Sprague Resources (SRLP) 10-Q 5 Nov 15 2015 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2015	Nov. 02, 2015
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q3
Trading Symbol	SRLP
Entity Registrant Name	Sprague Resources LP
Entity Central Index Key	1,525,287
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Common Units [Member]
Document Information [Line Items]
Entity Common Stock, Shares Outstanding		11,011,756
Subordinated Units
Document Information [Line Items]
Entity Common Stock, Shares Outstanding		10,071,970

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 14,975	$ 4,080
Accounts receivable, net	139,726	289,424
Inventories	229,416	390,555
Fair value of derivative assets	150,060	229,890
Deferred income taxes	866	895
Other current assets	41,840	52,416
Total current assets	576,883	967,260
Property, plant and equipment, net	250,658	250,126
Assets held for sale	0	1,321
Intangibles, net	23,184	27,626
Other assets, net	23,965	30,219
Goodwill	63,288	63,288
Total assets	937,978	1,339,840
Current liabilities:
Accounts payable	90,941	198,609
Accrued liabilities	46,442	63,816
Fair value of derivative liabilities	54,399	89,176
Due to General Partner and affiliates	12,938	15,340
Current portion of long-term debt	230,059	397,214
Current portion of capital leases	1,009	1,313
Total current liabilities	$ 435,788	$ 765,468
Commitments and contingencies (Note 9)
Long-term debt	$ 325,094	$ 418,356
Long-term capital leases	3,667	5,424
Other liabilities	17,323	17,884
Due to General Partner	1,249	988
Deferred income taxes	16,532	15,826
Total liabilities	799,653	1,223,946
Unitholders’ equity:
Accumulated other comprehensive loss, net of tax	(12,213)	(9,833)
Total unitholders’ equity	138,325	115,894
Total liabilities and unitholders’ equity	937,978	1,339,840
Common Unitholders - Public
Unitholders’ equity:
Partners' equity	181,584	171,055
Common Unitholders - Affiliated
Unitholders’ equity:
Partners' equity	(3,166)	(5,566)
Subordinated Unitholders - Affiliated
Unitholders’ equity:
Partners' equity	$ (27,880)	$ (39,762)

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (Parenthetical) - shares	Jun. 30, 2015	Dec. 31, 2014
Common Unitholders - Public
Units, issued	8,969,914	8,777,922
Units, outstanding	8,969,914	8,777,922
Common Unitholders - Affiliated
Units, issued	2,034,378	2,034,378
Units, outstanding	2,034,378	2,034,378
Subordinated Unitholders - Affiliated
Units, issued	10,071,970	10,071,970
Units, outstanding	10,071,970	10,071,970

Unaudited Condensed Consolidate

Unaudited Condensed Consolidated Statements of Operations - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Net sales	$ 558,022	$ 897,408	$ 2,818,123	$ 3,871,768
Cost of products sold (exclusive of depreciation and amortization)	498,537	860,669	2,604,969	3,678,876
Operating expenses	17,870	14,401	54,394	46,597
Selling, general and administrative	19,894	14,923	71,193	53,458
Depreciation and amortization	5,188	4,373	15,365	12,458
Total operating costs and expenses	541,489	894,366	2,745,921	3,791,389
Operating income	16,533	3,042	72,202	80,379
Other income	0	0	514	0
Interest income	138	124	367	401
Interest expense	(6,399)	(6,819)	(20,624)	(21,548)
Income (loss) before income taxes	10,272	(3,653)	52,459	59,232
Income tax provision	(1,692)	(1,649)	(2,490)	(2,006)
Net income (loss)	8,580	(5,302)	49,969	57,226
Add/(deduct):
Income attributable to Kildair (Note 2)	0	(5,416)	0	(2,103)
Incentive distributions declared	(105)	0	(154)	0
Limited partners’ interest in net income (loss)	$ 8,475	$ (10,718)	$ 49,815	$ 55,123
Net income (loss) per limited partner unit:
Common - basic (in dollars per unit)	$ 0.40	$ (0.53)	$ 2.37	$ 2.73
Common - diluted (in dollars per unit)	$ 0.39	$ (0.53)	$ 2.32	$ 2.73
Units used to compute net income (loss) per limited partner unit:
Common - basic units	10,999,848	10,091,388	10,965,400	10,085,058
Common - diluted units	11,253,395	10,091,388	11,199,128	10,120,935
Distribution declared per common and subordinated units (in dollars per unit)	$ 0.5025	$ 0.4425	$ 1.4625	$ 1.2825
Subordinated Unitholders - Affiliated
Net income (loss)	$ 4,051		$ 23,850
Add/(deduct):
Limited partners’ interest in net income (loss)		$ (5,354)		$ 27,544
Net income (loss) per limited partner unit:
Common - basic (in dollars per unit)	$ 0.40	$ (0.53)	$ 2.37	$ 2.73
Common - diluted (in dollars per unit)	0.40	(0.53)	2.37	2.73
Subordinated - basic and diluted (in dollars per share)	$ 0.40	$ (0.53)	$ 2.37	$ 2.73
Units used to compute net income (loss) per limited partner unit:
Subordinated - basic and diluted units	10,071,970	10,071,970	10,071,970	10,071,970

Unaudited Condensed Consolidat5

Unaudited Condensed Consolidated Statements of Comprehensive (Loss) Income - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 8,580	$ (5,302)	$ 49,969	$ 57,226
Unrealized (loss) gain on interest rate swaps
Net (loss) gain arising in the period	(428)	45	(1,388)	(54)
Reclassification adjustment related to losses realized in income	126	631	384	1,864
Net change in unrealized (loss) gain on interest rate swaps	(302)	676	(1,004)	1,810
Tax effect	8	(17)	29	(46)
Unrealized (loss) gain on interest rate swaps, Total	(294)	659	(975)	1,764
Foreign currency translation adjustment	(156)	(662)	(1,405)	(665)
Other comprehensive (loss) income	(450)	(3)	(2,380)	1,099
Comprehensive income (loss)	$ 8,130	$ (5,305)	$ 47,589	$ 58,325

Unaudited Condensed Consolidat6

Unaudited Condensed Consolidated Statements of Unitholders' Equity (Deficit) - USD ($) $ in Thousands	Total	Kildair	Castle	Accumulated Other Comprehensive (Loss) Income	Common-Public	Common-PublicCastle	Common-Sprague Holdings	Common-Sprague HoldingsKildair	Subordinated-Sprague Holdings	Subordinated-Sprague HoldingsKildair	IDR
Beginning balance at Dec. 31, 2013	$ 71,293			$ (10,610)	$ 127,496		$ (6,155)		$ (39,438)		$ 0
Net income	122,814				50,141		9,953		62,720
Distributions paid	(31,594)				(13,370)		(2,460)		(15,764)
Other comprehensive income	777			777
Unit-based compensation	3,617				1,528		286		1,803
Distribution to sponsor for Kildair acquisition		$ (66,667)						$ (17,652)		$ (49,015)
Other contribution from Parent	470						470
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)		0
Common units issued for acquisition		$ 10,002	$ 5,318			$ 5,318		$ 10,002
Net income	49,969				21,193		4,827		23,900		49
Distributions paid	(29,870)				(12,660)		(2,884)		(14,277)		(49)
Other comprehensive income	(2,380)			(2,380)
Unit-based compensation	2,116				898		205		1,013
Common units issued with annual bonus	4,939				2,088		479		2,372
Units withheld for employee tax obligation	(2,343)				(990)		(227)		(1,126)
Ending balance at Sep. 30, 2015	$ 138,325			$ (12,213)	$ 181,584		$ (3,166)		$ (27,880)		$ 0

Unaudited Condensed Consolidat7

Unaudited Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Cash flows from operating activities
Net income	$ 49,969	$ 57,226
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (includes amortization of deferred debt issuance costs)	18,033	16,137
Provision for doubtful accounts	1,785	2,703
Gain on sale of assets and insurance recoveries	(482)	(83)
Deferred income taxes	773	746
Non-cash unit-based compensation	5,231	5,267
Changes in assets and liabilities:
Accounts receivable	147,912	76,615
Inventories	161,139	109,292
Prepaid expenses and other assets	16,113	(28,763)
Fair value of commodity derivative instruments	44,050	(57,226)
Due to General Partner and affiliates	(2,148)	7,836
Accounts payable, accrued liabilities and other	(124,713)	(89,528)
Net cash provided by operating activities	317,662	100,222
Cash flows from investing activities
Purchases of property, plant and equipment	(11,044)	(13,314)
Proceeds from property insurance settlement, sale of assets and other activities	407	139
Net cash used in investing activities	(10,637)	(13,175)
Cash flows from financing activities
Net payments under credit agreements	(260,259)	(60,816)
Payments on capital lease liabilities and term debt	(1,061)	(603)
Payments on long-term terminal obligations	(310)	(423)
Debt issuance costs	(1,938)	0
Distributions paid	(29,870)	(22,655)
Foreign exchange on capital lease obligations	(226)	(112)
Units withheld for employee tax obligation	(2,343)	(136)
Net increase in payable to Parent	0	147
Net cash used in financing activities	(296,007)	(84,598)
Effect of exchange rate changes on cash balances held in foreign currencies	(123)	9
Net change in cash and cash equivalents	10,895	2,458
Cash and cash equivalents, beginning of period	4,080	2,046
Cash and cash equivalents, end of period	14,975	4,504
Supplemental disclosure of cash flow information
Cash paid for interest	18,307	20,104
Cash paid for taxes	$ 3,490	$ 1,164

Description of Business and Sum

Description of Business and Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2015
Accounting Policies [Abstract]
Description of Business and Summary of Significant Accounting Policies	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”). 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. 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 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. As of September 30, 2015 , the Parent, through its ownership of Sprague Holdings, owns 2,034,378 common units and 10,071,970 subordinated units, representing an aggregate of 57% of the limited partner interest in the Partnership. Sprague Holdings also owns the General Partner, which in turn owns a non-economic interest in the Partnership. Sprague Holdings currently holds incentive distribution rights (“IDRs”) that entitle it to receive increasing percentages of the cash the Partnership distributes from distributable cash flow up to a maximum of 50% . 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 partnership units that it owns. See Notes 11 and 12. 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 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. The Partnership's 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 consolidated financial statements included herein reflect all normal and recurring adjustments which, in the opinion of management, are necessary for a fair presentation of the Partnership’s consolidated financial position at September 30, 2015 and December 31, 2014 and the consolidated results of operations and cash flows for the three and nine months ended September 30, 2015 and 2014, respectively. 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. Recent Accounting Pronouncements In October 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standard Update (“ASU”) 2015-16, Simplifying the Accounting for Measurement-Period Adjustments which requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. The Partnership is currently evaluating the potential impact of this guidance which is effective for fiscal years beginning after December 15, 2015 and interim periods within those fiscal years. In July 2015, the FASB issued ASU 2015-11, Simplifying the Measurement of Inventory , which requires that inventory within the scope of the guidance be measured at the lower of cost or net realizable value. The Partnership is currently evaluating the potential impact of this guidance which is effective for fiscal years beginning after December 15, 2016 and interim periods within those fiscal years. In April 2015, the FASB issued ASU 2015-6, 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 FASB issued ASU 2015-3, Simplifying the Presentation of Debt Issuance Costs, ("ASU 2015-3") 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. In August 2015, the FASB issued ASU 2015-15 to reflect SEC commentary that given the absence of authoritative guidance within ASU 2015-03 for debt issuance costs related to line-of-credit arrangements, the SEC would not object to an entity deferring and presenting debt issuance costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. The Partnership has not yet adopted the provisions of ASU 2015-3, which is effective for annual reporting periods beginning after December 15, 2015, and interim periods within those fiscal years. As of September 30, 2015 and December 31, 2014, the Partnership’s unamortized debt issuance costs were $15.1 million and $15.5 million , respectively. In May 2014, the FASB issued ASU 2014-9, 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. In July 2015, the FASB issued ASU-2015-14, Revenue from Contracts with Customers-Deferral of the Effective Date which establishes the effective date of this guidance for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. The Partnership continues to evaluate both the impact of this new standard on the consolidated financial statements and the transition method it will utilize for adoption.

Business Combinations

Business Combinations	9 Months Ended
	Sep. 30, 2015
Business Combinations [Abstract]
Business Combinations	Business Combinations Kildair On December 9, 2014 , the Partnership indirectly acquired all of the equity interests in Kildair Service Ltd. (“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 outstanding Kildair debt at the date of acquisition), which included $10.0 million in the Partnership’s 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. The limited partners’ interest in net income (loss) as well as the related per unit amounts have not been recast. 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 (recorded at a 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 900,000 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. 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 and expects to finalize the purchase price allocation during the fourth quarter of 2015. The following table represents the unaudited pro forma consolidated net sales and net (loss) income as if Castle had been included in the unaudited condensed consolidated results for the periods presented below: Three Months Ended September 30, 2014 Nine Months Ended September 30, 2014 Net sales $ 964,120 $ 4,497,657 Net (loss) income $ (8,673 ) $ 61,750 Limited partners’ interest in net (loss) income $ (14,089 ) $ 59,647 Net (loss) income per limited partner common unit - basic $ (0.69 ) $ 2.93 Net (loss) income per limited partner common unit - diluted $ (0.69 ) $ 2.93 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 related tax effects. 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 assets and liabilities. Total consideration at closing was $32.8 million . Metromedia Energy marketed natural gas and brokered 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 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 acquired assets and liabilities. The goodwill recognized was 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 deductible for tax purposes.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Loss, Net of Tax	9 Months Ended
	Sep. 30, 2015
Equity [Abstract]
Accumulated Other Comprehensive Loss, Net of Tax	Accumulated Other Comprehensive Loss, Net of Tax Amounts included in accumulated other comprehensive loss, net of tax, consisted of the following: September 30, 2015 December 31, 2014 Fair value of interest rate swaps, net of tax $ (1,381 ) $ (406 ) Cumulative foreign currency translation adjustment (10,832 ) (9,427 ) Accumulated other comprehensive loss, net of tax $ (12,213 ) $ (9,833 ) A summary of the changes in accumulated other comprehensive loss related to foreign currency translation is as follows: Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Balance - beginning of period $ (10,676 ) $ (8,287 ) $ (9,427 ) $ (8,284 ) Foreign currency translation adjustment (156 ) (662 ) (1,405 ) (665 ) Balance - end of period $ (10,832 ) $ (8,949 ) $ (10,832 ) $ (8,949 )

Inventories

Inventories	9 Months Ended
	Sep. 30, 2015
Inventory Disclosure [Abstract]
Inventories	Inventories September 30, December 31, Petroleum and related products $ 200,849 $ 366,431 Asphalt 24,630 18,357 Natural gas 1,450 3,387 Coal 2,487 2,380 Inventories $ 229,416 $ 390,555 Due to changing market conditions, the Partnership recorded a provision of $10.6 million and $50.5 million as of September 30, 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 Condensed Consolidated Statements of Operations.

Debt

Debt	9 Months Ended
	Sep. 30, 2015
Debt Disclosure [Abstract]
Debt	Debt September 30, December 31, 2014 Current debt Credit agreement $ 229,839 $ 396,961 Other 220 253 Current debt 230,059 397,214 Long-term debt Credit agreement 324,661 417,789 Other 433 567 Long-term debt 325,094 418,356 Total debt $ 555,153 $ 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 matures on December 9, 2019 . Obligations under the Credit Agreement are secured by substantially all of the assets of the Partnership and its subsidiaries. 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 . Indebtedness under the Credit Agreement bears 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 September 30, 2015 and December 31, 2014 , working capital facilities borrowings were $248.4 million and $503.2 million , respectively, and outstanding letters of credit were $15.7 million and $120.2 million , respectively. The working capital facilities are subject to borrowing base reporting and as of September 30, 2015 and December 31, 2014 , had a borrowing base of $477.7 million and $843.3 million , respectively. As of September 30, 2015 , excess availability under the working capital facility was $213.6 million . Acquisition line borrowings were $306.1 million at September 30, 2015 and $311.6 million at December 31, 2014 . As of September 30, 2015 , excess availability under the acquisition facility was $93.9 million . The weighted average interest rate was 3.0% and 2.8% at September 30, 2015 and December 31, 2014 , respectively. The current portion of the credit agreement at September 30, 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 September 30, 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	9 Months Ended
	Sep. 30, 2015
Related Party Transactions [Abstract]
Related Party Transactions	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 $22.5 million and $13.4 million for the three months ended September 30, 2015 and 2014, respectively and $76.2 million and $58.5 million for the nine months ended September 30, 2015 and 2014, respectively. Through the General Partner, the Partnership also participates in the Parent’s pension and other post-retirement benefits. At September 30, 2015 and December 31, 2014 total amounts due to the General Partner with respect to these benefits and overhead costs were $14.2 million and $16.3 million , respectively.

Segment Reporting

Segment Reporting	9 Months Ended
	Sep. 30, 2015
Segment Reporting [Abstract]
Segment Reporting	Segment Reporting 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 (defined below). 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 periods presented below. The Partnership had no single customer whose revenue was greater than 10% of total net sales for the three and nine months ended September 30, 2015 and 2014 , respectively. The Partnership’s foreign sales, primarily sales of refined products, asphalt and natural gas to its customers in Canada, were $55.4 million and $93.2 million for the three months ended September 30, 2015 and 2014 and $163.4 million and $268.7 million for the nine months ended September 30, 2015 and 2014 , respectively. Summarized financial information for the Partnership’s reportable segments is presented in the table below: Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 (in thousands) (in thousands) Net sales: Refined products $ 488,639 $ 830,821 $ 2,499,335 $ 3,574,461 Natural gas 52,568 53,376 265,805 255,058 Materials handling 12,027 9,790 33,905 26,868 Other operations 4,788 3,421 19,078 15,381 Net sales $ 558,022 $ 897,408 $ 2,818,123 $ 3,871,768 Adjusted gross margin(1): Refined products $ 31,852 $ 32,176 $ 124,101 $ 101,868 Natural gas 4,423 4,604 40,556 42,614 Materials handling 12,027 9,816 33,899 26,886 Other operations 2,024 1,251 6,648 3,939 Adjusted gross margin 50,326 47,847 205,204 175,307 Reconciliation to operating income(2): Add: unrealized gain (loss) on inventory(3) 575 4,686 (5,102 ) 11,311 Add: unrealized gain (loss) on prepaid forward contracts(4) (2,248 ) — (2,248 ) — Add: unrealized gain (loss) on natural gas transportation contracts(5) 10,832 (15,794 ) 15,300 6,274 Operating costs and expenses not allocated to operating segments: Operating expenses (17,870 ) (14,401 ) (54,394 ) (46,597 ) Selling, general and administrative (19,894 ) (14,923 ) (71,193 ) (53,458 ) Depreciation and amortization (5,188 ) (4,373 ) (15,365 ) (12,458 ) Operating income 16,533 3,042 72,202 80,379 Other income — — 514 — Interest income 138 124 367 401 Interest expense (6,399 ) (6,819 ) (20,624 ) (21,548 ) Income tax provision (1,692 ) (1,649 ) (2,490 ) (2,006 ) Net income (loss) $ 8,580 $ (5,302 ) $ 49,969 $ 57,226 (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 (loss). (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 gains (losses) with respect to the derivatives that are included in net income (loss). (4) The unrealized hedging gain (loss) on prepaid forward contracts represents the Partnership’s estimate of the change in fair value of the prepaid forward contracts which are not recorded in net income (loss) until the forward contract is settled in the future (i.e., when the commodity is delivered to the customer). As these contracts are prepaid, they do not qualify as derivatives. The fair value of the derivatives the Partnership uses to economically hedge its prepaid forward contracts declines or appreciates in value as the value of the underlying forward contract appreciates or declines, which creates unrealized hedging gains (losses) with respect to the derivatives that are included in net income (loss). (5) 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 (loss). Segment Assets Due to the commingled 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 September 30, 2015 and December 31, 2014 , goodwill recorded 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 Off-B

Financial Instruments and Off-Balance Sheet Risk	9 Months Ended
	Sep. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Financial Instruments and Off-Balance Sheet Risk	Financial Instruments and Off-Balance Sheet Risk 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 Condensed 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 Condensed Consolidated Balance Sheets. Substantially all of the Partnership’s commodity derivative contracts outstanding as of September 30, 2015 will settle prior to March 31, 2017. 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 (loss) or other comprehensive income (loss) 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 ("Levels") for the inputs used to measure the fair value of financial assets and liabilities based on the source of the input, which 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 OTC 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, OTC 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 and nine months ended September 30, 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 September 30, 2015 or December 31, 2014 . The following table presents financial assets and financial liabilities of the Partnership measured at fair value on a recurring basis: As of September 30, 2015 Fair Value Measurement Quoted Prices in Active Markets Level 1 Significant Other Observable Inputs Level 2 Significant Unobservable Inputs Level 3 Financial assets: Commodity fixed forwards $ 149,992 $ — $ 149,992 $ — Commodity swaps and options 61 — 61 — Commodity derivatives 150,053 — 150,053 — Currency swaps 7 — 7 — Total $ 150,060 $ — $ 150,060 $ — Financial liabilities: Commodity fixed forwards $ 47,817 $ — $ 47,817 $ — Commodity swaps and options 5,161 — 5,161 — Commodity derivatives 52,978 — 52,978 — Interest rate swaps 1,421 — 1,421 — Total $ 54,399 $ — $ 54,399 $ — As of December 31, 2014 Fair Value Quoted Significant Significant 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 fixed forwards $ 80,080 $ — $ 80,080 $ — Commodity swaps and options 8,424 — 8,424 — Commodity exchange contracts 97 97 — — 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 Condensed 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 $150.1 million at September 30, 2015 . Information related to these offsetting arrangements is as follows: As of September 30, 2015 Gross Amount Not Offset in the Balance Sheet Gross Amounts of Recognized Assets/ Liabilities Gross Amounts Offset in the Balance Sheet Amounts of Assets/ Liabilities in Balance Sheet Financial Instruments Cash Collateral Posted Net Amount Commodity derivative assets $ 150,053 $ — $ 150,053 $ (1,814 ) $ (2,180 ) $ 146,059 Currency swap derivative assets 7 — 7 — — 7 Fair value of derivative assets $ 150,060 $ — $ 150,060 $ (1,814 ) $ (2,180 ) $ 146,066 Commodity derivative liabilities $ (52,978 ) $ — $ (52,978 ) $ 1,814 $ — $ (51,164 ) Interest rate swap derivative liabilities (1,421 ) — (1,421 ) — — (1,421 ) Fair value of derivative liabilities $ (54,399 ) $ — $ (54,399 ) $ 1,814 $ — $ (52,585 ) As of December 31, 2014 Gross Amount Not Offset in Gross Amounts of Gross Amounts of Financial Cash Net Amount 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 included in cost of products sold (exclusive of depreciation and amortization) in the Condensed Consolidated Statements of Operations: Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Refined products contracts $ 47,481 $ 34,126 $ 74,086 $ 37,373 Natural gas contracts 11,435 (11,230 ) 12,596 (34,044 ) Total $ 58,916 $ 22,896 $ 86,682 $ 3,329 There were no discretionary trading activities for the three and nine months ended September 30, 2015 and 2014. The following table presents gross volume of commodity derivative instruments outstanding for the periods indicated. As of September 30, 2015 As of December 31, 2014 Refined Products (Barrels) Natural Gas (MMBTUs) Refined Products (Barrels) Natural Gas (MMBTUs) Long contracts 9,482 122,719 10,823 131,376 Short contracts (12,662 ) (74,780 ) (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 September 30, 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 six interest rate swaps with a total notional value of $175.0 million whose swap periods will begin in January 2016 , expiring in January 2017. There was no material ineffectiveness determined for the cash flow hedges for the three and nine months ended September 30, 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 September 30, 2015 , the amount of unrealized losses, net of tax, expected to be reclassified to earnings during the following twelve-month period was approximately $1.2 million . Currency Derivatives Kildair enters into forward currency contracts to mitigate the risk of currency rate fluctuations between its Canadian dollar denominated activity and the U.S. dollar, which is its functional currency. At September 30, 2015 , Kildair held a forward currency swap that matures in October 2015. The contract obligates Kildair to sell $10.0 million in Canadian dollars at an exchange rate of 1.3332 to 1. The Canadian to U.S. dollar exchange rate was 1.3345 to 1 at September 30, 2015 .

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	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.

Equity-Based Compensation

Equity-Based Compensation	9 Months Ended
	Sep. 30, 2015
Equity [Abstract]
Equity-Based Compensation	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 expected bonus payment as a liability until a grant date has been established and awards finalized, which occurs in the first quarter of the year following the year for which the bonus is earned. Approximately $4.9 million of the annual bonus expense accrual as of December 31, 2014 was subsequently settled by issuing 200,775 common units and the Partnership withheld from the recipients 67,141 common units (market value of $1.7 million ) to satisfy minimum tax withholding obligations. The Partnership estimates that $2.7 million of the annual bonus expense recorded during the nine months ended September 30, 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 and 200% ) 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 (vested market value of $1.8 million ) were issued during January 2015. In connection with these vested awards, the Partnership withheld from the recipients 24,605 units (vested market value of $0.6 million ) to satisfy minimum tax withholding obligations. Units issued under the Partnership’s incentive plans are newly issued. Total unrecognized compensation cost related to performance-based phantom units totaled $4.3 million as of September 30, 2015 which is expected to be recognized over a period of 27 months. Performance-based phantom units accrue distribution 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 during the nine months ended September 30, 2015 is set forth below: Restricted Units Time Based Phantom Units Performance-Based Phantom Units Units Weighted Average Grant Date Fair Value (per unit) Units Weighted Average Grant Date Fair Value (per unit) Units Weighted Average Grant Date Fair Value (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 September 30, 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 Holdings Subordinated 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 phantom awards 58,358 — — Balance as of September 30, 2015 8,969,914 2,034,378 10,071,970 Unit-based compensation recorded in unitholders’ equity for the three months ended September 30, 2015 and 2014 was $0.7 million and $2.1 million , respectively, and for the nine months ended September 30, 2015 and 2014 was $2.1 million and $2.7 million , respectively, and is included in selling, general and administrative expenses.

Earnings Per Unit

Earnings Per Unit	9 Months Ended
	Sep. 30, 2015
Earnings Per Share [Abstract]
Earnings Per Unit	Earnings Per Unit Earnings per unit applicable to limited partners (including subordinated unitholders) is computed by dividing limited partners’ interest in net income (loss), 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 ownership percentages, after giving effect to priority income allocations for incentive distributions, 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 (loss) allocations used in the calculation of earnings (loss) 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 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 periods indicated. Three Months Ended September 30 Nine Months Ended September 30 2015 2014 2015 2014 Weighted average limited partner common units - basic 10,999,848 10,091,388 10,965,400 10,085,058 Dilutive effect of unvested restricted and phantom units 253,547 — 233,728 35,877 Weighted average limited partner common units - dilutive 11,253,395 10,091,388 11,199,128 10,120,935 The following tables provide a reconciliation of net income (loss) and the assumed allocation of net income (loss) to the limited partners’ interest for purposes of computing net income (loss) per unit for the periods presented: Three Months Ended September 30, 2015 Common Subordinated IDR Total (in thousands, except for per unit amounts) Net income $ 8,580 Distributions declared $ 5,533 $ 5,061 $ 105 $ 10,699 Assumed net loss from operations after distributions (1,109 ) (1,010 ) — (2,119 ) Assumed net income to be allocated $ 4,424 $ 4,051 $ 105 $ 8,580 Loss per unit - basic $ 0.40 $ 0.40 Loss per unit - diluted $ 0.39 $ 0.40 Three Months Ended September 30, 2014 Common Subordinated IDR Total (in thousands, except for per unit amounts) Net loss $ (5,302 ) Income attributable to Kildair (Note 2) (5,416 ) $ (10,718 ) Distributions declared $ 4,502 $ 4,457 $ — $ 8,959 Assumed net loss from operations after distributions (9,866 ) (9,811 ) — (19,677 ) Assumed net loss to be allocated $ (5,364 ) $ (5,354 ) $ — $ (10,718 ) Loss per unit - basic $ (0.53 ) $ (0.53 ) Loss per unit - diluted $ (0.53 ) $ (0.53 ) Nine Months Ended September 30, 2015 Common Subordinated IDR Total (in thousands, except for per unit amounts) Net income $ 49,969 Distributions declared $ 16,102 $ 14,730 $ 154 $ 30,986 Assumed net income from operations after distributions 9,863 9,120 — 18,983 Assumed net income to be allocated $ 25,965 $ 23,850 $ 154 $ 49,969 Earnings per unit - basic $ 2.37 $ 2.37 Earnings per unit - diluted $ 2.32 $ 2.37 Nine Months Ended September 30, 2014 Common Subordinated IDR Total (in thousands, except for per unit amounts) Net income $ 57,226 Income attributable to Kildair (Note 2) (2,103 ) $ 55,123 Distributions declared $ 12,984 $ 12,918 $ — $ 25,902 Assumed net income from operations after distributions 14,595 14,626 — 29,221 Assumed net income to be allocated $ 27,579 $ 27,544 $ — $ 55,123 Earnings per unit - basic $ 2.73 $ 2.73 Earnings per unit - diluted $ 2.73 $ 2.73

Partnership Distributions

Partnership Distributions	9 Months Ended
	Sep. 30, 2015
Equity [Abstract]
Partnership Distributions	Partnership Distributions The Partnership agreement sets forth the calculation to be used to determine the amount and priority of cash distributions to the common and subordinated unitholders. As holder of the IDRs, Sprague Holdings is entitled to incentive distributions if the amount that the Partnership distributes exceeds specified target levels shown below: Marginal Percentage Interest in Cash Distributions Quarterly Distribution per Unit Target Amount Unitholders Incentive Distribution Rights Holders Minimum Quarterly Distribution $0.4125 100% 0% First Target Distribution above $0.4125 up to $0.474375 100% 0% Second Target Distribution above $0.474375 up to $0.515625 85% 15% Third Target Distribution above $0.515625 up to $0.61875 75% 25% Thereafter above $0.61875 50% 50% On January 28, 2015 , the Partnership declared a cash distribution of $0.4575 per unit for the three months ended December 31, 2014, which was paid on February 13, 2015 , to unitholders of record on February 9, 2015 . On April 29, 2015 , the Partnership declared a cash distribution of $0.4725 per unit for the three months ended March 31, 2015, which was paid on May 15, 2015 , to unitholders of record on May 11, 2015 . On July 29, 2015, the Partnership declared a cash distribution of $0.4875 per unit for the three months ended June 30, 2015, which was paid on August 14, 2015, to unitholders of record on August 10, 2015. In addition, on October 28, 2015 , the Partnership declared a cash distribution of $0.5025 per unit for the three months ended September 30, 2015 , to be paid on November 13, 2015 , to unitholders of record on November 10, 2015 .

Description of Business and S20

Description of Business and Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 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 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. The Partnership's 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 consolidated financial statements included herein reflect all normal and recurring adjustments which, in the opinion of management, are necessary for a fair presentation of the Partnership’s consolidated financial position at September 30, 2015 and December 31, 2014 and the consolidated results of operations and cash flows for the three and nine months ended September 30, 2015 and 2014, respectively. 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.
New Accounting Guidance	Recent Accounting Pronouncements In October 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standard Update (“ASU”) 2015-16, Simplifying the Accounting for Measurement-Period Adjustments which requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. The Partnership is currently evaluating the potential impact of this guidance which is effective for fiscal years beginning after December 15, 2015 and interim periods within those fiscal years. In July 2015, the FASB issued ASU 2015-11, Simplifying the Measurement of Inventory , which requires that inventory within the scope of the guidance be measured at the lower of cost or net realizable value. The Partnership is currently evaluating the potential impact of this guidance which is effective for fiscal years beginning after December 15, 2016 and interim periods within those fiscal years. In April 2015, the FASB issued ASU 2015-6, 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 FASB issued ASU 2015-3, Simplifying the Presentation of Debt Issuance Costs, ("ASU 2015-3") 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. In August 2015, the FASB issued ASU 2015-15 to reflect SEC commentary that given the absence of authoritative guidance within ASU 2015-03 for debt issuance costs related to line-of-credit arrangements, the SEC would not object to an entity deferring and presenting debt issuance costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. The Partnership has not yet adopted the provisions of ASU 2015-3, which is effective for annual reporting periods beginning after December 15, 2015, and interim periods within those fiscal years. As of September 30, 2015 and December 31, 2014, the Partnership’s unamortized debt issuance costs were $15.1 million and $15.5 million , respectively. In May 2014, the FASB issued ASU 2014-9, 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. In July 2015, the FASB issued ASU-2015-14, Revenue from Contracts with Customers-Deferral of the Effective Date which establishes the effective date of this guidance for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. The Partnership continues to evaluate both the impact of this new standard on the consolidated financial statements and the transition method it will utilize for adoption

Business Combinations (Tables)

Business Combinations (Tables)	9 Months Ended
	Sep. 30, 2015
Business Combinations [Abstract]
Summary of Business Acquisition, Pro Forma Consolidated Net Sales and Net Income (Loss)	The following table represents the unaudited pro forma consolidated net sales and net (loss) income as if Castle had been included in the unaudited condensed consolidated results for the periods presented below: Three Months Ended September 30, 2014 Nine Months Ended September 30, 2014 Net sales $ 964,120 $ 4,497,657 Net (loss) income $ (8,673 ) $ 61,750 Limited partners’ interest in net (loss) income $ (14,089 ) $ 59,647 Net (loss) income per limited partner common unit - basic $ (0.69 ) $ 2.93 Net (loss) income per limited partner common unit - diluted $ (0.69 ) $ 2.93

Accumulated Other Comprehensi22

Accumulated Other Comprehensive Loss, Net of Tax (Tables)	9 Months Ended
	Sep. 30, 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: September 30, 2015 December 31, 2014 Fair value of interest rate swaps, net of tax $ (1,381 ) $ (406 ) Cumulative foreign currency translation adjustment (10,832 ) (9,427 ) Accumulated other comprehensive loss, net of tax $ (12,213 ) $ (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 September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Balance - beginning of period $ (10,676 ) $ (8,287 ) $ (9,427 ) $ (8,284 ) Foreign currency translation adjustment (156 ) (662 ) (1,405 ) (665 ) Balance - end of period $ (10,832 ) $ (8,949 ) $ (10,832 ) $ (8,949 )

Inventories (Tables)

Inventories (Tables)	9 Months Ended
	Sep. 30, 2015
Inventory Disclosure [Abstract]
Schedule of Inventories	September 30, December 31, Petroleum and related products $ 200,849 $ 366,431 Asphalt 24,630 18,357 Natural gas 1,450 3,387 Coal 2,487 2,380 Inventories $ 229,416 $ 390,555

Debt (Tables)

Debt (Tables)	9 Months Ended
	Sep. 30, 2015
Debt Disclosure [Abstract]
Schedule of Debt	September 30, December 31, 2014 Current debt Credit agreement $ 229,839 $ 396,961 Other 220 253 Current debt 230,059 397,214 Long-term debt Credit agreement 324,661 417,789 Other 433 567 Long-term debt 325,094 418,356 Total debt $ 555,153 $ 815,570

Segment Reporting (Tables)

Segment Reporting (Tables)	9 Months Ended
	Sep. 30, 2015
Segment Reporting [Abstract]
Summary of Financial Information for Partnership's Reportable Segments	Summarized financial information for the Partnership’s reportable segments is presented in the table below: Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 (in thousands) (in thousands) Net sales: Refined products $ 488,639 $ 830,821 $ 2,499,335 $ 3,574,461 Natural gas 52,568 53,376 265,805 255,058 Materials handling 12,027 9,790 33,905 26,868 Other operations 4,788 3,421 19,078 15,381 Net sales $ 558,022 $ 897,408 $ 2,818,123 $ 3,871,768 Adjusted gross margin(1): Refined products $ 31,852 $ 32,176 $ 124,101 $ 101,868 Natural gas 4,423 4,604 40,556 42,614 Materials handling 12,027 9,816 33,899 26,886 Other operations 2,024 1,251 6,648 3,939 Adjusted gross margin 50,326 47,847 205,204 175,307 Reconciliation to operating income(2): Add: unrealized gain (loss) on inventory(3) 575 4,686 (5,102 ) 11,311 Add: unrealized gain (loss) on prepaid forward contracts(4) (2,248 ) — (2,248 ) — Add: unrealized gain (loss) on natural gas transportation contracts(5) 10,832 (15,794 ) 15,300 6,274 Operating costs and expenses not allocated to operating segments: Operating expenses (17,870 ) (14,401 ) (54,394 ) (46,597 ) Selling, general and administrative (19,894 ) (14,923 ) (71,193 ) (53,458 ) Depreciation and amortization (5,188 ) (4,373 ) (15,365 ) (12,458 ) Operating income 16,533 3,042 72,202 80,379 Other income — — 514 — Interest income 138 124 367 401 Interest expense (6,399 ) (6,819 ) (20,624 ) (21,548 ) Income tax provision (1,692 ) (1,649 ) (2,490 ) (2,006 ) Net income (loss) $ 8,580 $ (5,302 ) $ 49,969 $ 57,226 (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 (loss). (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 gains (losses) with respect to the derivatives that are included in net income (loss). (4) The unrealized hedging gain (loss) on prepaid forward contracts represents the Partnership’s estimate of the change in fair value of the prepaid forward contracts which are not recorded in net income (loss) until the forward contract is settled in the future (i.e., when the commodity is delivered to the customer). As these contracts are prepaid, they do not qualify as derivatives. The fair value of the derivatives the Partnership uses to economically hedge its prepaid forward contracts declines or appreciates in value as the value of the underlying forward contract appreciates or declines, which creates unrealized hedging gains (losses) with respect to the derivatives that are included in net income (loss). (5) 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 (loss).

Financial Instruments and Off26

Financial Instruments and Off-Balance Sheet Risk (Tables)	9 Months Ended
	Sep. 30, 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 financial assets and financial liabilities of the Partnership measured at fair value on a recurring basis: As of September 30, 2015 Fair Value Measurement Quoted Prices in Active Markets Level 1 Significant Other Observable Inputs Level 2 Significant Unobservable Inputs Level 3 Financial assets: Commodity fixed forwards $ 149,992 $ — $ 149,992 $ — Commodity swaps and options 61 — 61 — Commodity derivatives 150,053 — 150,053 — Currency swaps 7 — 7 — Total $ 150,060 $ — $ 150,060 $ — Financial liabilities: Commodity fixed forwards $ 47,817 $ — $ 47,817 $ — Commodity swaps and options 5,161 — 5,161 — Commodity derivatives 52,978 — 52,978 — Interest rate swaps 1,421 — 1,421 — Total $ 54,399 $ — $ 54,399 $ — As of December 31, 2014 Fair Value Quoted Significant Significant 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 fixed forwards $ 80,080 $ — $ 80,080 $ — Commodity swaps and options 8,424 — 8,424 — Commodity exchange contracts 97 97 — — 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 Assets	Information related to these offsetting arrangements is as follows: As of September 30, 2015 Gross Amount Not Offset in the Balance Sheet Gross Amounts of Recognized Assets/ Liabilities Gross Amounts Offset in the Balance Sheet Amounts of Assets/ Liabilities in Balance Sheet Financial Instruments Cash Collateral Posted Net Amount Commodity derivative assets $ 150,053 $ — $ 150,053 $ (1,814 ) $ (2,180 ) $ 146,059 Currency swap derivative assets 7 — 7 — — 7 Fair value of derivative assets $ 150,060 $ — $ 150,060 $ (1,814 ) $ (2,180 ) $ 146,066 Commodity derivative liabilities $ (52,978 ) $ — $ (52,978 ) $ 1,814 $ — $ (51,164 ) Interest rate swap derivative liabilities (1,421 ) — (1,421 ) — — (1,421 ) Fair value of derivative liabilities $ (54,399 ) $ — $ (54,399 ) $ 1,814 $ — $ (52,585 ) As of December 31, 2014 Gross Amount Not Offset in Gross Amounts of Gross Amounts of Financial Cash Net Amount 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 Offsetting Liabilities	Information related to these offsetting arrangements is as follows: As of September 30, 2015 Gross Amount Not Offset in the Balance Sheet Gross Amounts of Recognized Assets/ Liabilities Gross Amounts Offset in the Balance Sheet Amounts of Assets/ Liabilities in Balance Sheet Financial Instruments Cash Collateral Posted Net Amount Commodity derivative assets $ 150,053 $ — $ 150,053 $ (1,814 ) $ (2,180 ) $ 146,059 Currency swap derivative assets 7 — 7 — — 7 Fair value of derivative assets $ 150,060 $ — $ 150,060 $ (1,814 ) $ (2,180 ) $ 146,066 Commodity derivative liabilities $ (52,978 ) $ — $ (52,978 ) $ 1,814 $ — $ (51,164 ) Interest rate swap derivative liabilities (1,421 ) — (1,421 ) — — (1,421 ) Fair value of derivative liabilities $ (54,399 ) $ — $ (54,399 ) $ 1,814 $ — $ (52,585 ) As of December 31, 2014 Gross Amount Not Offset in Gross Amounts of Gross Amounts of Financial Cash Net Amount 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 included in cost of products sold (exclusive of depreciation and amortization) in the Condensed Consolidated Statements of Operations: Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Refined products contracts $ 47,481 $ 34,126 $ 74,086 $ 37,373 Natural gas contracts 11,435 (11,230 ) 12,596 (34,044 ) Total $ 58,916 $ 22,896 $ 86,682 $ 3,329
Schedule of Gross Volume of Commodity Derivative Instruments Outstanding	The following table presents gross volume of commodity derivative instruments outstanding for the periods indicated. As of September 30, 2015 As of December 31, 2014 Refined Products (Barrels) Natural Gas (MMBTUs) Refined Products (Barrels) Natural Gas (MMBTUs) Long contracts 9,482 122,719 10,823 131,376 Short contracts (12,662 ) (74,780 ) (15,434 ) (82,796 )

Equity-Based Compensation (Tabl

Equity-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2015
Equity [Abstract]
Summary of Partnership's Unit Awards Subject to Vesting	A summary of the Partnership’s unit awards subject to vesting during the nine months ended September 30, 2015 is set forth below: Restricted Units Time Based Phantom Units Performance-Based Phantom Units Units Weighted Average Grant Date Fair Value (per unit) Units Weighted Average Grant Date Fair Value (per unit) Units Weighted Average Grant Date Fair Value (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 September 30, 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 Holdings Subordinated 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 phantom awards 58,358 — — Balance as of September 30, 2015 8,969,914 2,034,378 10,071,970

Earnings Per Unit (Tables)

Earnings Per Unit (Tables)	9 Months Ended
	Sep. 30, 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 periods indicated. Three Months Ended September 30 Nine Months Ended September 30 2015 2014 2015 2014 Weighted average limited partner common units - basic 10,999,848 10,091,388 10,965,400 10,085,058 Dilutive effect of unvested restricted and phantom units 253,547 — 233,728 35,877 Weighted average limited partner common units - dilutive 11,253,395 10,091,388 11,199,128 10,120,935
Schedule of Reconciliation and Assumed Allocation of Net Income to Limited Partners' Interest for Computing Net Income Per Unit	The following tables provide a reconciliation of net income (loss) and the assumed allocation of net income (loss) to the limited partners’ interest for purposes of computing net income (loss) per unit for the periods presented: Three Months Ended September 30, 2015 Common Subordinated IDR Total (in thousands, except for per unit amounts) Net income $ 8,580 Distributions declared $ 5,533 $ 5,061 $ 105 $ 10,699 Assumed net loss from operations after distributions (1,109 ) (1,010 ) — (2,119 ) Assumed net income to be allocated $ 4,424 $ 4,051 $ 105 $ 8,580 Loss per unit - basic $ 0.40 $ 0.40 Loss per unit - diluted $ 0.39 $ 0.40 Three Months Ended September 30, 2014 Common Subordinated IDR Total (in thousands, except for per unit amounts) Net loss $ (5,302 ) Income attributable to Kildair (Note 2) (5,416 ) $ (10,718 ) Distributions declared $ 4,502 $ 4,457 $ — $ 8,959 Assumed net loss from operations after distributions (9,866 ) (9,811 ) — (19,677 ) Assumed net loss to be allocated $ (5,364 ) $ (5,354 ) $ — $ (10,718 ) Loss per unit - basic $ (0.53 ) $ (0.53 ) Loss per unit - diluted $ (0.53 ) $ (0.53 ) Nine Months Ended September 30, 2015 Common Subordinated IDR Total (in thousands, except for per unit amounts) Net income $ 49,969 Distributions declared $ 16,102 $ 14,730 $ 154 $ 30,986 Assumed net income from operations after distributions 9,863 9,120 — 18,983 Assumed net income to be allocated $ 25,965 $ 23,850 $ 154 $ 49,969 Earnings per unit - basic $ 2.37 $ 2.37 Earnings per unit - diluted $ 2.32 $ 2.37 Nine Months Ended September 30, 2014 Common Subordinated IDR Total (in thousands, except for per unit amounts) Net income $ 57,226 Income attributable to Kildair (Note 2) (2,103 ) $ 55,123 Distributions declared $ 12,984 $ 12,918 $ — $ 25,902 Assumed net income from operations after distributions 14,595 14,626 — 29,221 Assumed net income to be allocated $ 27,579 $ 27,544 $ — $ 55,123 Earnings per unit - basic $ 2.73 $ 2.73 Earnings per unit - diluted $ 2.73 $ 2.73

Partnership Distributions (Tabl

Partnership Distributions (Tables)	9 Months Ended
	Sep. 30, 2015
Equity [Abstract]
Schedule of Incentive Distribution Amount Exceeds Specified Target Levels that Partnership Distributes	The Partnership agreement sets forth the calculation to be used to determine the amount and priority of cash distributions to the common and subordinated unitholders. As holder of the IDRs, Sprague Holdings is entitled to incentive distributions if the amount that the Partnership distributes exceeds specified target levels shown below: Marginal Percentage Interest in Cash Distributions Quarterly Distribution per Unit Target Amount Unitholders Incentive Distribution Rights Holders Minimum Quarterly Distribution $0.4125 100% 0% First Target Distribution above $0.4125 up to $0.474375 100% 0% Second Target Distribution above $0.474375 up to $0.515625 85% 15% Third Target Distribution above $0.515625 up to $0.61875 75% 25% Thereafter above $0.61875 50% 50%

Description of Business and S30

Description of Business and Summary of Significant Accounting Policies - Additional Information (Detail) $ / shares in Units, $ in Millions	9 Months Ended
	Sep. 30, 2015USD ($)Segment$ / sharesTerminal	Jun. 30, 2015shares	Dec. 31, 2014USD ($)
Nature Of Business And Basis Of Presentation [Line Items]
Limited partnership formation date	Jun. 23, 2011
Number of terminals owned | Terminal	19
Number of reporting operating segments | Segment	4
Distributions from distributable cash flow | $ / shares	$ 0.474375
Unamortized debt issuance costs | $	$ 15.1		$ 15.5
Maximum
Nature Of Business And Basis Of Presentation [Line Items]
Percentages incentive distribution rights		50.00%
Sprague Holdings
Nature Of Business And Basis Of Presentation [Line Items]
Common units issued		2,034,378
Percentage of limited partnership interest	57.00%
Subordinated Units | Sprague Holdings
Nature Of Business And Basis Of Presentation [Line Items]
Common units issued		10,071,970

Business Combinations - Additio

Business Combinations - Additional Information (Detail) $ in Millions	Dec. 09, 2014USD ($)	Dec. 08, 2014USD ($)bbl	Oct. 01, 2014USD ($)	Sep. 30, 2015
Kildair
Business Acquisition [Line Items]
Business acquisition, effective date of acquisition				Dec. 9, 2014
Business acquisition, purchase price	$ 175
Business acquisition, common stock value	$ 10
Castle
Business Acquisition [Line Items]
Business acquisition, effective date of acquisition				Dec. 8, 2014
Business acquisition, purchase price		$ 45.3
Business acquisition, common stock value		5.3
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 | bbl		900,000
Metromedia Energy
Business Acquisition [Line Items]
Business acquisition, effective date of acquisition				Oct. 1, 2014
Business acquisition, purchase price			$ 32.8
Payments to acquire businesses			$ 22

Business Combinations - Summary

Business Combinations - Summary of Business Acquisition, Pro Forma Consolidated Net Sales and Net Income (Loss) (Detail) - Castle - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2014
Business Acquisition [Line Items]
Net sales	$ 964,120	$ 4,497,657
Net (loss) income	(8,673)	61,750
Limited partners’ interest in net (loss) income	$ (14,089)	$ 59,647
Net (loss) income per limited partner common unit - basic	$ (0.69)	$ 2.93
Net (loss) income per limited partner common unit - diluted	$ (0.69)	$ 2.93

Accumulated Other Comprehensi33

Accumulated Other Comprehensive Loss, Net of Tax - Schedule of Accumulated Other Comprehensive Loss, Net of Tax (Detail) - USD ($) $ in Thousands	Sep. 30, 2015	Jun. 30, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Dec. 31, 2013
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Fair value of interest rate swaps, net of tax	$ (1,381)		$ (406)
Cumulative foreign currency translation adjustment	(10,832)	$ (10,676)	(9,427)	$ (8,949)	$ (8,287)	$ (8,284)
Accumulated other comprehensive loss, net of tax	$ (12,213)		$ (9,833)

Accumulated Other Comprehensi34

Accumulated Other Comprehensive Loss, Net of Tax - Summary of Changes in Accumulated Other Comprehensive Loss Related to Foreign Currency Translation (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Cumulative Translation Adjustment Summary [Roll Forward]
Balance - beginning of period	$ (10,676)	$ (8,287)	$ (9,427)	$ (8,284)
Foreign currency translation adjustment	(156)	(662)	(1,405)	(665)
Balance - end of period	$ (10,832)	$ (8,949)	$ (10,832)	$ (8,949)

Inventories - Schedule of Inven

Inventories - Schedule of Inventories (Detail) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Inventory [Line Items]
Inventories	$ 229,416	$ 390,555
Petroleum and Related Products
Inventory [Line Items]
Inventories	200,849	366,431
Asphalt
Inventory [Line Items]
Inventories	24,630	18,357
Natural Gas
Inventory [Line Items]
Inventories	1,450	3,387
Coal
Inventory [Line Items]
Inventories	$ 2,487	$ 2,380

Inventories - Additional Inform

Inventories - Additional Information (Detail) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Petroleum, Natural Gas and Asphalt Inventory
Public Utilities, Inventory [Line Items]
Provision for inventory write-down	$ 10.6	$ 50.5

Debt - Schedule of Debt (Detail

Debt - Schedule of Debt (Detail) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Current debt
Credit agreement	$ 229,839	$ 396,961
Other	220	253
Current debt	230,059	397,214
Long-term debt
Credit agreement	324,661	417,789
Other	433	567
Long-term debt	325,094	418,356
Total debt	$ 555,153	$ 815,570

Debt - Additional Information (

Debt - Additional Information (Detail) - USD ($)	Dec. 09, 2014	Sep. 30, 2015	Dec. 31, 2014
Working Capital Facility | Federal Funds Rate | U.S. dollar
Debt Instrument [Line Items]
Debt instruments, interest rate		0.50%
Working Capital Facility | Eurocurrency Rate | U.S. dollar
Debt Instrument [Line Items]
Debt instruments, interest rate		1.00%
Working Capital Facility | Eurocurrency Rate | Canadian Dollars
Debt Instrument [Line Items]
Debt instruments, interest rate		1.00%
Working Capital Facility | Amended and Restated Revolving Credit Agreement
Debt Instrument [Line Items]
Debt instrument, potential increase in maximum borrowing capacity	$ 200,000,000
Acquisition Credit Facility | Amended and Restated Revolving Credit Agreement
Debt Instrument [Line Items]
Debt instrument, potential increase in maximum borrowing capacity	200,000,000
Credit Agreement
Debt Instrument [Line Items]
Agreement amendment date		Dec. 9, 2014
Debt instruments, weighted average interest rate		3.00%	2.80%
Credit Agreement | Amended and Restated Revolving Credit Agreement
Debt Instrument [Line Items]
Debt instruments, maturity date		Dec. 9, 2019
Credit Agreement | Working Capital Facility
Debt Instrument [Line Items]
Borrowings under Credit Agreement		$ 248,400,000	$ 503,200,000
Letters of credit outstanding		15,700,000	120,200,000
Borrowing base under Credit Agreement		477,700,000	843,300,000
Excess availability under Credit Agreement		213,600,000
Credit Agreement | Working Capital Facility | Amended and Restated Revolving Credit Agreement
Debt Instrument [Line Items]
Debt instruments, borrowing capacity	1,000,000,000
Credit Agreement | Working Capital Facility | Amended and Restated Revolving Credit Agreement | Kildair
Debt Instrument [Line Items]
Debt instruments, borrowing capacity	120,000,000
Credit Agreement | Acquisition Credit Facility
Debt Instrument [Line Items]
Borrowings under Credit Agreement		306,100,000	$ 311,600,000
Excess availability under Credit Agreement		$ 93,900,000
Credit Agreement | Acquisition Credit Facility | Amended and Restated Revolving Credit Agreement
Debt Instrument [Line Items]
Debt instruments, borrowing capacity	$ 400,000,000

Related Party Transactions - Ad

Related Party Transactions - Additional Information (Detail) - General Partner - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Related Party Transaction [Line Items]
Reimbursement of employees related benefits expenses and other costs	$ 22.5	$ 13.4	$ 76.2	$ 58.5
Amounts due to General Partner	$ 14.2		$ 14.2		$ 16.3

Segment Reporting - Additional

Segment Reporting - Additional Information (Detail) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015USD ($)Customer	Sep. 30, 2014USD ($)Customer	Sep. 30, 2015USD ($)CustomerSegment	Sep. 30, 2014USD ($)Customer	Jun. 30, 2015USD ($)	Dec. 31, 2014USD ($)
Segment Reporting Information [Line Items]
Number of reporting operating segments | Segment			4
Net sales	$ 558,022	$ 897,408	$ 2,818,123	$ 3,871,768
Significant fixed assets	937,978		937,978			$ 1,339,840
Goodwill	63,288		63,288			63,288
Canada
Segment Reporting Information [Line Items]
Net sales	55,400	$ 93,200	163,400	$ 268,700
Natural Gas
Segment Reporting Information [Line Items]
Significant fixed assets					$ 0
Goodwill	18,600		18,600			18,600
Refined Products
Segment Reporting Information [Line Items]
Goodwill	36,600		36,600			36,600
Materials Handling
Segment Reporting Information [Line Items]
Goodwill	6,900		6,900			6,900
Other Operations
Segment Reporting Information [Line Items]
Goodwill	$ 1,200		$ 1,200			$ 1,200
Sales Revenue, Net | Customer Concentration Risk
Segment Reporting Information [Line Items]
Number of customers accounted for more than 10% of revenue | Customer	0	0	0	0

Segment Reporting - Summary of

Segment Reporting - Summary of Financial Information for Partnership's Reportable Segments (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Net sales:
Net sales	$ 558,022	$ 897,408	$ 2,818,123	$ 3,871,768
Operating costs and expenses not allocated to operating segments:
Operating expenses	(17,870)	(14,401)	(54,394)	(46,597)
Selling, general and administrative	(19,894)	(14,923)	(71,193)	(53,458)
Depreciation and amortization	(5,188)	(4,373)	(15,365)	(12,458)
Operating income	16,533	3,042	72,202	80,379
Other income	0	0	514	0
Interest income	138	124	367	401
Interest expense	(6,399)	(6,819)	(20,624)	(21,548)
Income tax provision	(1,692)	(1,649)	(2,490)	(2,006)
Net income (loss)	8,580	(5,302)	49,969	57,226	$ 122,814
Operating Segments
Adjusted gross margin:
Adjusted gross margin	50,326	47,847	205,204	175,307
Operating Segments | Refined Products
Net sales:
Net sales	488,639	830,821	2,499,335	3,574,461
Adjusted gross margin:
Adjusted gross margin	31,852	32,176	124,101	101,868
Operating Segments | Natural Gas
Net sales:
Net sales	52,568	53,376	265,805	255,058
Adjusted gross margin:
Adjusted gross margin	4,423	4,604	40,556	42,614
Operating Segments | Materials Handling
Net sales:
Net sales	12,027	9,790	33,905	26,868
Adjusted gross margin:
Adjusted gross margin	12,027	9,816	33,899	26,886
Operating Segments | Other Operations
Net sales:
Net sales	4,788	3,421	19,078	15,381
Adjusted gross margin:
Adjusted gross margin	2,024	1,251	6,648	3,939
Segment Reconciling Items
Reconciliation to operating income:
Add: unrealized gain (loss) on inventory	575	4,686	(5,102)	11,311
Add: unrealized gain (loss) on prepaid forward contracts	(2,248)	0	(2,248)	0
Add: unrealized gain (loss) on natural gas transportation contracts	10,832	(15,794)	15,300	6,274
Operating costs and expenses not allocated to operating segments:
Operating expenses	(17,870)	(14,401)	(54,394)	(46,597)
Selling, general and administrative	(19,894)	(14,923)	(71,193)	(53,458)
Depreciation and amortization	$ (5,188)	$ (4,373)	$ (15,365)	$ (12,458)

Financial Instruments and Off42

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 ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Financial assets:
Financial assets	$ 150,060	$ 229,890
Financial liabilities:
Financial liabilities	54,399	89,176
Commodity Fixed Forwards
Financial assets:
Financial assets	149,992	229,679
Financial liabilities:
Financial liabilities	47,817	80,080
Commodity Swaps and Options
Financial assets:
Financial assets	61	74
Financial liabilities:
Financial liabilities	5,161	8,424
Commodity Exchange Contracts
Financial liabilities:
Financial liabilities		97
Commodity Derivatives
Financial assets:
Financial assets	150,053	229,753
Financial liabilities:
Financial liabilities	52,978	88,601
Interest Rate Swap
Financial assets:
Financial assets		137
Financial liabilities:
Financial liabilities	1,421	553
Currency Swap
Financial assets:
Financial assets	7
Financial liabilities:
Financial liabilities		22
Quoted Prices in Active Markets Level 1
Financial assets:
Financial assets	0
Financial liabilities:
Financial liabilities	0	97
Quoted Prices in Active Markets Level 1 | Commodity Fixed Forwards
Financial liabilities:
Financial liabilities		0
Quoted Prices in Active Markets Level 1 | Commodity Exchange Contracts
Financial liabilities:
Financial liabilities		97
Quoted Prices in Active Markets Level 1 | Commodity Derivatives
Financial assets:
Financial assets	0
Financial liabilities:
Financial liabilities	0	97
Significant Other Observable Inputs Level 2
Financial assets:
Financial assets	150,060	229,890
Financial liabilities:
Financial liabilities	54,399	89,079
Significant Other Observable Inputs Level 2 | Commodity Fixed Forwards
Financial assets:
Financial assets	149,992	229,679
Financial liabilities:
Financial liabilities	47,817	80,080
Significant Other Observable Inputs Level 2 | Commodity Swaps and Options
Financial assets:
Financial assets	61	74
Financial liabilities:
Financial liabilities	5,161	8,424
Significant Other Observable Inputs Level 2 | Commodity Exchange Contracts
Financial liabilities:
Financial liabilities		0
Significant Other Observable Inputs Level 2 | Commodity Derivatives
Financial assets:
Financial assets	150,053	229,753
Financial liabilities:
Financial liabilities	52,978	88,504
Significant Other Observable Inputs Level 2 | Interest Rate Swap
Financial assets:
Financial assets		137
Financial liabilities:
Financial liabilities	1,421	553
Significant Other Observable Inputs Level 2 | Currency Swap
Financial assets:
Financial assets	$ 7
Financial liabilities:
Financial liabilities		$ 22

Financial Instruments and Off43

Financial Instruments and Off-Balance Sheet Risk - Additional Information (Detail) CAD in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2014USD ($)	Sep. 30, 2015USD ($)	Sep. 30, 2014USD ($)	Oct. 31, 2015	Sep. 30, 2015CADInterest_Rate_Swaps	Sep. 30, 2015USD ($)Interest_Rate_Swaps	Dec. 31, 2014USD ($)
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gross fair value of financial instruments						$ 150,060,000	$ 229,890,000
Contracts obligate Canadian subsidiary to sell U.S. dollars at exchange rate | CAD					CAD 10
Canadian Dollars
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Foreign currency exchange rate					1.3345	1.3345
Interest Rate Swap
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Material ineffectiveness for the cash flow hedges	$ 0	$ 0	$ 0
Unrealized losses, net of tax, expected to be reclassified to earnings						$ 1,200,000
Interest Rate Swap | Six Interest Rate Swap Agreements
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of interest rate swap | Interest_Rate_Swaps					6	6
Notional amount of interest rate swap agreements						$ 175,000,000
Notional amount of interest rate swaps expiration period		2016-01
Notional amount of interest rate swaps beginning period		2015-01
Interest Rate Swap | Six Interest Rate Swap Agreements Expires in January 2017
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of interest rate swap | Interest_Rate_Swaps					6	6
Notional amount of interest rate swap agreements						$ 175,000,000
Notional amount of interest rate swaps expiration period		2017-01
Notional amount of interest rate swaps beginning period		2016-01
Forward Currency Swaps
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, maturity date		Jul. 31, 2015
Foreign currency contract, currency		The contract obligates Kildair to sell $10.0 million in Canadian dollars at an exchange rate of 1.3332 to 1.
Subsequent Event | Canadian Dollars
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Foreign currency exchange rate				1.3332

Financial Instruments and Off44

Financial Instruments and Off-Balance Sheet Risk - Summary of Offsetting Arrangements (Detail) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gross Amount of Recognized Assets	$ 150,060	$ 229,890
Gross Amounts Offset in the Balance Sheert, Assets	0	0
Amounts of Assets In Balance Sheet	150,060	229,890
Financial Instruments, Assets	(1,814)	(4,831)
Cash Collateral Posted	(2,180)	(2,417)
Net Amount, Assets	146,066	222,642
Gross Amount of Recognized Liabilities	(54,399)	(89,176)
Gross Amounts Offset in the Balance Sheet, Liabilities	0	0
Amounts of Liabilities in Balance Sheet	(54,399)	(89,176)
Financial Instruments, Liabilities	1,814	4,831
Net Amount, Liabilities	(52,585)	(84,345)
Commodity Derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gross Amount of Recognized Assets	150,053	229,753
Gross Amounts Offset in the Balance Sheert, Assets	0	0
Amounts of Assets In Balance Sheet	150,053	229,753
Financial Instruments, Assets	(1,814)	(4,831)
Cash Collateral Posted	(2,180)	(2,417)
Net Amount, Assets	146,059	222,505
Gross Amount of Recognized Liabilities	(52,978)	(88,601)
Gross Amounts Offset in the Balance Sheet, Liabilities	0	0
Amounts of Liabilities in Balance Sheet	(52,978)	(88,601)
Financial Instruments, Liabilities	1,814	4,831
Net Amount, Liabilities	(51,164)	(83,770)
Currency Swap
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gross Amount of Recognized Assets	7
Gross Amounts Offset in the Balance Sheert, Assets	0
Amounts of Assets In Balance Sheet	7
Net Amount, Assets	7
Gross Amount of Recognized Liabilities		(22)
Gross Amounts Offset in the Balance Sheet, Liabilities		0
Amounts of Liabilities in Balance Sheet		(22)
Net Amount, Liabilities		(22)
Interest Rate Swap
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gross Amount of Recognized Assets		137
Gross Amounts Offset in the Balance Sheert, Assets		0
Amounts of Assets In Balance Sheet		137
Net Amount, Assets		137
Gross Amount of Recognized Liabilities	(1,421)	(553)
Gross Amounts Offset in the Balance Sheet, Liabilities	0	0
Amounts of Liabilities in Balance Sheet	(1,421)	(553)
Net Amount, Liabilities	$ (1,421)	$ (553)

Financial Instruments and Off45

Financial Instruments and Off-Balance Sheet Risk - Summary of Realized and Unrealized Gains (Losses) on Derivative Instruments for Commodity Risk Management (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized and unrealized gains (losses) on derivative instruments	$ 58,916	$ 22,896	$ 86,682	$ 3,329
Refined Products Contracts
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized and unrealized gains (losses) on derivative instruments	47,481	34,126	74,086	37,373
Natural Gas Contracts
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized and unrealized gains (losses) on derivative instruments	$ 11,435	$ (11,230)	$ 12,596	$ (34,044)

Financial Instruments and Off46

Financial Instruments and Off-Balance Sheet Risk - Schedule of Gross Volume of Commodity Derivative Instruments Outstanding (Detail) bbl in Thousands, MMBTU in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2015MMBTUbbl	Dec. 31, 2014MMBTUbbl
Long | Refined Products Contracts
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gross volume, refined products	9,482	10,823
Long | Natural Gas Contracts
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gross volume, natural gas | MMBTU	122,719	131,376
Short | Refined Products Contracts
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gross volume, refined products	12,662	15,434
Short | Natural Gas Contracts
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gross volume, natural gas | MMBTU	74,780	82,796

Equity-Based Compensation - Add

Equity-Based Compensation - Additional Information (Detail) - USD ($) $ in Thousands	Mar. 05, 2015	Jan. 31, 2015	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Annual bonus expense					$ 2,700		$ 4,900
Number of common units issued for settlement of annual bonus expenses					200,775
Unit-based compensation recorded in unitholders' equity					$ 5,231	$ 5,267
Annual Bonus Program
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of units reacquired from recipient					67,141
Grant date fair value					$ 1,700
Restricted and Phantom Unit Award Activity
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unit-based compensation recorded in unitholders' equity			$ 700	$ 2,100	$ 2,100	$ 2,700
Performance Based Phantom Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of units reacquired from recipient					24,605
Grant date fair value					$ 600
Percentage of phantom units granted							200.00%
Estimated fair value of performance-based phantom units	$ 4,500
Weighted average volatility rate	32.90%
Weighted average risk free rate	0.98%
Common stock units issued		74,048
Vested market value		$ 1,800
Unrecognized compensation cost			$ 4,300		$ 4,300
Unrecognized compensation cost, expected recognition period					27 months
Performance Based Phantom Units | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of phantom units granted					0.00%
Performance Based Phantom Units | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of phantom units granted					200.00%

Equity-Based Compensation - Sum

Equity-Based Compensation - Summary of Partnership's Unit Awards Subject to Vesting (Detail)	9 Months Ended
	Sep. 30, 2015$ / sharesshares
Restricted Common Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonvested units, beginning | shares	4,444
Forfeited units | shares	0
Nonvested units, ending | shares	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
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonvested units, beginning | shares	23,685
Forfeited units | shares	0
Vested units | shares	(13,766)
Nonvested units, ending | shares	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
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonvested units, beginning | shares	111,075
Granted units | shares	141,000
Forfeited units | shares	0
Nonvested units, ending | shares	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

Equity-Based Compensation - Sch

Equity-Based Compensation - Schedule of Changes in Partnership's Units (Detail) - shares	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Common Unitholders - Public
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Beginning balance	8,777,922	8,506,666
Ending balance	8,969,914	8,777,922
Common Unitholders - Public | Directors and Employees
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units issued		27,401
Common Unitholders - Public | Employee Bonus Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units issued	133,634
Common Unitholders - Public | Phantom Share Units (PSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units issued	58,358
Common Unitholders - Public | Castle
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units issued in connection with acquisition		243,855
Common Unitholders - Affiliated
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Beginning balance	2,034,378	1,571,970
Ending balance	2,034,378	2,034,378
Common Unitholders - Affiliated | Kildair
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units issued in connection with acquisition		462,408
Subordinated Unitholders - Affiliated
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Beginning balance	10,071,970	10,071,970
Ending balance	10,071,970	10,071,970

Earnings Per Unit - Additional

Earnings Per Unit - Additional Information (Detail) - shares	9 Months Ended
	Sep. 30, 2015	Jun. 30, 2015
Subordinated Units
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Units outstanding prior to IPO	0
Prior to October 30, 2013
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Potentially dilutive units outstanding		0

Earnings Per Unit - Summary of

Earnings Per Unit - Summary of Weighted Average Common Units Outstanding (Detail) - shares	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Earnings Per Share [Abstract]
Weighted average limited partner common units - basic	10,999,848	10,091,388	10,965,400	10,085,058
Dilutive effect of unvested restricted and phantom units	253,547	0	233,728	35,877
Weighted average limited partner common units - dilutive	11,253,395	10,091,388	11,199,128	10,120,935

Earnings Per Unit - Schedule of

Earnings Per Unit - Schedule of Reconciliation and Assumed Allocation of Net Income to Limited Partners' Interest for Computing Net Income Per Unit (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net income (loss)	$ 8,580	$ (5,302)	$ 49,969	$ 57,226	$ 122,814
Income attributable to Kildair (Note 2)	0	(5,416)	0	(2,103)
Net Income (Loss) Allocated to Limited Partners	8,475	(10,718)	49,815	55,123
Distributions declared	10,699	8,959	30,986	25,902
Assumed net income (loss) from operations after distributions	$ (2,119)	$ (19,677)	$ 18,983	$ 29,221
Earnings (loss) per unit - basic	$ 0.40	$ (0.53)	$ 2.37	$ 2.73
Earnings (loss) per unit - diluted	$ 0.39	$ (0.53)	$ 2.32	$ 2.73
Common Unitholders - Affiliated
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net income (loss)	$ 4,424		$ 25,965
Net Income (Loss) Allocated to Limited Partners		$ (5,364)		$ 27,579
Distributions declared	5,533	4,502	16,102	12,984
Assumed net income (loss) from operations after distributions	$ (1,109)	$ (9,866)	$ 9,863	$ 14,595
Earnings (loss) per unit - basic	$ 0.40	$ (0.53)	$ 2.37	$ 2.73
Earnings (loss) per unit - diluted	$ 0.39	$ (0.53)	$ 2.32	$ 2.73
Subordinated Unitholders - Affiliated
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net income (loss)	$ 4,051		$ 23,850
Net Income (Loss) Allocated to Limited Partners		$ (5,354)		$ 27,544
Distributions declared	5,061	4,457	14,730	12,918
Assumed net income (loss) from operations after distributions	$ (1,010)	$ (9,811)	$ 9,120	$ 14,626
Earnings (loss) per unit - basic	$ 0.40	$ (0.53)	$ 2.37	$ 2.73
Earnings (loss) per unit - diluted	$ 0.40	$ (0.53)	$ 2.37	$ 2.73
IDR
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net income (loss)	$ 105		$ 154
Net Income (Loss) Allocated to Limited Partners		$ 0		$ 0
Distributions declared	105	0	154	0
Assumed net income (loss) from operations after distributions	$ 0	$ 0	$ 0	$ 0

Partnership Distributions - Sch

Partnership Distributions - Schedule of Incentive Distribution Amount Exceeds Specified Target Levels that Partnership Distributes (Detail)	9 Months Ended
	Sep. 30, 2015$ / shares
Minimum Quarterly Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Quarterly Distribution per Unit Target Amount	$ 0.4125
First Target Distribution | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Quarterly Distribution per Unit Target Amount	0.4125
First Target Distribution | Maximum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Quarterly Distribution per Unit Target Amount	0.474375
Second Target Distribution | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Quarterly Distribution per Unit Target Amount	0.474375
Second Target Distribution | Maximum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Quarterly Distribution per Unit Target Amount	0.515625
Third Target Distribution | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Quarterly Distribution per Unit Target Amount	0.515625
Third Target Distribution | Maximum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Quarterly Distribution per Unit Target Amount	0.61875
Thereafter | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Quarterly Distribution per Unit Target Amount	$ 0.61875
Unitholders | Minimum Quarterly Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Cash Distributions	100.00%
Unitholders | First Target Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Cash Distributions	100.00%
Unitholders | Second Target Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Cash Distributions	85.00%
Unitholders | Third Target Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Cash Distributions	75.00%
Unitholders | Thereafter
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Cash Distributions	50.00%
Incentive Distribution Rights Holders | Minimum Quarterly Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Cash Distributions	0.00%
Incentive Distribution Rights Holders | First Target Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Cash Distributions	0.00%
Incentive Distribution Rights Holders | Second Target Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Cash Distributions	15.00%
Incentive Distribution Rights Holders | Third Target Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Cash Distributions	25.00%
Incentive Distribution Rights Holders | Thereafter
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Cash Distributions	50.00%

Partnership Distributions - Add

Partnership Distributions - Additional Information (Detail) - $ / shares

Nov. 13, 2015

Oct. 28, 2015

Aug. 14, 2015

Jul. 29, 2015

May. 15, 2015

Apr. 29, 2015

Feb. 13, 2015

Jan. 28, 2015

Sep. 30, 2015

Sep. 30, 2014

Sep. 30, 2015

Sep. 30, 2014

Distribution Made to Limited Partner [Line Items]

Distribution declared per unit

$ 0.4875

$ 0.4725

$ 0.4575

$ 0.5025

$ 0.4425

$ 1.4625

$ 1.2825

Distribution paid

$ 487.5000

$ 0.4725

$ 0.4575

Dividend Declared

Distribution Made to Limited Partner [Line Items]

Cash distribution, declared date

Jan. 28, 2015

Cash distribution, paid date

Feb. 13, 2015

Cash distribution, record date

Feb. 9, 2015

Dividend Declared Two

Distribution Made to Limited Partner [Line Items]

Cash distribution, declared date

Apr. 29, 2015

Cash distribution, paid date

May 15, 2015

Cash distribution, record date

May 11, 2015

Scenario, Forecast

Distribution Made to Limited Partner [Line Items]

Distribution paid

$ 0.5025

Subsequent Event

Distribution Made to Limited Partner [Line Items]

Distribution declared per unit

$ 0.5025