitholders - Affiliated [Member]
Unitholders' equity:
Partners' equity	-21,652,000	-39,762,000
General Partner [Member]
Current liabilities:
Due to General Partner and affiliates	11,969,000	15,340,000
Due to General Partner	$848,000	$988,000

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical)	Mar. 31, 2015	Dec. 31, 2014
Common Unitholders - Public [Member]
Units, issued	8,969,914	8,969,914
Units, outstanding	8,777,922	8,777,922
Common Unitholders - Affiliated [Member]
Units, issued	2,034,378	2,034,378
Units, outstanding	2,034,378	2,034,378
Subordinated Unitholders - Affiliated [Member]
Units, issued	10,071,970	10,071,970
Units, outstanding	10,071,970	10,071,970

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Operations (USD $)	3 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Net sales	$1,598,358	$1,994,699
Cost of products sold (exclusive of depreciation and amortization)	1,490,373	1,864,419
Operating expenses	18,883	16,838
Selling, general and administrative	32,381	27,411
Depreciation and amortization	4,992	3,955
Total operating costs and expenses	1,546,629	1,912,623
Operating income	51,729	82,076
Other income	514
Interest income	112	110
Interest expense	-7,766	-8,016
Income before income taxes	44,589	74,170
Income tax provision	-650	-1,038
Net income	43,939	73,132
Exclude loss attributable to Kildair (Note 1)		2,203
Assumed net income to be allocated	43,939	75,335
Net income per limited partner unit:
Common - basic	$2.10	$3.74
Common - diluted	$2.06	$3.74
Units used to compute net income per limited partner unit:
Common - basic	10,897,488	10,072,186
Common - diluted	11,064,510	10,073,176
Distribution declared per common and subordinated units	$0.47	$0.41
Subordinated Unitholders - Affiliated [Member]
Assumed net income to be allocated	$21,105	$37,667
Net income per limited partner unit:
Common - basic	$2.10	$3.74
Common - diluted	$2.10	$3.74
Subordinated - basic and diluted	$2.10	$3.74
Units used to compute net income per limited partner unit:
Subordinated - basic and diluted	10,071,970	10,071,970

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Comprehensive Income (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Statement of Comprehensive Income [Abstract]
Net income	$43,939	$73,132
Unrealized (loss) gain on interest rate swaps
Net loss arising in the period	-700	-63
Reclassification adjustment related for losses realized in income	130	608
Net change in unrealized loss on interest rate swaps	-570	545
Tax effect	17	-14
Unrealized (loss) gain on interest rate swaps, Total	-553	531
Foreign currency translation adjustment	-1,349	-459
Other comprehensive (loss) income	-1,902	72
Comprehensive income	$42,037	$73,204

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements of Unitholders' Equity (Deficit) (USD $)	Total	Accumulated Other Comprehensive (Loss) Income [Member]	Common-Public [Member]	Common-Sprague Holdings [Member]	Subordinated-Sprague Holdings [Member]	Kildair [Member]	Kildair [Member]	Castle (Romita) [Member]	Castle (Romita) [Member]
In Thousands							Common-Sprague Holdings [Member]		Common-Public [Member]
Beginning balance at Dec. 31, 2013	$71,293	($10,610)	$127,496	($6,155)	($39,438)
Net income	122,814		50,141	9,953	62,720
Other comprehensive (loss) income	777	777
Unit-based compensation	3,617		1,528	286	1,803
Distribution to unitholders	-31,594		-13,370	-2,460	-15,764
Distribution to sponsor for Kildair acquisition	-66,667			-17,652	-49,015
Common units issued for acquisition						10,002	10,002	5,318	5,318
Other contribution from Parent	470			470
Repurchased units withheld for employee tax obligation	-136		-58	-10	-68
Ending balance at Dec. 31, 2014	115,894	-9,833	171,055	-5,566	-39,762
Net income	43,939		18,571	4,263	21,105
Other comprehensive (loss) income	-1,902	-1,902
Unit-based compensation	764		323	74	367
Distribution to unitholders	-9,589		-4,050	-931	-4,608
Common units issued in connection with annual bonus	4,939		2,088	479	2,372
Repurchased units withheld for employee tax obligation	-2,343		-990	-227	-1,126
Ending balance at Mar. 31, 2015	$151,702	($11,735)	$186,997	($1,908)	($21,652)

Condensed_Consolidated_Stateme3

Condensed Consolidated Statements of Cash Flows (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash flows from operating activities
Net income	$43,939	$73,132
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (includes amortization of deferred debt issue costs)	5,898	5,179
Provision for doubtful accounts	730	190
Gain on sale of assets and insurance recoveries	-514	-5
Deferred income taxes	-678	620
Non-cash unit-based compensation	4,068	538
Changes in assets and liabilities:
Accounts receivable	-53,480	-59,883
Inventories	172,643	135,747
Prepaid expenses and other assets	7,230	424
Fair value of commodity derivative instruments	26,531	-52,750
Due to General Partner and affiliates	-3,510	12,928
Accounts payable, accrued liabilities and other	-80,439	-25,617
Net cash provided by operating activities	122,418	90,503
Cash flows from investing activities
Purchases of property, plant and equipment	-3,527	-5,600
Proceeds from property insurance settlement and sale of assets	336	25
Net cash used in investing activities	-3,191	-5,575
Cash flows from financing activities
Net payments under credit agreements	-87,042	-74,016
Payments on capital lease liabilities and term debt	-390	-208
Payments on long-term terminal obligations	-97	-167
Debt issue costs	-1,938
Distribution to unitholders	-9,589	-5,693
Foreign exchange on capital lease obligations	-157	-88
Repurchased units withheld for employee tax obligation	-2,343	-136
Net increase in payable to Parent		147
Net cash used in financing activities	-101,556	-80,161
Effect of exchange rate changes on cash balances held in foreign currencies	-142	34
Net change in cash and cash equivalents	17,529	4,801
Cash and cash equivalents, beginning of period	4,080	2,046
Cash and cash equivalents, end of period	21,609	6,847
Supplemental disclosure of cash flow information
Cash paid for interest	6,929	7,429
Cash paid for taxes	$773	$511

Description_of_Business_and_Su

Description of Business and Summary of Significant Accounting Policies	3 Months Ended
	Mar. 31, 2015
Accounting Policies [Abstract]
Description of Business and Summary of Significant Accounting Policies	1. Description of Business and Summary of Significant Accounting Policies
	Partnership Businesses
	Sprague Resources LP (the “Partnership”) is a Delaware limited partnership formed on June 23, 2011 to engage in activities for which limited partnerships may be organized under the Delaware Revised Limited Partnership Act including, but not limited to, actions to form a limited liability company and/or acquire assets owned by Sprague Operating Resources LLC, a Delaware limited liability company and the Partnership’s operating company (the “Predecessor” and “OLLC”), an entity engaged in the sales and marketing of energy products, as well as materials handling operations.
	Unless the context otherwise requires, references to “Sprague Resources,” and the “Partnership,” when used in a historical context prior to October 30, 2013, refer to Sprague Operating Resources LLC, the “Predecessor” for accounting purposes and the successor to Sprague Energy Corp., also referenced as “the Predecessor” and when used in the present tense or prospectively, refer to Sprague Resources LP and its subsidiaries. Unless the context otherwise requires, references to “Axel Johnson” or the “Parent” refer to Axel Johnson Inc. and its controlled affiliates, collectively, other than Sprague Resources, its subsidiaries and its general partner. References to “Sprague Holdings” refer to Sprague Resources Holdings LLC, a wholly owned subsidiary of Axel Johnson and the owner of the General Partner. References to the “General Partner” refer to Sprague Resources GP LLC.
	The Partnership is one of the largest independent wholesale distributors of refined products in the Northeast United States based on aggregate terminal capacity. The Partnership owns, operates and/or controls a network of 19 refined products and materials handling terminals located in the Northeast United States and in Quebec, Canada. The Partnership also utilizes third-party terminals in the Northeast United States through which it sells or distributes refined products pursuant to rack, exchange and throughput agreements. The Partnership has four business segments: refined products, natural gas, materials handling and other operations. The refined products segment purchases a variety of refined products, such as heating oil, diesel fuel, residual fuel oil, kerosene, jet fuel, gasoline and asphalt (primarily from refining companies, trading organizations and producers), and sells them to wholesale and commercial customers. The natural gas segment purchases, sells and distributes natural gas to commercial and industrial customers in the Northeast and Mid-Atlantic United States. The Partnership purchases the natural gas it sells from natural gas producers and trading companies. The materials handling segment offloads, stores and prepares for delivery a variety of customer-owned products, including asphalt, clay slurry, salt, gypsum, crude oil, coal, petroleum coke, caustic soda, tallow, pulp and heavy equipment. The Partnership’s other operations include the purchase and distribution of coal and certain commercial trucking activities.
	On October 1, 2012, the Predecessor acquired Kildair Service Ltd. and two related subsidiaries (together “Kildair”). Kildair owns a terminal in Sorel-Tracy, Quebec, on the St. Lawrence River where it maintains 3.3 million barrels of residual fuel, asphalt, and crude oil storage. Kildair’s primary businesses include marketing of residual fuel oil both locally and for export, marketing of asphalt including polymer modified grades, and crude-by-rail handling services. Kildair’s terminal has blending infrastructure allowing the ability to process a wide range of varying quality blend components.
	In connection with the completion on October 30, 2013 of the initial public offering (the “IPO”) of common units representing limited partner interests in the Partnership, Axel Johnson Inc. contributed to Sprague Holdings all of the ownership interests in the Predecessor. The Predecessor distributed to a wholly owned subsidiary of Sprague Holdings certain assets and liabilities, its ownership of Kildair and accounts receivable and cash in an aggregate amount equal to the net proceeds of the IPO. Sprague Holdings then contributed all of the ownership interests in the Predecessor to the Partnership. All of the assets and liabilities of the Predecessor contributed to the Partnership by Sprague Holdings were recorded at the Parent’s historical cost, as the foregoing transactions are among entities under common control.
	On December 9, 2014, the Partnership acquired all of the equity interest in Kildair through the acquisition of the equity interests of Kildair’s parent, Sprague Canadian Properties, LLC, from a wholly owned subsidiary of Sprague Holdings. As this transaction represents a transfer of entities under common control, the Condensed Consolidated Financial Statements and related information presented herein have been recast to include the historical results of Kildair for all periods presented where Kildair was controlled by Axel Johnson, which commenced on October 1, 2012. Limited partners’ interest in net income as well as the related per unit amounts have not been recast for the three months ended March 31, 2014.
	As of March 31, 2015, the Parent, through its ownership of Sprague Holdings owns 2,034,378 common units and 10,071,970 subordinated units, representing an aggregate 57% limited partner interest in the Partnership. Sprague Holdings also owns the Partnership’s General Partner, which in turn owns a non-economic interest in the Partnership. The principal difference between the Partnership’s common units and subordinated units is that during the subordination period, the common units have the right to receive distributions of cash from distributable cash flow each quarter in an amount equal to $0.4125 per common unit, which is the amount
	defined in the partnership agreement as the minimum quarterly distribution, plus any arrearages in the payment of the minimum quarterly distribution on the common units from prior quarters, before any distributions of cash from distributable cash flow may be made on the subordinated units. Furthermore, no arrearages will accrue or be paid on the subordinated units. Upon expiration of the subordination period, any outstanding arrearages in payment of the minimum quarterly distribution on the common units will be extinguished (not paid), each outstanding subordinated unit will immediately convert into one common unit and will thereafter participate pro rata with the other common units in distributions.
	Sprague Holdings currently holds incentive distribution rights (“IDR’s”) that entitle it to receive increasing percentages, up to a maximum of 50%, of the cash the Partnership distributes from distributable cash flow. IDR participation begins once distributions exceed $0.474375 per unit per quarter. The maximum distribution of 50% does not include any distributions that Sprague Holdings may receive on any limited partner units that it owns.
	Basis of Presentation
	The Condensed Consolidated Financial Statements include the accounts of the Partnership and its wholly-owned subsidiaries. Intercompany transactions between the Partnership, and its subsidiaries have been eliminated. The accompanying unaudited condensed consolidated financial statements were prepared in accordance with the requirements of the Securities and Exchange Commission (“SEC”) for interim financial information. As permitted under those rules, certain notes or other financial information that are normally required by U.S. generally accepted accounting principles (“GAAP”) to be included in annual financial statements have been condensed or omitted from these interim financial statements. These interim financial statements should be read in conjunction with the consolidated financial statements and related notes of the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2014 as filed with the SEC on March 16, 2015 (the “2014 Annual Report”).
	The significant accounting policies are described in Note 1 “Description of Business and Summary of Significant Accounting Policies” in the Partnership’s audited consolidated financial statements, included in the 2014 Annual Report, and are the same as are used in preparing these unaudited interim condensed consolidated financial statements.
	The unaudited results of operations for the interim periods reported are not necessarily indicative of results to be expected for the full year. Demand for some of the Partnership’s refined petroleum products, specifically heating oil and residual oil for space heating purposes, and to a lesser extent natural gas, are generally higher during the first and fourth quarters of the calendar year which may result in significant fluctuations in the Partnership’s quarterly operating results.
	Use of Estimates
	The preparation of financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities in the balance sheet and the reported revenues and expenses in the income statement. Actual results could differ from those estimates. Among the estimates made by management are asset valuations, the fair value of derivative assets and liabilities, environmental and legal obligations and income taxes.
	New Accounting Guidance
	In April 2015, the Financial Accounting Standards Board issued Accounting Standard Update 2015-06, Earnings Per Share (Topic 260): Effects on Historical Earnings per Unit of Master Limited Partnership Dropdown Transactions (a consensus of the Emerging Issues Task Force). The Partnership is currently evaluating the potential impact of this guidance, however at this time we do not believe that the application of this ASU will result in changes to the Partnership’s presentation of earnings per unit or related disclosures in connection with the Partnership’s 2014 dropdown transaction. This guidance is effective for fiscal years beginning after December 15, 2015 and interim periods within those fiscal years and is to be applied on a retrospective basis.
	In April 2015, the Financial Accounting Standards Board issued Accounting Standard Update 2015-03, Simplifying the Presentation of Debt Issuance Costs, which requires debt issuance costs to be presented in the balance sheet as a direct deduction from the carrying value of the associated debt liability, consistent with the presentation of a debt discount. The Partnership has not yet adopted the provisions of this guidance which is effective for annual reporting periods beginning after December 15, 2015, and interim periods within those fiscal years. As of March 31, 2015 and December 31, 2014, the Partnership’s unamortized debt issuance costs were $16.9 million and $15.5 million respectively.
	In May 2014, the Financial Accounting Standards Board issued Accounting Standard Update 2014-09, Revenue from Contracts with Customers, which revises the principles of revenue recognition from one based on the transfer of risks and rewards to when a customer obtains control of a good or service. The Partnership is currently evaluating the potential impact of this guidance which is effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period.

Business_Combinations

Business Combinations	3 Months Ended
	Mar. 31, 2015
Business Combinations [Abstract]
Business Combinations	2. Business Combinations
	Acquisition of Kildair
	On December 9, 2014, the Partnership indirectly acquired all of the equity interests in Kildair through the Partnership’s acquisition of all of the equity interest of Kildair’s parent, Sprague Canadian Properties LLC, from Axel Johnson for total consideration of $175.0 million, (a portion of which was used to retire Kildair debt) which included $10.0 million in the Partnership’s unregistered common units. As the acquisition of Kildair by the Partnership represents a transfer of entities under common control, the Condensed Consolidated Financial Statements and related information presented herein have been recast by including the historical financial results of Kildair for all periods that were controlled by Axel Johnson. As such, summarized financial information has not been presented. The Partnership recognized $1.7 million of acquisition-related costs that were expensed in 2014.
	Acquisition of Castle Oil
	On December 8, 2014, the Partnership acquired substantially all of the assets of Castle Oil Corporation (“Castle”) and certain of its affiliates by purchasing Castle’s Bronx, New York terminal and its associated wholesale, commercial, and retail fuel distribution business. The acquisition-date fair value of the consideration consisted of cash of $45.3 million, an obligation to pay $5.0 million over a three year period (net present value of $4.6 million) and $5.3 million in the Partnership’s unregistered common units, plus payments for Castle’s inventory and other current assets of $37.0 million. Castle’s Bronx terminal is a large deep water petroleum products terminal located in New York City, and has 0.9 million barrels of storage capacity. The purchase of this facility augments the Partnership’s supply, storage and marketing opportunities and provides new opportunities in refined fuels, and expanded materials handling capabilities. The acquisition was accounted for as a business combination and was financed with borrowings under the Partnership’s credit facility.
	The following summarizes the preliminary fair values of the assets acquired and liabilities assumed:
	Inventories	$	36,512
	Derivative assets		4,837
	Other current assets and prepaids		533
	Property, plant and equipment		49,879
	Intangibles and other assets		5,046
	Total identifiable assets acquired		96,807
	Accrued liabilities		2,018
	Derivative liabilities		390
	Long term capital leases		1,481
	Other liabilities		761
	Total liabilities assumed		4,650
	Net assets acquired	$	92,157
	A preliminary allocation of the purchase price to the assets acquired and liabilities assumed was made based on available information and incorporating management’s best estimates. The Partnership is currently in the process of finalizing the valuation of the assets acquired and liabilities assumed. The actual allocation of the final purchase price and resulting effect on income from operations may differ from the amounts included above. The Partnership expects to finalize the purchase allocation during 2015.
	The following represents the unaudited pro forma consolidated net sales and net income as if Castle had been included in the unaudited consolidated results of the Partnership for the three months ended March 31, 2014.
		Three Months Ended
		March 31, 2014
	Net sales	$	2,435,524
	Net income	$	83,039
	Limited partners’ interest in net income	$	85,242
	Net income per limited partner common unit - basic	$	4.18
	Net income per limited partner common unit - diluted	$	4.18
	These amounts have been calculated after applying the Partnership’s accounting policies and adjusting the results of Castle to reflect the additional depreciation and amortization that would have been charged assuming the fair value adjustments to property, plant and equipment; and intangible assets had been applied on January 1, 2014, together with the consequential tax effects. The Partnership recognized $1.1 million of acquisition related costs that were expensed in 2014.
	Acquisition of Metromedia Gas & Power, Inc.
	On October 1, 2014, the Partnership completed its purchase of Metromedia Gas & Power Inc. (“Metromedia Energy”) for $22.0 million, not including the purchase of natural gas inventory, utility security deposits, and other adjustments. Total consideration at closing was $32.8 million. Metromedia Energy markets natural gas and brokers electricity to commercial, industrial and municipal consumers primarily in the Northeast and Mid-Atlantic United States. The acquisition was accounted for as a business combination and was financed with borrowings under the Partnership’s credit facility.
	The following table summarizes the fair values of the assets acquired and liabilities assumed at the acquisition date.
	Inventories	$	1,365
	Derivative assets		24,971
	Other current assets		543
	Intangible assets		13,900
	Natural gas transportation assets		39,427
	Other long term assets		6,683
	Property, plant and equipment		556
	Total identifiable assets acquired		87,445
	Derivative liabilities		67,413
	Other current liabilities		52
	Natural gas transportation liabilities		1,458
	Total liabilities assumed		68,923
	Net identifiable assets acquired		18,522
	Goodwill		14,243
	Net assets acquired	$	32,765
	The Partnership determined the fair value of intangible assets using income approaches that incorporated projected cash flows as well as excess earnings and lost profits methods. The Partnership determined the fair value of derivative assets, derivative liabilities and natural gas transportation assets by applying the Partnership’s existing valuation methodologies. The Partnership determined that book value approximated fair value for substantially all other assets and liabilities.
	The goodwill recognized is primarily attributable to Metromedia Energy’s assembled workforce, its reputation in the Northeast United States and the residual cash flow the Partnership believes that it will be able to generate. The goodwill is expected to be deductible for tax purposes. The Partnership recognized $0.1 million of acquisition related costs that were expensed in 2014.

Accumulated_Other_Comprehensiv

Accumulated Other Comprehensive Loss, Net of Tax	3 Months Ended
	Mar. 31, 2015
Equity [Abstract]
Accumulated Other Comprehensive Loss, Net of Tax	3. Accumulated Other Comprehensive Loss, Net of Tax
	Amounts included in accumulated other comprehensive loss, net of tax, consisted of the following:
		March 31,			December 31,
		2015			2014
	Fair value of interest rate swaps, net of tax	$	(959	)	$	(406	)
	Cumulative foreign currency translation adjustment		(10,776	)		(9,427	)
	Accumulated other comprehensive loss, net of tax	$	(11,735	)	$	(9,833	)
	A summary of the changes in accumulated other comprehensive loss related to foreign currency translation is as follows:
		Three Months Ended March 31,
		2015			2014
	Balance - beginning of period	$	(9,427	)	$	(8,284	)
	Foreign currency translation adjustment		(1,349	)		(459	)
	Balance - end of period	$	(10,776	)	$	(8,743	)

Inventories

Inventories	3 Months Ended
	Mar. 31, 2015
Inventory Disclosure [Abstract]
Inventories	4. Inventories
		March 31,		December 31,
		2015		2014
	Petroleum and related products	$	196,764	$	366,431
	Asphalt		18,595		18,357
	Coal		1,907		2,380
	Natural gas		646		3,387
	Inventories	$	217,912	$	390,555
	Due to changing market conditions, the Partnership recorded a provision of $9.6 million and $50.5 million as of March 31, 2015 and December 31, 2014, respectively, to write-down petroleum, natural gas and asphalt inventory to its net realizable value. These charges are included in cost of products sold (exclusive of depreciation and amortization) in the Consolidated Statements of Operations.

Debt

Debt	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Debt	5. Debt
			March 31,		December 31,
			2015		2014
	Current debt
	Credit agreement		$	258,460	$	396,961
	Other			218		253
	Current debt			258,678		397,214
	Long-term debt
	Credit agreement			469,240		417,789
	Other			468		567
	Long-term debt			469,708		418,356
	Total debt		$	728,386	$	815,570
	Credit Agreement
	On December 9, 2014, in connection with the acquisition of Kildair, the Partnership entered into an amended and restated revolving credit agreement (the “Credit Agreement”) that will mature on December 9, 2019. The revolving credit facilities under the Credit Agreement contain, among other items, the following:
		•		U.S. dollar revolving working capital facility of up to $1.0 billion to be used for working capital loans and letters of credit in the principal amount equal to the lesser of the Partnership’s borrowing base and $1.0 billion;
		•		Multicurrency revolving working capital facility of up to $120.0 million to be used by Kildair for working capital loans and letters of credit in the principal amount equal to the lesser of Kildair’ s borrowing base and $120.0 million;
		•		Revolving acquisition facility of up to $400.0 million to be used for loans and letters of credit to fund capital expenditures and acquisitions and other general corporate purposes related to the Partnership’s current businesses; and,
		•		Subject to certain conditions, the U.S. dollar or multicurrency revolving working capital facilities may be increased by $200.0 million. Additionally, subject to certain conditions, the revolving acquisition facility may be increased by $200.0 million.
	All obligations under the Credit Agreement are secured by substantially all of the assets of the Partnership and its subsidiaries.
	Indebtedness under the Credit Agreement will bear interest, at the Partnership’s option, at a rate per annum equal to either the Eurocurrency Base Rate (which is the LIBOR Rate for loans denominated in U.S. dollars and CDOR for loans denominated in Canadian dollars, in each case adjusted for certain regulatory costs) for interest periods of one, two, three or six months plus a specified margin or an alternate rate plus a specified margin.
	For the U.S. dollar working capital facility and the acquisition facility, the alternate rate is the Base Rate which is the higher of (a) the U.S. Prime Rate as in effect from time to time, (b) the Federal Funds rate as in effect from time to time plus 0.50% and (c) the one-month Eurocurrency Rate for U.S. dollars as in effect from time to time plus 1.00%.
	For the Canadian dollar working capital facility, the alternate rate is the Prime Rate which is the higher of (a) the Canadian Prime Rate as in effect from time to time and (b) the one-month Eurocurrency Rate for U.S. dollars as in effect from time to time plus 1.00%.
	As of March 31, 2015 and December 31, 2014, working capital facilities borrowings were $416.1 million and $503.2 million, respectively, and outstanding letters of credit were $36.1 million and $120.2 million, respectively. The working capital facilities are subject to borrowing base reporting and as of March 31, 2015 and December 31, 2014, had a borrowing base of $639.1 million and $843.3 million, respectively. As of March 31, 2015, excess availability under the working capital facility was $186.9 million.
	Acquisition line borrowings were $311.6 million at both March 31, 2015 and December 31, 2014, respectively. As of March 31, 2015, excess availability under the acquisition facility was $88.4 million.
	The weighted average interest rate was 2.8% at both March 31, 2015 and December 31, 2014 respectively. The current portion of the credit agreement at March 31, 2015 and December 31, 2014 represents the amounts intended to be repaid during the following twelve month period.
	The Credit Agreement contains certain restrictions and covenants among which are a minimum level of net working capital, fixed charge coverage and debt leverage ratios and limitations on the incurrence of indebtedness. As of March 31, 2015, the Partnership is in compliance with these financial covenants. The Credit Agreement limits the Partnership’s ability to make distributions in the event of a default as defined in the Credit Agreement.

Related_Party_Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2015
Related Party Transactions [Abstract]
Related Party Transactions	6. Related Party Transactions
	The General Partner charges the Partnership for the reimbursements of employee costs and related employee benefits and other overhead costs supporting the Partnership’s operations which amounted to $32.6 million and $30.1 million for the three months ended March 31, 2015 and 2014, respectively. Through the General Partner, the Partnership also participates in certain of the Parent’s pension and other post-retirement benefits. Amounts due to the General Partner were $12.8 million and $16.3 million as of March 31, 2015 and December 31, 2014 respectively.

Segment_Reporting

Segment Reporting	3 Months Ended
	Mar. 31, 2015
Segment Reporting [Abstract]
Segment Reporting	7. Segment Reporting
	The Partnership is a wholesale and commercial distributor engaged in the purchase, storage, distribution and sale of refined products and natural gas, and also provides storage and handling services for a broad range of materials. The Partnership has four reporting operating segments that comprise the structure used by the chief operating decision makers (CEO and CFO/COO) to make key operating decisions and assess performance. These segments are refined products, natural gas, materials handling and other activities.
	The Partnership’s refined products segment purchases a variety of refined products, such as heating oil, diesel fuel, residual fuel oil, asphalt, kerosene, jet fuel and gasoline (primarily from refining companies, trading organizations and producers), and sells them to its customers. The Partnership has wholesale customers who resell the refined products they purchase from the Partnership and commercial customers who consume the refined products they purchase from the Partnership. The Partnership’s wholesale customers consist of home heating oil retailers and diesel fuel and gasoline resellers. The Partnership’s commercial customers include federal and state agencies, municipalities, regional transit authorities, large industrial companies, real estate management companies, hospitals and educational institutions.
	The Partnership’s natural gas segment purchases, sells and distributes natural gas to commercial and industrial customers primarily in the Northeast and Mid-Atlantic United States. The Partnership purchases natural gas from natural gas producers and trading companies.
	The Partnership’s materials handling segment offloads, stores, and/or prepares for delivery a variety of customer-owned products, including asphalt, clay slurry, salt, gypsum, crude oil, coal, petroleum coke, caustic soda, tallow, pulp and heavy equipment. These services are fee-based activities which are generally conducted under multi-year agreements.
	The Partnership’s other activities include the purchase, sale and distribution of coal and commercial trucking activities unrelated to its refined products segment. Other activities are not reported separately as they represent less than 10% of consolidated net sales and adjusted gross margin.
	The Partnership evaluates segment performance based on adjusted gross margin, which is net sales less cost of products sold (exclusive of depreciation and amortization) increased by unrealized hedging losses and decreased by unrealized hedging gains, in each case with respect to refined products and natural gas inventory and natural gas transportation contracts.
	Based on the way the business is managed, it is not reasonably possible for the Partnership to allocate the components of operating costs and expenses among the operating segments. There were no significant intersegment sales for any of the years presented below.
	Summarized financial information for the Partnership’s reportable segments for the three months ended March 31, 2015 and 2014 is presented in the table below:
			Three Months Ended
			March 31,
			2015			2014
			(in thousands)
	Net sales:
	Refined products		$	1,431,845		$	1,844,973
	Natural gas			146,679			134,340
	Materials handling			10,184			8,079
	Other operations			9,650			7,307
	Net sales		$	1,598,358		$	1,994,699
	Adjusted gross margin(1):
	Refined products		$	66,306		$	51,530
	Natural gas			34,817			35,344
	Materials handling			10,184			8,077
	Other operations			2,983			1,336
	Adjusted gross margin			114,290			96,287
	Reconciliation to operating income(2):
	Add: unrealized gain (loss) on inventory(3)			(3,534	)		5,866
	Add: unrealized gain (loss) on natural gas transportation contracts(4)			(2,771	)		28,127
	Operating costs and expenses not allocated to operating segments:
	Operating expenses			(18,883	)		(16,838	)
	Selling, general and administrative			(32,381	)		(27,411	)
	Depreciation and amortization			(4,992	)		(3,955	)
	Operating income			51,729			82,076
	Other income			514			—
	Interest income			112			110
	Interest expense			(7,766	)		(8,016	)
	Income tax provision			(650	)		(1,038	)
	Net income		$	43,939		$	73,132
	1)	Adjusted gross margin is a non-GAAP financial measure used by management and external users of the Partnership’s consolidated financial statements to assess the Partnership’s economic results of operations and its market value reporting to lenders. The Partnership adjusts its segment results for the impact of unrealized hedging gains and losses with regard to refined products and natural gas inventory and natural gas transportation contracts relating to the underlying commodity derivative hedges, which are not marked to market for the purpose of recording unrealized gains or losses in net income (loss). These adjustments align the unrealized hedging gains and losses to the period in which the revenue from the sale of inventory and the utilization of transportation contracts relating to those hedges is realized in net income.
	-2	Reconciliation of adjusted gross margin to operating income, the most directly comparable GAAP measure.
	-3	Inventory is valued at the lower of cost or market. The fair value of the derivatives the Partnership uses to economically hedge its inventory declines or appreciates in value as the value of the underlying inventory appreciates or declines, which creates unrealized hedging losses (gains) with respect to the derivatives that are included in net income.
	-4	The unrealized hedging (gain) loss on natural gas transportation contracts represents the Partnership’s estimate of the change in fair value of the natural gas transportation contracts which are not recorded in net income (loss) until the transportation is utilized in the future (i.e., when natural gas is delivered to the customer), as these contracts are executory contracts that do not qualify as derivatives. As the fair value of the natural gas transportation contracts decline or appreciate, the offsetting physical or financial derivative will also appreciate or decline creating ‘unmatched’ unrealized hedging losses (gains) in net income.
	The Partnership had no single customer whose revenue was greater than 10% of total net sales for the three months ended March 31, 2015 and 2014, respectively. The Partnership’s foreign sales, primarily sales of refined products, asphalt and natural gas to its customers in Canada, were $58.1 million and $92.4 million for the three months ended March 31, 2015 and 2014, respectively.
	Segment Assets
	Due to the comingled nature and uses of the Partnership’s fixed assets, the Partnership does not track its fixed assets between its refined products and materials handling operating segments or its other activities. There are no significant fixed assets attributable to the natural gas reportable segment.
	As of March 31, 2015 and December 31, 2014, goodwill for the refined products, natural gas, materials handling and other operations segments amounted to $36.6 million, $18.6 million, $6.9 million and $1.2 million, respectively.

Financial_Instruments_and_OffB

Financial Instruments and Off-Balance Sheet Risk	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Financial Instruments and Off-Balance Sheet Risk	8. Financial Instruments and Off-Balance Sheet Risk
	Cash and Cash Equivalents, Accounts Receivable and Debt
	As of March 31, 2015 and December 31, 2014, the carrying amounts of cash and cash equivalents and accounts receivable approximated fair value because of the short maturity of these instruments. As of March 31, 2015 and December 31, 2014, the carrying value of the Partnership’s debt approximated fair value due to the variable interest nature of these instruments.
	Derivative Instruments
	The Partnership utilizes derivative instruments consisting of futures contracts, forward contracts, swaps, options and other derivatives individually or in combination, to mitigate its exposure to fluctuations in prices of refined petroleum products and natural gas. On a limited basis and within the Partnership’s risk management guidelines, the Partnership can utilize derivatives to generate profits from changes in market prices. The Partnership enters into futures and over-the-counter (“OTC”) transactions either on regulated exchanges or in the OTC market. Futures contracts are exchange-traded contractual commitments to either receive or deliver a standard amount or value of a commodity at a specified future date and price, with some futures contracts based on cash settlement rather than a delivery requirement. Futures exchanges typically require margin deposits as security. OTC contracts, which may or may not require margin deposits as security, involve parties that have agreed either to exchange cash payments or deliver or receive the underlying commodity at a specified future date and price. The Partnership posts initial margin with futures transaction brokers, along with variation margin, which is paid or received on a daily basis, and is included in other current assets in the Consolidated Balance Sheets. In addition, the Partnership may either pay or receive margin based upon exposure with counterparties. Payments made by the Partnership are included in other current assets, whereas payments received by the Partnership are included in accrued liabilities in the Consolidated Balance Sheets. Substantially all of the Partnership’s commodity derivative contracts outstanding as of March 31, 2015 will settle prior to September 30, 2016.
	The Partnership enters into some master netting arrangements to mitigate credit risk with significant counterparties. Master netting arrangements are standardized contracts that govern all specified transactions with the same counterparty and allow the Partnership to terminate all contracts upon occurrence of certain events, such as counterparty’s default. The Partnership has elected not to offset the fair value of its derivatives, even where these arrangements provide the right to do so.
	The Partnership’s derivative instruments are recorded at fair value, with changes in fair value recognized in net income or other comprehensive income each period as appropriate. The Partnership’s fair value measurements are determined using the market approach and includes non-performance risk and time value of money considerations. Counterparty credit is considered for receivable balances, and the Partnership’s credit is considered for payable balances.
	The Partnership determines fair value in accordance with Accounting Standards Codification (“ASC”) 820, “Fair Value Measurements and Disclosures” which established a hierarchy for the inputs used to measure the fair value of financial assets and liabilities based on the source of the input, which generally range from quoted prices for identical instruments in a principal trading market (Level 1) to estimates determined using significant unobservable inputs (Level 3). Multiple inputs may be used to measure fair value, however, the level of fair value is based on the lowest significant input level within this fair value hierarchy.
	Details on the methods and assumptions used to determine the fair values are as follows:
	Fair value measurements based on Level 1 inputs: Measurements that are most observable and are based on quoted prices of identical instruments obtained from the principal markets in which they are traded. Closing prices are both readily available and representative of fair value. Market transactions occur with sufficient frequency and volume to assure liquidity.
	Fair value measurements based on Level 2 inputs: Measurements that are derived indirectly from observable inputs or from quoted prices from markets that are less liquid. Measurements based on Level 2 inputs include over-the-counter derivative instruments that are priced on an exchange traded curve, but have contractual terms that are not identical to exchange traded contracts. The Partnership utilizes fair value measurements based on Level 2 inputs for its fixed forward contracts, over-the-counter commodity price swaps and interest rate swaps. The Partnership did not have any transfers between Level 1 and Level 2 fair value measurement during the three months ended March 31, 2015.
	Fair value measurements based on Level 3 inputs: Measurements that are least observable are estimated from significant unobservable inputs determined from sources with little or no market activity for comparable contracts or for positions with longer durations.
	The Partnership does not offset fair value amounts recognized for the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) against the fair value of derivative instruments executed with the same counterparty under the same master netting arrangement. The Partnership had no right to reclaim, or obligation to return, cash collateral as of March 31, 2015 or December 31, 2014.
	The following table presents all financial assets and financial liabilities of the Partnership measured at fair value on a recurring basis as of March 31, 2015 and December 31, 2014:
		As of March 31, 2015
		Fair Value			Quoted			Significant			Significant
		Measurement			Prices in			Other			Unobservable
					Active			Observable			Inputs
					Markets			Inputs			Level 3
					Level 1			Level 2
	Financial assets:
	Commodity fixed forwards	$	169,186		$	—		$	169,186		$	—
	Commodity swaps and options		112			—			112			—
	Total	$	169,298		$	—		$	169,298		$	—
	Financial liabilities:
	Commodity exchange contracts	$	93		$	93		$	—		$	—
	Commodity fixed forwards		47,508			—			47,508			—
	Commodity swaps and options		7,055			—			7,055			—
	Commodity derivatives		54,656			93			54,563			—
	Interest rate swaps		987			—			987			—
	Currency swaps		42			—			42			—
	Total	$	55,685		$	93		$	55,592		$	—
		As of December 31, 2014
		Fair Value			Quoted			Significant			Significant
		Measurement			Prices in			Other			Unobservable
					Active			Observable			Inputs
					Markets			Inputs			Level 3
					Level 1			Level 2
	Financial assets:
	Commodity fixed forwards	$	229,679		$	—		$	229,679		$	—
	Commodity swaps and options		74			—			74			—
	Commodity derivatives		229,753			—			229,753			—
	Interest rate swaps		137			—			137			—
	Total	$	229,890		$	—		$	229,890		$	—
	Financial liabilities:
	Commodity exchange contracts	$	97		$	97		$	—		$	—
	Commodity fixed forwards		80,080			—			80,080			—
	Commodity swaps and options		8,424			—			8,424			—
	Commodity derivatives		88,601			97			88,504			—
	Interest rate swaps		553			—			553			—
	Currency swaps		22			—			22			—
	Total	$	89,176		$	97		$	89,079		$	—
	The Partnership enters into derivative contracts with counterparties, some of which are subject to master netting arrangements, which allow net settlements under certain conditions. The Partnership presents derivatives at gross fair values in the Consolidated Balance Sheets. The maximum amount of loss due to credit risk that the Partnership would incur if its counterparties failed completely to perform according to the terms of the contracts, based on the gross fair value of these financial instruments, was $169.3 million at March 31, 2015. Information related to these offsetting arrangements as of March 31, 2015 and December 31, 2014 is as follows:
		As of March 31, 2015
											Gross Amount Not Offset in
		Gross									the Balance Sheet
		Amounts of			Gross			Amounts of			Financial			Cash			Net Amount
		Recognized			Amounts			Assets/			Instruments			Collateral
		Assets/			Offset in the			Liabilities in						Posted
		Liabilities			Balance Sheet			Balance Sheet
	Fair value of commodity derivative assets	$	169,298		$	—		$	169,298		$	(3,371	)	$	(1,147	)	$	164,780
	Commodity derivative liabilities	$	(54,656	)	$	—		$	(54,656	)	$	3,371		$	—		$	(51,285	)
	Interest rate swap derivative liabilities		(987	)		—			(987	)		—			—			(987	)
	Currency swap derivative liabilities		(42	)		—			(42	)		—			—			(42	)
Fair value of derivative liabilities	$	(55,685	)	$	—		$	(55,685	)	$	3,371		$	—		$	(52,314	)
	As of December 31, 2014
										Gross Amount Not Offset in
	Gross									the Balance Sheet
	Amounts of			Gross			Amounts of			Financial			Cash			Net Amount
	Recognized			Amounts			Assets/			Instruments			Collateral
	Assets/			Offset in the			Liabilities in						Posted
	Liabilities			Balance Sheet			Balance Sheet
Commodity derivative assets	$	229,753		$	—		$	229,753		$	(4,831	)	$	(2,417	)	$	222,505
Interest rate swap derivative assets		137			—			137			—			—			137
Fair value of derivative assets	$	229,890		$	—		$	229,890		$	(4,831	)	$	(2,417	)	$	222,642
Commodity derivative liabilities	$	(88,601	)	$	—		$	(88,601	)	$	4,831		$	—		$	(83,770	)
Interest rate swap derivative liabilities		(553	)		—			(553	)		—			—			(553	)
Currency swap derivative liabilities		(22	)		—			(22	)		—			—			(22	)
Fair value of derivative liabilities	$	(89,176	)	$	—		$	(89,176	)	$	4,831		$	—		$	(84,345	)
The following table presents total realized and unrealized gains (losses) on derivative instruments utilized for commodity risk management purposes for the three months ended March 31, 2015 and 2014. Such amounts are included in cost of products sold (exclusive of depreciation and amortization) in the Condensed Consolidated Statements of Operations:
	Three Months Ended March 31,
	2015			2014
Refined products contracts	$	61,804		$	6,342
Natural gas contracts		(4,328	)		(13,693	)
Total	$	57,476		$	(7,351	)
There were no discretionary trading activities for the three months ended March 31, 2015 and 2014. The following table presents the gross volume of commodity derivative instruments outstanding as of March 31, 2015 and December 31, 2014:
	As of March 31, 2015						As of December 31, 2014
	Refined Products			Natural Gas			Refined Products			Natural Gas
	(Barrels)			(MMBTUs)			(Barrels)			(MMBTUs)
Long contracts		8,711			117,614			10,823			131,376
Short contracts		(11,793	)		(71,417	)		(15,434	)		(82,796	)
Interest Rate Derivatives
The Partnership has entered into interest rate swaps to manage its exposure to changes in interest rates on its Credit Agreement. The Partnership’s interest rate swaps hedge actual and forecasted LIBOR borrowings and have been designated as cash flow hedges. Counterparties to the Partnership’s interest rate swaps are large multinational banks and the Partnership does not believe there is a material risk of counterparty non-performance.
At March 31, 2015, the Partnership held six interest rate swaps with a total notional value of $175.0 million whose swap periods began in January 2015, expiring in January 2016; and five interest rate swaps with a total notional value of $150.0 million whose swap periods begin in January 2016, expiring in January 2017. There was no material ineffectiveness determined for the cash flow hedges for the three months ended March 31, 2015 and 2014.
The Partnership records unrealized gains and losses on its interest rate swaps as a component of accumulated other comprehensive loss, net of tax, which is reclassified to earnings as interest expense when the payments are made. As of March 31, 2015, the amount of unrealized losses, net of tax, expected to be reclassified to earnings during the following twelve-month period was approximately $0.5 million.
Currency Derivatives
Kildair enters into forward currency contracts to manage the risk of currency rate fluctuations between its Canadian dollar denominated activity and the U.S. dollar, which is its functional currency. At March 31, 2015, Kildair has entered into a series of forward currency swaps that mature through April 2015. The contracts obligate Kildair to purchase $10.0 million in Canadian dollars at an exchange rate of 1.2734 to 1. The Canadian to U.S. dollar exchange rate was 1.2666 to 1 at March 31, 2015.

Commitments_and_Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	9. Commitments and Contingencies
	Legal, Environmental and Other Proceedings
	The Partnership is involved in various lawsuits, other proceedings and environmental matters, all of which arose in the normal course of business. The Partnership believes, based upon its examination of currently available information, its experience to date, and advice from legal counsel, that the individual and aggregate liabilities resulting from the resolution of these contingent matters will not have a material adverse impact on the Partnership’s consolidated results of operations, financial position or cash flows.

EquityBased_Compensation

Equity-Based Compensation	3 Months Ended
	Mar. 31, 2015
Equity [Abstract]
Equity-Based Compensation	10. Equity-Based Compensation
	On July 11, 2014, the board of directors of the General Partner approved that under the annual bonus program which is provided to substantially all employees, bonuses for the majority of participants will be settled in cash with others receiving a combination of cash and common units. The Partnership records the entire expected bonus payment as a liability until a grant date has been established and awards finalized, which occurs in the first quarter of the following year. During the three months ended March 31, 2015, $4.9 million of the annual bonus expense accrual as of December 31, 2014 was settled by issuing 200,775 common units and the Partnership withheld from the recipients 67,141 common units (estimated fair value of $1.7 million) to satisfy minimum tax withholding obligations. The Partnership estimates that $3.3 million of the annual bonus expense recorded during the three months ended March 31, 2015 will be settled in common units.
	The board of directors of the General Partner grants performance-based phantom unit awards to key employees that vest if certain performance criteria are met. Upon vesting, a holder of performance-based phantom units is entitled to receive a number of common units of the Partnership equal to a percentage (between 0 to 200 percent) of the target phantom units granted, based on the Partnership’s total unitholder return over the vesting period, compared with the total unitholder return of a peer group of other master limited partnership energy companies over the same period. The Partnership’s performance-based phantom unit awards are equity awards with both service and market-based conditions, which results in the compensation cost for these awards being recognized over the requisite service period, provided that the requisite service period is fulfilled, regardless of when, if ever, the market based conditions are satisfied. The fair value of the performance-based phantom units granted is estimated based on a Monte Carlo model that estimated the most likely performance outcome based on the terms of the award. The key inputs in the model include the market price of the Partnership’s common units as of the valuation date, the historical volatility of the market price of the Partnership’s common units, the historical volatility of the market price of the common units or common stock of the peer companies and the correlation between changes in the market price of the Partnership’s common units and those of the peer companies.
	The fair value of the performance-based phantom units granted on March 5, 2015 was estimated to be $4.5 million based on a Monte Carlo simulation using a weighted average volatility of 32.9% and a weighted average risk free rate of 0.98%.
	Based on the total unitholder return calculation, the performance-based phantom units with a performance period ending as of December 31, 2014 vested at the 200% level and as a result 74,048 common units were issued during the three months ended March 31, 2015. In connection with these vested awards, the Partnership withheld from the recipients 24,605 units (estimated fair value of $0.6 million) to satisfy minimum tax withholding obligations.
	Total unrecognized compensation cost related to performance-based phantom units totaled $5.4 million as of March 31, 2015, which is expected to be recognized over a period of 33 months. Performance-based phantom units accrue dividend equivalents which are recorded as liabilities over the requisite service period and are paid in cash upon vesting of the underlying performance-based phantom unit.
	A summary of the Partnership’s unit awards subject to vesting for the three months ended March 31, 2015 is set forth below:
		Restricted Units				Time Based						Performance-Based
						Phantom Units						Phantom Units
		Units		Weighted		Units			Weighted			Units		Weighted
				Average					Average					Average
				Grant Date					Grant Date					Grant Date
				Fair Value					Fair Value					Fair Value
				(per unit)					(per unit)					(per unit)
	Nonvested at December 31, 2014		4,444	$	17.33		23,685		$	20.16			111,075	$	36.88
	Granted		—		—		—			—			141,000	$	31.58
	Forfeited		—		—		—			—			—		—
	Vested		—		—		(13,766	)	$	(20.16	)		—		—
	Nonvested at March 31, 2015		4,444	$	17.33		9,919		$	20.16			252,075	$	33.92
	The following table provides information with respect to changes in the Partnership’s units:
		Common Units
		Public		Sprague		Subordinated
				Holdings		Units
	Balance as of December 31, 2013		8,506,666		1,571,970		10,071,970
	Employee and Director vested awards		27,401		—		—
	Units issued in connection with Castle acquisition		243,855		—		—
	Units issued in connection with Kildair acquisition		—		462,408		—
	Balance as of December 31, 2014		8,777,922		2,034,378		10,071,970
	Units issued in connection with employee bonus		133,634		—		—
	Units issued in connection with employee phantom awards		58,358		—		—
	Balance as of March 31, 2015		8,969,914		2,034,378		10,071,970
	Unit-based compensation recorded in unitholders’ equity for the three months ended March 31, 2015 and 2014 was $0.8 million and $0.5 million, respectively, and is included in selling, general and administrative expenses. Units issued under the Partnership’s LTIP are newly issued.

Earnings_Per_Unit

Earnings Per Unit	3 Months Ended
	Mar. 31, 2015
Earnings Per Share [Abstract]
Earnings Per Unit	11. Earnings Per Unit
	Earnings per unit applicable to limited partners (including subordinated unitholders) is computed by dividing limited partners’ interest in net income, after deducting any incentive distributions, by the weighted-average number of outstanding common and subordinated units. The Partnership’s net income is allocated to the limited partners in accordance with their respective partnership percentages, after giving effect to priority income allocations for incentive distributions, if any, to Sprague Holdings, the holder of the IDRs, pursuant to the partnership agreement, which are declared and paid following the close of each quarter. Earnings (losses) per unit is only calculated for the Partnership after the IPO as no units were outstanding prior to October 30, 2013. Earnings in excess of distributions are allocated to the limited partners based on their respective ownership interests. Payments made to the Partnership’s unitholders are determined in relation to actual distributions declared and are not based on the net income allocations used in the calculation of earnings per unit.
	In addition to the common and subordinated units, the Partnership has also identified the IDRs and unvested unit awards as participating securities and uses the two-class method when calculating the net income per unit applicable to limited partners, which is based on the weighted-average number of common units outstanding during the period. Diluted earnings per unit includes the effects of potentially dilutive units on the Partnership’s common units, consisting of unvested unit awards. Basic and diluted earnings per unit applicable to subordinated limited partners are the same because there are no potentially dilutive subordinated units outstanding.
	The following table shows the weighted average common units outstanding used to compute net income per common unit for the three months ended March 31, 2015 and 2014:
		Three Months Ended
		March 31,
		2015		2014
	Weighted average limited partner common units - basic		10,897,488		10,072,186
	Dilutive effect of unvested restricted and phantom units		167,022		990
	Weighted average limited partner common units - dilutive		11,064,510		10,073,176
	The following table presents the Partnership’s basic earnings per common and subordinated unit for the three months ended March 31, 2015 and 2014:
		Three Months Ended March 31, 2015
		Common		Subordinated		Total
		Units		Units
		(in thousands, except for per unit amounts)
	Limited partners’ interest in net income					$	43,939
	Distributions declared	$	5,204	$	4,759	$	9,963
	Assumed net income from operations after distributions		17,630		16,346		33,976
	Assumed net income to be allocated	$	22,834	$	21,105	$	43,939
	Earnings per unit - basic	$	2.1	$	2.1
	Earnings per unit - diluted	$	2.06	$	2.1
		Three Months Ended March 31, 2014
		Common		Subordinated		Total
		Units		Units
		(in thousands, except for per unit amounts)
	Limited partners’ interest in net income					$	75,335
	Distributions declared	$	4,165	$	4,155	$	8,320
	Assumed net income from operations after distributions.		33,503		33,512		67,015
	Assumed net income to be allocated	$	37,668	$	37,667	$	75,335
	Earnings per unit - basic	$	3.74	$	3.74
	Earnings per unit - diluted	$	3.74	$	3.74

Partnership_Distributions

Partnership Distributions	3 Months Ended
	Mar. 31, 2015
Equity [Abstract]
Partnership Distributions	12. Partnership Distributions
	The Partnership agreement sets forth the calculation to be used to determine the amount and priority of cash distributions that the common and subordinated unitholders will receive.
	On January 28, 2015, the Partnership declared a cash distribution totaling $9.6 million, or $0.4575 per unit for the three months ended December 31, 2014. Such distribution was paid on February 13, 2015, to unitholders of record on February 9, 2015.

Subsequent_Event

Subsequent Event	3 Months Ended
	Mar. 31, 2015
Subsequent Events [Abstract]
Subsequent Event	13. Subsequent Event
	On April 29, 2015, the Partnership declared a cash distribution totaling $10.0 million, or $0.4725 per unit for the three months ended March 31, 2015, payable on May 15, 2015, to unitholders of record on May 11, 2015.

Description_of_Business_and_Su1

Description of Business and Summary of Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2015
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation
	The Condensed Consolidated Financial Statements include the accounts of the Partnership and its wholly-owned subsidiaries. Intercompany transactions between the Partnership, and its subsidiaries have been eliminated. The accompanying unaudited condensed consolidated financial statements were prepared in accordance with the requirements of the Securities and Exchange Commission (“SEC”) for interim financial information. As permitted under those rules, certain notes or other financial information that are normally required by U.S. generally accepted accounting principles (“GAAP”) to be included in annual financial statements have been condensed or omitted from these interim financial statements. These interim financial statements should be read in conjunction with the consolidated financial statements and related notes of the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2014 as filed with the SEC on March 16, 2015 (the “2014 Annual Report”).
	The significant accounting policies are described in Note 1 “Description of Business and Summary of Significant Accounting Policies” in the Partnership’s audited consolidated financial statements, included in the 2014 Annual Report, and are the same as are used in preparing these unaudited interim condensed consolidated financial statements.
	The unaudited results of operations for the interim periods reported are not necessarily indicative of results to be expected for the full year. Demand for some of the Partnership’s refined petroleum products, specifically heating oil and residual oil for space heating purposes, and to a lesser extent natural gas, are generally higher during the first and fourth quarters of the calendar year which may result in significant fluctuations in the Partnership’s quarterly operating results.
Use of Estimates	Use of Estimates
	The preparation of financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities in the balance sheet and the reported revenues and expenses in the income statement. Actual results could differ from those estimates. Among the estimates made by management are asset valuations, the fair value of derivative assets and liabilities, environmental and legal obligations and income taxes.
New Accounting Guidance	New Accounting Guidance
	In April 2015, the Financial Accounting Standards Board issued Accounting Standard Update 2015-06, Earnings Per Share (Topic 260): Effects on Historical Earnings per Unit of Master Limited Partnership Dropdown Transactions (a consensus of the Emerging Issues Task Force). The Partnership is currently evaluating the potential impact of this guidance, however at this time we do not believe that the application of this ASU will result in changes to the Partnership’s presentation of earnings per unit or related disclosures in connection with the Partnership’s 2014 dropdown transaction. This guidance is effective for fiscal years beginning after December 15, 2015 and interim periods within those fiscal years and is to be applied on a retrospective basis.
	In April 2015, the Financial Accounting Standards Board issued Accounting Standard Update 2015-03, Simplifying the Presentation of Debt Issuance Costs, which requires debt issuance costs to be presented in the balance sheet as a direct deduction from the carrying value of the associated debt liability, consistent with the presentation of a debt discount. The Partnership has not yet adopted the provisions of this guidance which is effective for annual reporting periods beginning after December 15, 2015, and interim periods within those fiscal years. As of March 31, 2015 and December 31, 2014, the Partnership’s unamortized debt issuance costs were $16.9 million and $15.5 million respectively.
	In May 2014, the Financial Accounting Standards Board issued Accounting Standard Update 2014-09, Revenue from Contracts with Customers, which revises the principles of revenue recognition from one based on the transfer of risks and rewards to when a customer obtains control of a good or service. The Partnership is currently evaluating the potential impact of this guidance which is effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period.

Business_Combinations_Tables

Business Combinations (Tables)	3 Months Ended
	Mar. 31, 2015
Summary of Business Acquisition, Pro Forma Consolidated Net Sales and Net Income	The following represents the unaudited pro forma consolidated net sales and net income as if Castle had been included in the unaudited consolidated results of the Partnership for the three months ended March 31, 2014.
		Three Months Ended
		March 31, 2014
	Net sales	$	2,435,524
	Net income	$	83,039
	Limited partners’ interest in net income	$	85,242
	Net income per limited partner common unit - basic	$	4.18
	Net income per limited partner common unit - diluted	$	4.18
Metromedia Energy [Member]
Summary of Fair Values of Assets Acquired and Liabilities Assumed at Acquisition Date	The following table summarizes the fair values of the assets acquired and liabilities assumed at the acquisition date.
	Inventories	$	1,365
	Derivative assets		24,971
	Other current assets		543
	Intangible assets		13,900
	Natural gas transportation assets		39,427
	Other long term assets		6,683
	Property, plant and equipment		556
	Total identifiable assets acquired		87,445
	Derivative liabilities		67,413
	Other current liabilities		52
	Natural gas transportation liabilities		1,458
	Total liabilities assumed		68,923
	Net identifiable assets acquired		18,522
	Goodwill		14,243
	Net assets acquired	$	32,765
Castle Oil [Member]
Summary of Fair Values of Assets Acquired and Liabilities Assumed at Acquisition Date	The following summarizes the preliminary fair values of the assets acquired and liabilities assumed:
	Inventories	$	36,512
	Derivative assets		4,837
	Other current assets and prepaids		533
	Property, plant and equipment		49,879
	Intangibles and other assets		5,046
	Total identifiable assets acquired		96,807
	Accrued liabilities		2,018
	Derivative liabilities		390
	Long term capital leases		1,481
	Other liabilities		761
	Total liabilities assumed		4,650
	Net assets acquired	$	92,157

Accumulated_Other_Comprehensiv1

Accumulated Other Comprehensive Loss, Net of Tax (Tables)	3 Months Ended
	Mar. 31, 2015
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Loss, Net of Tax	Amounts included in accumulated other comprehensive loss, net of tax, consisted of the following:
		March 31,			December 31,
		2015			2014
	Fair value of interest rate swaps, net of tax	$	(959	)	$	(406	)
	Cumulative foreign currency translation adjustment		(10,776	)		(9,427	)
	Accumulated other comprehensive loss, net of tax	$	(11,735	)	$	(9,833	)
Summary of Changes in Accumulated Other Comprehensive Loss Related to Foreign Currency Translation	A summary of the changes in accumulated other comprehensive loss related to foreign currency translation is as follows:
		Three Months Ended March 31,
		2015			2014
	Balance - beginning of period	$	(9,427	)	$	(8,284	)
	Foreign currency translation adjustment		(1,349	)		(459	)
	Balance - end of period	$	(10,776	)	$	(8,743	)

Inventories_Tables

Inventories (Tables)	3 Months Ended
	Mar. 31, 2015
Inventory Disclosure [Abstract]
Schedule of Inventories
		March 31,		December 31,
		2015		2014
	Petroleum and related products	$	196,764	$	366,431
	Asphalt		18,595		18,357
	Coal		1,907		2,380
	Natural gas		646		3,387
	Inventories	$	217,912	$	390,555

Debt_Tables

Debt (Tables)	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Schedule of Debt
		March 31,		December 31,
		2015		2014
	Current debt
	Credit agreement	$	258,460	$	396,961
	Other		218		253
	Current debt		258,678		397,214
	Long-term debt
	Credit agreement		469,240		417,789
	Other		468		567
	Long-term debt		469,708		418,356
	Total debt	$	728,386	$	815,570

Segment_Reporting_Tables

Segment Reporting (Tables)	3 Months Ended
	Mar. 31, 2015
Segment Reporting [Abstract]
Summary of Financial Information for Partnership's Reportable Segments	Summarized financial information for the Partnership’s reportable segments for the three months ended March 31, 2015 and 2014 is presented in the table below:
			Three Months Ended
			March 31,
			2015			2014
			(in thousands)
	Net sales:
	Refined products		$	1,431,845		$	1,844,973
	Natural gas			146,679			134,340
	Materials handling			10,184			8,079
	Other operations			9,650			7,307
	Net sales		$	1,598,358		$	1,994,699
	Adjusted gross margin(1):
	Refined products		$	66,306		$	51,530
	Natural gas			34,817			35,344
	Materials handling			10,184			8,077
	Other operations			2,983			1,336
	Adjusted gross margin			114,290			96,287
	Reconciliation to operating income(2):
	Add: unrealized gain (loss) on inventory(3)			(3,534	)		5,866
	Add: unrealized gain (loss) on natural gas transportation contracts(4)			(2,771	)		28,127
	Operating costs and expenses not allocated to operating segments:
	Operating expenses			(18,883	)		(16,838	)
	Selling, general and administrative			(32,381	)		(27,411	)
	Depreciation and amortization			(4,992	)		(3,955	)
	Operating income			51,729			82,076
	Other income			514			—
	Interest income			112			110
	Interest expense			(7,766	)		(8,016	)
	Income tax provision			(650	)		(1,038	)
	Net income		$	43,939		$	73,132
	1)	Adjusted gross margin is a non-GAAP financial measure used by management and external users of the Partnership’s consolidated financial statements to assess the Partnership’s economic results of operations and its market value reporting to lenders. The Partnership adjusts its segment results for the impact of unrealized hedging gains and losses with regard to refined products and natural gas inventory and natural gas transportation contracts relating to the underlying commodity derivative hedges, which are not marked to market for the purpose of recording unrealized gains or losses in net income (loss). These adjustments align the unrealized hedging gains and losses to the period in which the revenue from the sale of inventory and the utilization of transportation contracts relating to those hedges is realized in net income.
	-2	Reconciliation of adjusted gross margin to operating income, the most directly comparable GAAP measure.
	-3	Inventory is valued at the lower of cost or market. The fair value of the derivatives the Partnership uses to economically hedge its inventory declines or appreciates in value as the value of the underlying inventory appreciates or declines, which creates unrealized hedging losses (gains) with respect to the derivatives that are included in net income.
	-4	The unrealized hedging (gain) loss on natural gas transportation contracts represents the Partnership’s estimate of the change in fair value of the natural gas transportation contracts which are not recorded in net income (loss) until the transportation is utilized in the future (i.e., when natural gas is delivered to the customer), as these contracts are executory contracts that do not qualify as derivatives. As the fair value of the natural gas transportation contracts decline or appreciate, the offsetting physical or financial derivative will also appreciate or decline creating ‘unmatched’ unrealized hedging losses (gains) in net income.

Financial_Instruments_and_OffB1

Financial Instruments and Off-Balance Sheet Risk (Tables)	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Summary of Financial Assets and Financial Liabilities of Partnership Measured at Fair Value on Recurring Basis	The following table presents all financial assets and financial liabilities of the Partnership measured at fair value on a recurring basis as of March 31, 2015 and December 31, 2014:
		As of March 31, 2015
		Fair Value			Quoted			Significant			Significant
		Measurement			Prices in			Other			Unobservable
					Active			Observable			Inputs
					Markets			Inputs			Level 3
					Level 1			Level 2
	Financial assets:
	Commodity fixed forwards	$	169,186		$	—		$	169,186		$	—
	Commodity swaps and options		112			—			112			—
	Total	$	169,298		$	—		$	169,298		$	—
	Financial liabilities:
	Commodity exchange contracts	$	93		$	93		$	—		$	—
	Commodity fixed forwards		47,508			—			47,508			—
	Commodity swaps and options		7,055			—			7,055			—
	Commodity derivatives		54,656			93			54,563			—
	Interest rate swaps		987			—			987			—
	Currency swaps		42			—			42			—
	Total	$	55,685		$	93		$	55,592		$	—
		As of December 31, 2014
		Fair Value			Quoted			Significant			Significant
		Measurement			Prices in			Other			Unobservable
					Active			Observable			Inputs
					Markets			Inputs			Level 3
					Level 1			Level 2
	Financial assets:
	Commodity fixed forwards	$	229,679		$	—		$	229,679		$	—
	Commodity swaps and options		74			—			74			—
	Commodity derivatives		229,753			—			229,753			—
	Interest rate swaps		137			—			137			—
	Total	$	229,890		$	—		$	229,890		$	—
	Financial liabilities:
	Commodity exchange contracts	$	97		$	97		$	—		$	—
	Commodity fixed forwards		80,080			—			80,080			—
	Commodity swaps and options		8,424			—			8,424			—
	Commodity derivatives		88,601			97			88,504			—
	Interest rate swaps		553			—			553			—
	Currency swaps		22			—			22			—
	Total	$	89,176		$	97		$	89,079		$	—
Summary of Offsetting Arrangements	Information related to these offsetting arrangements as of March 31, 2015 and December 31, 2014 is as follows:
		As of March 31, 2015
											Gross Amount Not Offset in
		Gross									the Balance Sheet
		Amounts of			Gross			Amounts of			Financial			Cash			Net Amount
		Recognized			Amounts			Assets/			Instruments			Collateral
		Assets/			Offset in the			Liabilities in						Posted
		Liabilities			Balance Sheet			Balance Sheet
	Fair value of commodity derivative assets	$	169,298		$	—		$	169,298		$	(3,371	)	$	(1,147	)	$	164,780
	Commodity derivative liabilities	$	(54,656	)	$	—		$	(54,656	)	$	3,371		$	—		$	(51,285	)
	Interest rate swap derivative liabilities		(987	)		—			(987	)		—			—			(987	)
	Currency swap derivative liabilities		(42	)		—			(42	)		—			—			(42	)
	Fair value of derivative liabilities	$	(55,685	)	$	—		$	(55,685	)	$	3,371		$	—		$	(52,314	)
		As of December 31, 2014
											Gross Amount Not Offset in
		Gross									the Balance Sheet
		Amounts of			Gross			Amounts of			Financial			Cash			Net Amount
		Recognized			Amounts			Assets/			Instruments			Collateral
		Assets/			Offset in the			Liabilities in						Posted
		Liabilities			Balance Sheet			Balance Sheet
	Commodity derivative assets	$	229,753		$	—		$	229,753		$	(4,831	)	$	(2,417	)	$	222,505
	Interest rate swap derivative assets		137			—			137			—			—			137
	Fair value of derivative assets	$	229,890		$	—		$	229,890		$	(4,831	)	$	(2,417	)	$	222,642
	Commodity derivative liabilities	$	(88,601	)	$	—		$	(88,601	)	$	4,831		$	—		$	(83,770	)
	Interest rate swap derivative liabilities		(553	)		—			(553	)		—			—			(553	)
	Currency swap derivative liabilities		(22	)		—			(22	)		—			—			(22	)
	Fair value of derivative liabilities	$	(89,176	)	$	—		$	(89,176	)	$	4,831		$	—		$	(84,345	)
Summary of Realized and Unrealized Gains (Losses) on Derivative Instruments for Commodity Risk Management	The following table presents total realized and unrealized gains (losses) on derivative instruments utilized for commodity risk management purposes for the three months ended March 31, 2015 and 2014. Such amounts are included in cost of products sold (exclusive of depreciation and amortization) in the Condensed Consolidated Statements of Operations:
		Three Months Ended March 31,
		2015			2014
	Refined products contracts	$	61,804		$	6,342
	Natural gas contracts		(4,328	)		(13,693	)
	Total	$	57,476		$	(7,351	)
Schedule of Gross Volume of Commodity Derivative Instruments Outstanding	The following table presents the gross volume of commodity derivative instruments outstanding as of March 31, 2015 and December 31, 2014:
		As of March 31, 2015						As of December 31, 2014
		Refined Products			Natural Gas			Refined Products			Natural Gas
		(Barrels)			(MMBTUs)			(Barrels)			(MMBTUs)
	Long contracts		8,711			117,614			10,823			131,376
	Short contracts		(11,793	)		(71,417	)		(15,434	)		(82,796	)

EquityBased_Compensation_Table

Equity-Based Compensation (Tables)	3 Months Ended
	Mar. 31, 2015
Equity [Abstract]
Summary of Partnership's Unit Awards Subject to Vesting	A summary of the Partnership’s unit awards subject to vesting for the three months ended March 31, 2015 is set forth below:
		Restricted Units				Time Based						Performance-Based
						Phantom Units						Phantom Units
		Units		Weighted		Units			Weighted			Units		Weighted
				Average					Average					Average
				Grant Date					Grant Date					Grant Date
				Fair Value					Fair Value					Fair Value
				(per unit)					(per unit)					(per unit)
	Nonvested at December 31, 2014		4,444	$	17.33		23,685		$	20.16			111,075	$	36.88
	Granted		—		—		—			—			141,000	$	31.58
	Forfeited		—		—		—			—			—		—
	Vested		—		—		(13,766	)	$	(20.16	)		—		—
	Nonvested at March 31, 2015		4,444	$	17.33		9,919		$	20.16			252,075	$	33.92
Schedule of Changes in Partnership's Units	The following table provides information with respect to changes in the Partnership’s units:
		Common Units
		Public		Sprague		Subordinated
				Holdings		Units
	Balance as of December 31, 2013		8,506,666		1,571,970		10,071,970
	Employee and Director vested awards		27,401		—		—
	Units issued in connection with Castle acquisition		243,855		—		—
	Units issued in connection with Kildair acquisition		—		462,408		—
	Balance as of December 31, 2014		8,777,922		2,034,378		10,071,970
	Units issued in connection with employee bonus		133,634		—		—
	Units issued in connection with employee phantom awards		58,358		—		—
	Balance as of March 31, 2015		8,969,914		2,034,378		10,071,970

Earnings_Per_Unit_Tables

Earnings Per Unit (Tables)	3 Months Ended
	Mar. 31, 2015
Earnings Per Share [Abstract]
Summary of Weighted Average Common Units Outstanding	The following table shows the weighted average common units outstanding used to compute net income per common unit for the three months ended March 31, 2015 and 2014:
		Three Months Ended
		March 31,
		2015		2014
	Weighted average limited partner common units - basic		10,897,488		10,072,186
	Dilutive effect of unvested restricted and phantom units		167,022		990
	Weighted average limited partner common units - dilutive		11,064,510		10,073,176
Schedule of Partnership's Basic Earnings Per Common and Subordinated Unit	The following table presents the Partnership’s basic earnings per common and subordinated unit for the three months ended March 31, 2015 and 2014:
		Three Months Ended March 31, 2015
		Common		Subordinated		Total
		Units		Units
		(in thousands, except for per unit amounts)
	Limited partners’ interest in net income					$	43,939
	Distributions declared	$	5,204	$	4,759	$	9,963
	Assumed net income from operations after distributions		17,630		16,346		33,976
	Assumed net income to be allocated	$	22,834	$	21,105	$	43,939
	Earnings per unit - basic	$	2.1	$	2.1
	Earnings per unit - diluted	$	2.06	$	2.1
		Three Months Ended March 31, 2014
		Common		Subordinated		Total
		Units		Units
		(in thousands, except for per unit amounts)
	Limited partners’ interest in net income					$	75,335
	Distributions declared	$	4,165	$	4,155	$	8,320
	Assumed net income from operations after distributions.		33,503		33,512		67,015
	Assumed net income to be allocated	$	37,668	$	37,667	$	75,335
	Earnings per unit - basic	$	3.74	$	3.74
	Earnings per unit - diluted	$	3.74	$	3.74

Description_of_Business_and_Su2

Description of Business and Summary of Significant Accounting Policies - Additional Information (Detail) (USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014	Oct. 01, 2012
	Segment		bbl
Nature Of Business And Basis Of Presentation [Line Items]
Limited partnership formation date	23-Jun-11
Number of reporting operating segments	4
Distributions from distributable cash flow	$0.47
Unamortized debt issuance costs	$16.90	$15.50
Common Units [Member]
Nature Of Business And Basis Of Presentation [Line Items]
Distribution amount per share	$0.41
Maximum [Member]
Nature Of Business And Basis Of Presentation [Line Items]
Percentages incentive distribution rights	50.00%
Sprague Holdings [Member]
Nature Of Business And Basis Of Presentation [Line Items]
Common units issued	2,034,378
Percentage of limited partnership interest	57.00%
Subordinated Units [Member] | Sprague Holdings [Member]
Nature Of Business And Basis Of Presentation [Line Items]
Common units issued	10,071,970
Predecessor [Member]
Nature Of Business And Basis Of Presentation [Line Items]
Number of terminals owned	19
Number of reporting operating segments	4
Predecessor [Member] | Kildair [Member]
Nature Of Business And Basis Of Presentation [Line Items]
Storage capacity related to Kildair			3,300,000

Business_Combinations_Addition

Business Combinations - Additional Information (Detail) (USD $)	0 Months Ended	3 Months Ended	12 Months Ended	0 Months Ended
In Millions, unless otherwise specified	Oct. 01, 2014	Mar. 31, 2015	Dec. 31, 2014	Dec. 09, 2014	Dec. 08, 2014
Metromedia Energy [Member]
Business Acquisition [Line Items]
Business acquisition, effective date of acquisition		1-Oct-14
Business acquisition, purchase price	$32.80
Acquisition related costs			0.1
Payments to acquire businesses	22
Kildair [Member]
Business Acquisition [Line Items]
Business acquisition, effective date of acquisition		9-Dec-14
Business acquisition, purchase price				175
Business acquisition, common stock value				10
Acquisition related costs			1.7
Castle Oil [Member]
Business Acquisition [Line Items]
Business acquisition, effective date of acquisition		8-Dec-14
Business acquisition, purchase price					45.3
Business acquisition, common stock value					5.3
Acquisition related costs			1.1
Business acquisition contingent consideration obligation to pay					5
Business acquisition contingent consideration payment period					3 years
Business acquisition contingent consideration net present value					4.6
Business acquisition, consideration payments for inventory and other current assets					$37
Storage capacity for gasoline products					900,000

Business_Combinations_Summary_

Business Combinations - Summary of Fair Values of Assets Acquired and Liabilities Assumed at Acquisition Date - Castle Oil (Detail) (Castle Oil [Member], USD $)	Dec. 08, 2014
In Thousands, unless otherwise specified
Castle Oil [Member]
Business Acquisition [Line Items]
Inventories	$36,512
Derivative assets	4,837
Other current assets and prepaids	533
Property, plant and equipment	49,879
Intangibles and other assets	5,046
Total identifiable assets acquired	96,807
Accrued liabilities	2,018
Derivative liabilities	390
Long term capital leases	1,481
Other liabilities	761
Total liabilities assumed	4,650
Net assets acquired	$92,157

Business_Combinations_Summary_1

Business Combinations - Summary of Business Acquisition, Pro Forma Consolidated Net Sales and Net Income (Detail) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014
Business Combinations [Abstract]
Net sales	$2,435,524
Net income	83,039
Limited partners' interest in net income	$85,242
Net income per limited partner common unit - basic	$4.18
Net income per limited partner common unit - diluted	$4.18

Business_Combinations_Summary_2

Business Combinations - Summary of Fair Values of Assets Acquired and Liabilities Assumed at Acquisition Date - Metromedia Gas and Power (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014	Oct. 01, 2014
In Thousands, unless otherwise specified
Business Acquisition [Line Items]
Goodwill	$63,288	$63,288
Metromedia Energy [Member]
Business Acquisition [Line Items]
Inventories			1,365
Derivative assets			24,971
Other current assets			543
Intangible assets			13,900
Natural gas transportation assets			39,427
Other long term assets			6,683
Property, plant and equipment			556
Total identifiable assets acquired			87,445
Derivative liabilities			67,413
Other current liabilities			52
Natural gas transportation liabilities			1,458
Total liabilities assumed			68,923
Net identifiable assets acquired			18,522
Goodwill			14,243
Net assets acquired			$32,765

Accumulated_Other_Comprehensiv2

Accumulated Other Comprehensive Loss, Net of Tax - Schedule of Accumulated Other Comprehensive Loss, Net of Tax (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Fair value of interest rate swaps, net of tax	($959)	($406)
Cumulative foreign currency translation adjustment	-10,776	-9,427	-8,743	-8,284
Accumulated other comprehensive loss, net of tax	($11,735)	($9,833)

Accumulated_Other_Comprehensiv3

Accumulated Other Comprehensive Loss, Net of Tax - Summary of Changes in Accumulated Other Comprehensive Income (Loss) Related to Foreign Currency Translation (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Balance - beginning of period	($9,427)	($8,284)
Foreign currency translation adjustment	-1,349	-459
Balance - end of period	($10,776)	($8,743)

Inventories_Schedule_of_Invent

Inventories - Schedule of Inventories (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Inventory [Line Items]
Inventories	$217,912	$390,555
Petroleum and Related Products [Member]
Inventory [Line Items]
Inventories	196,764	366,431
Asphalt [Member]
Inventory [Line Items]
Inventories	18,595	18,357
Coal [Member]
Inventory [Line Items]
Inventories	1,907	2,380
Natural Gas [Member]
Inventory [Line Items]
Inventories	$646	$3,387

Inventories_Additional_Informa

Inventories - Additional Information (Detail) (Petroleum, Natural Gas and Asphalt Inventory [Member], USD $)	3 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Petroleum, Natural Gas and Asphalt Inventory [Member]
Public Utilities, Inventory [Line Items]
Provision for inventory write-down	$9.60	$50.50

Debt_Schedule_of_Debt_Detail

Debt - Schedule of Debt (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Current debt
Credit agreement	$258,460	$396,961
Other	218	253
Current debt	258,678	397,214
Long-term debt
Credit agreement	469,240	417,789
Other	468	567
Long-term debt	469,708	418,356
Total debt	$728,386	$815,570

Debt_Additional_Information_De

Debt - Additional Information (Detail) (USD $)	3 Months Ended	0 Months Ended
	Mar. 31, 2015	Dec. 09, 2014	Dec. 31, 2014
U.S. dollar [Member] | Federal Funds Rate [Member]
Debt Instrument [Line Items]
Debt instruments, interest rate	0.50%
U.S. dollar [Member] | Eurocurrency Rate [Member]
Debt Instrument [Line Items]
Debt instruments, interest rate	1.00%
Canadian Dollars [Member] | Eurocurrency Rate [Member]
Debt Instrument [Line Items]
Debt instruments, interest rate	1.00%
Working Capital Facility [Member]
Debt Instrument [Line Items]
Debt instruments, borrowing capacity, increase		$200,000,000
Working Capital Facility [Member] | U.S. dollar [Member]
Debt Instrument [Line Items]
Debt instruments, interest rate description	For the U.S. dollar working capital facility and the acquisition facility, the alternate rate is the Base Rate which is the higher of (a) the U.S. Prime Rate as in effect from time to time, (b) the Federal Funds rate as in effect from time to time plus 0.50% and (c) the one-month Eurocurrency Rate for U.S. dollars as in effect from time to time plus 1.00%.
Working Capital Facility [Member] | Canadian Dollars [Member]
Debt Instrument [Line Items]
Debt instruments, interest rate description	For the Canadian dollar working capital facility, the alternate rate is the Prime Rate which is the higher of (a) the Canadian Prime Rate as in effect from time to time and (b) the one-month Eurocurrency Rate for U.S. dollars as in effect from time to time plus 1.00%.
Acquisition Credit Facility [Member]
Debt Instrument [Line Items]
Debt instruments, borrowing capacity, increase		200,000,000
Credit Agreement [Member]
Debt Instrument [Line Items]
Agreement amendment date	9-Dec-14
Debt instruments, weighted average interest rate	2.80%		2.80%
Credit Agreement [Member] | Amended and Restated Revolving Credit Agreement [Member]
Debt Instrument [Line Items]
Debt instruments, maturity date	9-Dec-19
Credit Agreement [Member] | Working Capital Facility [Member]
Debt Instrument [Line Items]
Debt instruments, borrowing capacity		1,000,000,000
Borrowings under Credit Agreement	416,100,000		503,200,000
Letters of credit outstanding	36,100,000		120,200,000
Borrowing base under Credit Agreement	639,100,000		843,300,000
Excess availability under Credit Agreement	186,900,000
Credit Agreement [Member] | Working Capital Facility [Member] | Kildair [Member]
Debt Instrument [Line Items]
Debt instruments, borrowing capacity		120,000,000
Credit Agreement [Member] | Acquisition Credit Facility [Member]
Debt Instrument [Line Items]
Debt instruments, borrowing capacity		400,000,000
Borrowings under Credit Agreement	311,600,000		311,600,000
Excess availability under Credit Agreement	88,400,000

Related_Party_Transactions_Add

Related Party Transactions - Additional Information (Detail) (General Partner [Member], USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
General Partner [Member]
Related Party Transaction [Line Items]
Reimbursement of employees related benefits expenses and other costs	$32.60	$30.10
Amounts due to General Partner	$12.80		$16.30

Segment_Reporting_Additional_I

Segment Reporting - Additional Information (Detail) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
	Customer	Customer
	Segment
Segment Reporting Information [Line Items]
Number of reporting operating segments	4
Number of customers accounted for more than 10% of revenue	0	0
Net sales revenue	$1,598,358,000	$1,994,699,000
Significant fixed assets	1,168,668,000		1,339,840,000
Goodwill	63,288,000		63,288,000
Canada [Member]
Segment Reporting Information [Line Items]
Net sales revenue	58,100,000	92,400,000
Natural Gas [Member]
Segment Reporting Information [Line Items]
Net sales revenue	146,679,000	134,340,000
Significant fixed assets	0
Goodwill	18,600,000		18,600,000
Refined Products [Member]
Segment Reporting Information [Line Items]
Net sales revenue	1,431,845,000	1,844,973,000
Goodwill	36,600,000		36,600,000
Materials Handling [Member]
Segment Reporting Information [Line Items]
Net sales revenue	10,184,000	8,079,000
Goodwill	6,900,000		6,900,000
Other Operations [Member]
Segment Reporting Information [Line Items]
Net sales revenue	9,650,000	7,307,000
Goodwill	$1,200,000		$1,200,000
Net Sales and Adjusted Gross Margin [Member] | Maximum [Member]
Segment Reporting Information [Line Items]
Percentage of net sales	10.00%
Sales Revenue, Net [Member] | Maximum [Member]
Segment Reporting Information [Line Items]
Percentage of net sales	10.00%	10.00%

Segment_Reporting_Summary_of_F

Segment Reporting - Summary of Financial Information for Partnership's Reportable Segments (Detail) (USD $)	3 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Net sales:
Net sales	$1,598,358	$1,994,699
Adjusted gross margin:
Adjusted gross margin	114,290	96,287
Reconciliation to operating income:
Add: unrealized gain (loss) on inventory	-3,534	5,866
Add: unrealized gain (loss) on natural gas transportation contracts	-2,771	28,127
Operating costs and expenses not allocated to operating segments:
Operating expenses	-18,883	-16,838
Selling, general and administrative	-32,381	-27,411
Depreciation and amortization	-4,992	-3,955
Operating income	51,729	82,076
Other income	514
Interest income	112	110
Interest expense	-7,766	-8,016
Income tax provision	-650	-1,038
Net income	43,939	73,132	122,814
Refined Products [Member]
Net sales:
Net sales	1,431,845	1,844,973
Adjusted gross margin:
Adjusted gross margin	66,306	51,530
Natural Gas [Member]
Net sales:
Net sales	146,679	134,340
Adjusted gross margin:
Adjusted gross margin	34,817	35,344
Materials Handling [Member]
Net sales:
Net sales	10,184	8,079
Adjusted gross margin:
Adjusted gross margin	10,184	8,077
Other Operations [Member]
Net sales:
Net sales	9,650	7,307
Adjusted gross margin:
Adjusted gross margin	$2,983	$1,336

Financial_Instruments_and_OffB2

Financial Instruments and Off-Balance Sheet Risk - Summary of Financial Assets and Financial Liabilities of Partnership Measured at Fair Value on Recurring Basis (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Financial assets:
Financial assets	$169,298	$229,890
Financial liabilities:
Financial liabilities	55,685	89,176
Commodity Exchange Contracts [Member]
Financial liabilities:
Financial liabilities	93	97
Commodity Fixed Forwards [Member]
Financial assets:
Financial assets	169,186	229,679
Financial liabilities:
Financial liabilities	47,508	80,080
Commodity Swaps and Options [Member]
Financial assets:
Financial assets	112	74
Financial liabilities:
Financial liabilities	7,055	8,424
Commodity Derivatives [Member]
Financial assets:
Financial assets	169,298	229,753
Financial liabilities:
Financial liabilities	54,656	88,601
Interest Rate Swaps [Member]
Financial assets:
Financial assets		137
Financial liabilities:
Financial liabilities	987	553
Currency Swap [Member]
Financial liabilities:
Financial liabilities	42	22
Quoted Prices in Active Markets Level 1 [Member]
Financial liabilities:
Financial liabilities	93	97
Quoted Prices in Active Markets Level 1 [Member] | Commodity Exchange Contracts [Member]
Financial liabilities:
Financial liabilities	93	97
Quoted Prices in Active Markets Level 1 [Member] | Commodity Derivatives [Member]
Financial liabilities:
Financial liabilities	93	97
Significant Other Observable Inputs Level 2 [Member]
Financial assets:
Financial assets	169,298	229,890
Financial liabilities:
Financial liabilities	55,592	89,079
Significant Other Observable Inputs Level 2 [Member] | Commodity Fixed Forwards [Member]
Financial assets:
Financial assets	169,186	229,679
Financial liabilities:
Financial liabilities	47,508	80,080
Significant Other Observable Inputs Level 2 [Member] | Commodity Swaps and Options [Member]
Financial assets:
Financial assets	112	74
Financial liabilities:
Financial liabilities	7,055	8,424
Significant Other Observable Inputs Level 2 [Member] | Commodity Derivatives [Member]
Financial assets:
Financial assets		229,753
Financial liabilities:
Financial liabilities	54,563	88,504
Significant Other Observable Inputs Level 2 [Member] | Interest Rate Swaps [Member]
Financial assets:
Financial assets		137
Financial liabilities:
Financial liabilities	987	553
Significant Other Observable Inputs Level 2 [Member] | Currency Swap [Member]
Financial liabilities:
Financial liabilities	$42	$22

Financial_Instruments_and_OffB3

Financial Instruments and Off-Balance Sheet Risk - Additional Information (Detail)	0 Months Ended			3 Months Ended
	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2014	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2015
	USD ($)	CAD	Canadian Dollars [Member]	Interest Rate Swaps [Member]	Interest Rate Swaps [Member]	Interest Rate Swaps [Member]	Interest Rate Swaps [Member]	Forward Currency Swaps [Member]
				USD ($)	USD ($)	Six Interest Rate Swap Agreements [Member]	Five Interest Rate Swap Agreements [Member]
						USD ($)	USD ($)
						Interest_Rate_Swaps	Interest_Rate_Swaps
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Maximum amount of loss due to credit risk if counterparties failed completely to perform	$169,300,000
Number of interest rate swap						6	5
Notional amount of interest rate swap agreements						175,000,000	150,000,000
Notional amount of interest rate swap, expire period						2016-01	2017-01
Notional amount of interest rate swap, beginning period						2015-01	2016-01
Material ineffectiveness for the cash flow hedges				0	0
Unrealized losses, net of tax, expected to be reclassified to earnings				500,000
Maturity of forward currency swaps								30-Apr-15
Purchase of U.S. dollars								The contracts obligate Kildair to purchase $10.0 million in Canadian dollars
Foreign currency exchange rate		1.2666	1.2734
Contracts obligate Canadian subsidiary to purchase U.S. dollars at exchange rate		10,000,000

Financial_Instruments_and_OffB4

Financial Instruments and Off-Balance Sheet Risk - Summary of Offsetting Arrangements (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gross Amounts of Recognized Assets		$229,890
Gross Amount Offset in the Balance Sheet, Assets		0
Amounts of Assets in Balance Sheet	169,298	229,890
Financial Instruments, Assets		-4,831
Cash Collateral Posted, Assets		-2,417
Net Amount, Assets		222,642
Gross Amounts of Recognized Liabilities	-55,685	-89,176
Gross Amount Offset in the Balance Sheet, Liabilities	0	0
Amounts of Liabilities in Balance Sheet	-55,685	-89,176
Financial Instruments, Liabilities	3,371	4,831
Cash Collateral Posted, Liabilities	0	0
Net Amount, Liabilities	-52,314	-84,345
Commodity Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gross Amounts of Recognized Assets	169,298	229,753
Gross Amount Offset in the Balance Sheet, Assets	0	0
Amounts of Assets in Balance Sheet	169,298	229,753
Financial Instruments, Assets	-3,371	-4,831
Cash Collateral Posted, Assets	-1,147	-2,417
Net Amount, Assets	164,780	222,505
Gross Amounts of Recognized Liabilities	-54,656	-88,601
Gross Amount Offset in the Balance Sheet, Liabilities	0	0
Amounts of Liabilities in Balance Sheet	-54,656	-88,601
Financial Instruments, Liabilities	3,371	4,831
Cash Collateral Posted, Liabilities	0	0
Net Amount, Liabilities	-51,285	-83,770
Interest Rate Swaps [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gross Amounts of Recognized Assets		137
Gross Amount Offset in the Balance Sheet, Assets		0
Amounts of Assets in Balance Sheet		137
Net Amount, Assets		137
Gross Amounts of Recognized Liabilities	-987	-553
Gross Amount Offset in the Balance Sheet, Liabilities	0	0
Amounts of Liabilities in Balance Sheet	-987	-553
Cash Collateral Posted, Liabilities	0	0
Net Amount, Liabilities	-987	-553
Currency Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gross Amounts of Recognized Liabilities	-42	-22
Gross Amount Offset in the Balance Sheet, Liabilities	0	0
Amounts of Liabilities in Balance Sheet	-42	-22
Cash Collateral Posted, Liabilities	0	0
Net Amount, Liabilities	($42)	($22)

Financial_Instruments_and_OffB5

Financial Instruments and Off-Balance Sheet Risk - Summary of Realized and Unrealized Gains (Losses) on Derivative Instruments for Commodity Risk Management (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized and unrealized gains (losses) on derivative instruments	$57,476	($7,351)
Refined Products Contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized and unrealized gains (losses) on derivative instruments	61,804	6,342
Natural Gas Contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized and unrealized gains (losses) on derivative instruments	($4,328)	($13,693)

Financial_Instruments_and_OffB6

Financial Instruments and Off-Balance Sheet Risk - Schedule of Gross Volume of Commodity Derivative Instruments Outstanding (Detail)	3 Months Ended	12 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
	bbl	bbl
Refined Products Contracts [Member] | Long Contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gross volume	8,711,000	10,823,000
Refined Products Contracts [Member] | Short Contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gross volume	-11,793,000	-15,434,000
Natural Gas Contracts [Member] | Long Contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gross volume	117,614,000	131,376,000
Natural Gas Contracts [Member] | Short Contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gross volume	-71,417,000	-82,796,000

EquityBased_Compensation_Addit

Equity-Based Compensation - Additional Information (Detail) (USD $)	3 Months Ended		12 Months Ended	0 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014	Mar. 05, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Annual bonus expense	$3,300,000		$4,900,000
Number of common units issued for settlement of annual bonus expenses	200,775
Unit-based compensation recorded in unitholders' equity	4,068,000	538,000
Annual Bonus Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of units reacquired from recipient	67,141
Estimated grant date fair value	1,700,000
Restricted and Phantom Unit Award Activity [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unit-based compensation recorded in unitholders' equity	800,000	500,000
Performance Based Phantom Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of units reacquired from recipient	24,605
Estimated grant date fair value	600,000
Percentage of phantom units granted	200.00%
Estimated fair value of performance-based phantom units				4,500,000
Weighted average volatility rate				32.90%
Weighted average risk free rate				0.98%
Common stock units issued	74,048
Unrecognized compensation cost	$5,400,000
Unrecognized compensation cost, expected recognition period	33 months
Performance Based Phantom Units [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of phantom units granted	0.00%
Performance Based Phantom Units [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of phantom units granted	200.00%

EquityBased_Compensation_Summa

Equity-Based Compensation - Summary of Partnership's Unit Awards Subject to Vesting (Detail) (USD $)	3 Months Ended
	Mar. 31, 2015
Restricted Common Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonvested Units, Beginning	4,444
Forfeited Units	0
Nonvested Units, Ending	4,444
Weighted-Average Grant Date Fair Value, Nonvested Units, Beginning	$17.33
Weighted-Average Grant Date Fair Value, Forfeited Units	$0
Weighted-Average Grant Date Fair Value, Nonvested Units, Ending	$17.33
Time Based Phantom Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonvested Units, Beginning	23,685
Forfeited Units	0
Vested Units	-13,766
Nonvested Units, Ending	9,919
Weighted-Average Grant Date Fair Value, Nonvested Units, Beginning	$20.16
Weighted-Average Grant Date Fair Value, Forfeited Units	$0
Weighted-Average Grant Date Fair Value, Vested Units	($20.16)
Weighted-Average Grant Date Fair Value, Nonvested Units, Ending	$20.16
Performance Based Phantom Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonvested Units, Beginning	111,075
Granted Units	141,000
Forfeited Units	0
Nonvested Units, Ending	252,075
Weighted-Average Grant Date Fair Value, Nonvested Units, Beginning	$36.88
Weighted-Average Grant Date Fair Value, Granted Units	$31.58
Weighted-Average Grant Date Fair Value, Forfeited Units	$0
Weighted-Average Grant Date Fair Value, Nonvested Units, Ending	$33.92

EquityBased_Compensation_Sched

Equity-Based Compensation - Schedule of Changes in Partnership's Units (Detail)	12 Months Ended	3 Months Ended
	Dec. 31, 2014	Mar. 31, 2015	Dec. 31, 2013
Common Unitholders - Public [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Beginning balance			8,506,666
Ending balance	8,777,922	8,969,914	8,506,666
Common Unitholders - Public [Member] | Directors and Employees [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units issued	27,401
Common Unitholders - Public [Member] | Employee Bonus Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units issued		133,634
Common Unitholders - Public [Member] | Phantom Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units issued		58,358
Common Unitholders - Public [Member] | Castle (Romita) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units issued in connection with acquisition	243,855
Common Unitholders - Affiliated [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Beginning balance			1,571,970
Ending balance	2,034,378	2,034,378	1,571,970
Common Unitholders - Affiliated [Member] | Kildair [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units issued in connection with acquisition	462,408
Subordinated Unitholders - Affiliated [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Beginning balance			10,071,970
Ending balance	10,071,970	10,071,970	10,071,970

Earnings_Per_Unit_Additional_I

Earnings Per Unit - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2015
Subordinated Units [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Potentially dilutive units outstanding	0
Prior to October 30, 2013 [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Units outstanding prior to IPO	0

Earnings_Per_Unit_Summary_of_W

Earnings Per Unit - Summary of Weighted Average Common Units Outstanding (Detail)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Weighted average limited partner common units - basic	10,897,488	10,072,186
Weighted average limited partner common units - dilutive	11,064,510	10,073,176
Phantom Units [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Dilutive effect of unvested restricted and phantom units	167,022	990

Earnings_Per_Unit_Schedule_of_

Earnings Per Unit - Schedule of Partnership's Basic Earnings Per Common and Subordinated Unit (Detail) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Limited partners' interest in net income	$43,939	$75,335
Distributions declared	9,963	8,320
Assumed net income from operations after distributions	33,976	67,015
Assumed net income to be allocated	43,939	75,335
Earnings per unit - basic	$2.10	$3.74
Earnings per unit - diluted	$2.06	$3.74
Common Unitholders - Affiliated [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Distributions declared	5,204	4,165
Assumed net income from operations after distributions	17,630	33,503
Assumed net income to be allocated	22,834	37,668
Earnings per unit - basic	$2.10	$3.74
Earnings per unit - diluted	$2.06	$3.74
Subordinated Unitholders - Affiliated [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Distributions declared	4,759	4,155
Assumed net income from operations after distributions	16,346	33,512
Assumed net income to be allocated	$21,105	$37,667
Earnings per unit - basic	$2.10	$3.74
Earnings per unit - diluted	$2.10	$3.74

Partnership_Distributions_Addi

Partnership Distributions - Additional Information (Detail) (USD $)	3 Months Ended		0 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Feb. 13, 2015	Jan. 28, 2015
Distribution Made to Limited Partner [Line Items]
Cash distribution, declared value	$9,963	$8,320
Cash distribution, paid value	9,589	5,693
Cash distribution, declared per share	$0.47	$0.41
Dividend Declared on January 28, 2015 [Member]
Distribution Made to Limited Partner [Line Items]
Cash distribution, declared value				9,600
Cash distribution, paid value			$9,600
Cash distribution, declared per share				$0.46
Cash distribution, paid per share			$0.46
Cash distribution, declared date	28-Jan-15
Cash distribution, paid date	13-Feb-15
Cash distribution, record date	9-Feb-15

Subsequent_Event_Additional_In

Subsequent Event - Additional Information (Detail) (USD $)	3 Months Ended		0 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Apr. 29, 2015
Subsequent Event [Line Items]
Cash distribution, declared value	$9,963	$8,320
Dividend Declared on April 29, 2015 [Member]
Subsequent Event [Line Items]
Cash distribution, declared date	29-Apr-15
Cash distribution, paid date	15-May-15
Cash distribution, record date	11-May-15
Subsequent Event [Member] | Dividend Declared on April 29, 2015 [Member]
Subsequent Event [Line Items]
Cash distribution, declared value			$10,000
Cash distribution, declared per share			$0.47