Alon USA Partners (ALDW) 10-K 13 Mar 14 2013 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information Document (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Mar. 01, 2014	Jun. 30, 2013
Entity Information	'	'	'
Entity Registrant Name	'Alon USA Partners, LP	'	'
Entity Central Index Key	'0001556766	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Accelerated Filer	'	'
Document Type	'10-K	'	'
Document Period End Date	31-Dec-13	'	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
Amendment Flag	'false	'	'
Entity Common Stock, Shares Outstanding	'	62,502,467	'
Entity Well-known Seasoned Issuer	'No	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Public Float	'	'	$273,700

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$153,583	$66,001
Accounts and other receivables, net	123,781	104,119
Accounts and other receivables, net - related parties	14,621	14,519
Inventories	49,146	57,034
Prepaid expenses and other current assets	4,642	6,868
Total current assets	345,773	248,541
Property, plant and equipment, net	472,885	483,061
Other assets, net	31,266	31,821
Total assets	849,924	763,423
Current liabilities:	'	'
Accounts payable	280,774	202,121
Accrued liabilities	44,492	42,218
Current portion of long-term debt	2,500	2,500
Total current liabilities	327,766	246,839
Other non-current liabilities	34,894	42,047
Long-term debt	341,822	292,811
Total liabilities	704,482	581,697
Commitments and contingencies (Note 15)	'	'
Partners’ equity:	'	'
General Partner	0	0
Common unitholders - 62,502,467 and 62,500,000 units issued and outstanding at December 31, 2013 and 2012, respectively	145,442	181,726
Total partners’ equity	145,442	181,726
Total liabilities and partners’ equity	$849,924	$763,423

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical)	Dec. 31, 2013	Dec. 31, 2012
Consolidated Balance Sheets (Parentheticals) [Abstract]	'	'
Common units, shares issued	62,502,467	62,500,000
Common units, shares outstanding	62,502,467	62,500,000

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Net sales (1)	$3,430,287	[1]	$3,476,817	[1]	$3,207,969	[1]
Operating costs and expenses:	'		'		'
Cost of sales	3,073,044		2,883,741		2,722,918
Direct operating expenses	110,940		100,908		98,178
Selling, general and administrative expenses	22,276		22,807		15,633
Depreciation and amortization	45,329		46,009		40,448
Total operating costs and expenses	3,251,589		3,053,465		2,877,177
Loss on disposition of assets	-21		0		0
Operating income	178,677		423,352		330,792
Interest expense	-40,474		-22,235		-16,719
Interest expense - related parties	0		-15,691		-17,067
Other income, net	23		8		18
Income before state income tax expense	138,226		385,434		297,024
State income tax expense	2,004		3,536		2,597
Net income	136,222		381,898		294,427
Less: Net income attributable to Predecessor operations	0		344,778		'
Net income attributable to Alon USA Partners, LP	$136,222		$37,120		'
Earnings per limited partner unit	$2.18		$0.59		'
Weighted average common units outstanding (in thousands)	62,502		62,500		'
Cash distribution per limited partner unit	$2.76		$0		'
[1]	Includes sales to related parties of $600,710, $588,828 and $553,253 for the years ended December 31, 2013, 2012 and 2011, respectively.

Consolidated_Statements_of_Ope1

Consolidated Statements of Operations (Parenthetical) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Consolidated Statement of Operations (Parenthetical) [Abstract]	'	'	'
Sales to related parties	$600,710	$588,828	$553,253

Consolidated_Statement_of_Part

Consolidated Statement of Partners' Equity Statement (USD $)	Total	Predecessor	Common Unitholders	General Partner
In Thousands
Total partners' equity at Dec. 31, 2010	$9,664	$9,664	$0	$0
Distributions paid to unitholders	-201,402	-201,402	0	0
Net income attributable to Predecessor operations	294,427	294,427	0	0
Assumption of term loan facility, net of financing costs	0	'	'	'
Total partners' equity at Dec. 31, 2011	102,689	102,689	0	0
Distributions paid to unitholders	-410,106	-410,106	0	0
Net income attributable to Predecessor operations	344,778	344,778	0	0
Proceeds from initial public offering, net of offering costs	167,769	167,769	0	0
Assumption of term loan facility, net of financing costs	-238,687	-238,687	0	0
Conversion of subordinated debt - related parties	178,163	178,163	0	0
Predecessor equity transferred to common unitholders	0	-144,606	144,606	0
Net income attributable to Alon USA Partners, LP	37,120	0	37,120	0
Total partners' equity at Dec. 31, 2012	181,726	0	181,726	0
Distributions paid to unitholders	-172,506	0	-172,506	0
Assumption of term loan facility, net of financing costs	0	'	'	'
Net income attributable to Alon USA Partners, LP	136,222	0	136,222	0
Total partners' equity at Dec. 31, 2013	$145,442	$0	$145,442	$0

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash flows from operating activities:	'	'	'
Net income	$136,222	$381,898	$294,427
Adjustments to reconcile net income to cash provided by operating activities:	'	'	'
Depreciation and amortization	45,329	46,009	40,448
Non-cash interest on subordinated debt - related parties	0	15,691	17,067
Amortization of debt issuance costs	1,990	2,105	1,450
Amortization of original issuance discount	511	61	0
Loss on disposition of assets	21	0	0
Changes in operating assets and liabilities:	'	'	'
Accounts and other receivables, net	-19,662	-3,266	-27,444
Accounts and other receivables, net - related parties	-102	-1,731	-859
Inventories	7,888	-25,296	7,317
Prepaid expenses and other current assets	2,226	-811	-3,579
Other assets, net	-1,634	1,978	-17,601
Accounts payable	53,453	90,802	-63,875
Accrued liabilities	-2,752	14,378	-4,561
Other non-current liabilities	-7,153	7,007	15,785
Net cash provided by operating activities	216,337	528,825	258,575
Cash flows from investing activities:	'	'	'
Capital expenditures	-23,390	-24,490	-12,460
Capital expenditures for turnarounds and catalysts	-6,236	-7,279	-7,085
Net cash used in investing activities	-29,626	-31,769	-19,545
Cash flows from financing activities:	'	'	'
Distributions paid to unitholders	-31,746	0	0
Distributions paid to unitholders - Alon Energy	-140,760	0	0
Net cash payments to Alon Energy	0	-410,106	-201,402
Proceeds from initial public offering, net of offering costs	0	167,769	0
Repayment of subordinated debt - related parties	0	-171,120	0
Revolving credit facility, net	51,000	-151,000	78,000
Payments on long-term debt	-2,500	0	0
Inventory agreement transactions	25,200	0	1,165
Deferred debt issuance costs	-323	-2,543	-1,200
Net cash used in financing activities	-99,129	-567,000	-123,437
Net increase (decrease) in cash and cash equivalents	87,582	-69,944	115,593
Cash and cash equivalents, beginning of period	66,001	135,945	20,352
Cash and cash equivalents, end of period	153,583	66,001	135,945
Supplemental cash flow information:	'	'	'
Cash paid for interest, net of capitalized interest	38,807	19,598	15,775
Cash paid for income tax	2,004	2,597	136
Supplemental disclosure of non-cash activity:	'	'	'
Capital expenditures included in accrued liabilities	5,026	0	0
Conversion of subordinated debt - related parties	0	178,163	0
Assumption of term loan facility, net of financing costs	$0	($238,687)	$0

Description_and_Nature_of_Busi

Description and Nature of Business	12 Months Ended
	Dec. 31, 2013
Description and Nature of Business [Abstract]	'
Nature of Operations	'
	Description and Nature of Business
	As used in this report, the terms “Alon,” the “Partnership,” “we,” “us” or “our” refer to Alon USA Partners, LP, one or more of its consolidated subsidiaries or all of them taken as a whole. References in this report to “Alon Energy” refer collectively to Alon USA Energy, Inc. and any of its subsidiaries, other than Alon USA Partners, LP, its subsidiaries and its general partner.
	Alon is a Delaware limited partnership formed in August 2012 by Alon Energy and its wholly owned subsidiary Alon USA Partners GP, LLC (the “General Partner”). In November 2012, we completed the initial public offering of 11,500,000 common units representing limited partner interests at a price of $16.00 per unit (the “Offering”).
	Our initial net assets were contributed to us by Alon Energy in exchange for 51,000,000 common units, representing an 81.6% interest in the Partnership and 100% non-economic ownership interest in the General Partner. As an entity under common control of Alon Energy, we recorded the net assets that Alon Energy contributed to us concurrently with the completion of the Offering at Alon Energy’s historical basis.
	We are a refiner and marketer of petroleum products operating primarily in the South Central and Southwestern regions of the United States. We own and operate a crude oil refinery in Big Spring, Texas with crude oil throughput capacity of 70,000 barrels per day, or “bpd”, which we refer to as the Big Spring refinery. We refine crude oil into petroleum products, including gasoline, diesel, jet fuel, petrochemicals, petrochemical feedstocks, asphalts and other petroleum products, which we market primarily in West and Central Texas, Oklahoma, New Mexico and Arizona. We refer to our operations in this region as our physically integrated system because it supplies Alon branded and unbranded distributors in this region with motor fuels produced at the Big Spring refinery. We distribute fuel products through a product pipeline and terminal network, which we own or access through leases or long-term throughput agreements. Our physically integrated system includes Alon Energy’s owned and operated retail convenience stores. We operate in a single reportable segment for financial reporting purposes based on how the business is managed.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Basis of Presentation and Significant Accounting Policies [Text Block]	'
	Summary of Significant Accounting Policies
	(a) Basis of Presentation
	The consolidated financial statements and related notes for the periods beginning and following November 27, 2012, include the accounts of the Partnership and its subsidiaries. Additionally, the accompanying financial statements and related notes for periods presented through November 26, 2012 present the combined financial position, results of operations, cash flows and partners’ equity of Alon USA Partners, LP Predecessor (“Predecessor”), our predecessor for accounting purposes, at historical cost. All significant intercompany balances and transactions have been eliminated.
	(b) Use of Estimates
	These consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America (“U.S. GAAP”), which requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
	(c) Revenue Recognition
	Substantially all of our revenues are derived from the sale of refined products. Revenues from sales of refined products are earned and realized upon transfer of title to the customer based on the contractual terms of delivery (including payment terms and prices). Generally, title transfers at the refinery or terminal when the refined product is loaded into the common carrier pipelines, trucks or railcars (free on board origin). In some situations, title transfers at the customer’s destination (free on board destination).
	We occasionally enter into refined product buy/sell arrangements, which involve linked purchases and sales related to refined product sales contracts entered into to address location, quality or grade requirements. These buy/sell transactions are included on a net basis in sales in the consolidated statements of operations and profits are recognized when the exchanged product is sold.
	Revenue from our inventory financing agreement (Note 8) is reported on a gross basis as we are considered a principal in this agreement.
	In the ordinary course of business, logistical and refinery production schedules necessitate the occasional sale of crude oil to third parties. All purchases and sales of crude oil are recorded net in cost of sales in the consolidated statements of operations.
	(d) Cost Classifications
	Cost of sales includes principally crude oil, blending materials, other raw materials and transportation costs. Cost of sales excludes depreciation and amortization, which is presented separately in the consolidated statements of operations.
	Direct operating expenses include costs associated with the actual operations of the refinery, such as energy and utility costs, routine maintenance, labor, insurance and environmental compliance costs. These costs also include actual costs incurred by Alon Energy and allocated to us. All operating costs associated with our crude oil and product pipelines are considered to be transportation costs and are reflected in cost of sales in the consolidated statements of operations.
	Selling, general and administrative expenses primarily include corporate overhead costs and marketing expenses. These costs also include actual costs incurred by Alon Energy and allocated to us.
	Interest expense includes interest expense, letters of credit, financing costs associated with crude oil purchases, financing fees, and amortization of both original issuance discount and deferred debt issuance costs but excludes capitalized interest.
	(e) Cash and Cash Equivalents
	All highly-liquid instruments with a maturity of three months or less at the time of purchase are considered to be cash equivalents. Cash equivalents are stated at cost, which approximates market value.
	(f) Accounts Receivable
	Financial instruments that potentially subject us to concentration of credit risk consist primarily of trade accounts receivables. Credit is extended based on evaluation of the customer’s financial condition and in certain circumstances collateral, such as letters of credit, prepayments or guarantees are required, as management deems appropriate. Reserve for bad debts is based on a combination of current sales and specific identification methods.
	Credit risk is minimized as a result of the ongoing credit assessment of our customers and a lack of concentration in our customer base. Credit losses are charged to allowance for doubtful accounts when deemed uncollectible. Our allowance for doubtful accounts is reflected as a reduction of accounts receivable in the consolidated balance sheets.
	The balance in allowance for doubtful accounts was $277 for each of the years ended December 31, 2013, 2012 and 2011.
	(g) Inventories
	Crude oil, refined products and blendstocks (including inventory consigned to others) are stated at the lower of cost or market. Cost is determined under the last-in, first-out (“LIFO”) valuation method. Cost of crude oil, refined products and blendstock inventories in excess of market value are charged to cost of sales. Such charges are subject to reversal in subsequent periods, not to exceed LIFO cost, if prices recover. Materials and supplies are stated at average cost.
	Crude oil inventory consigned to others represents inventory that was sold to third parties, which we are obligated to repurchase at the end of the respective agreements (Note 8). As a result of this requirement to repurchase the inventory, no revenue was recorded on these transactions and the inventory volumes remain valued under the LIFO method.
	(h) Hedging Activity
	We participate in Alon Energy’s company-wide risk management program. All derivative instruments are recorded in the consolidated balance sheets as either assets or liabilities measured at their fair value. We consider all commodity forwards, futures and option contracts to be part of our risk management strategy. We have elected not to designate these commodity contracts as cash flow hedges for financial accounting purposes. Accordingly, net unrealized gains and losses for changes in the fair value on open commodity derivative contracts are recognized in cost of sales in the consolidated statements of operations.
	The derivative transaction related to the inventory financing agreement has been designated as a fair value hedge of inventory. The gain or loss on the derivative instrument designated and qualifying as a fair value hedge, as well as the offsetting gain or loss on the hedged item attributable to the hedged risk, is recognized in earnings in the same period.
	(i) Property, Plant and Equipment
	The carrying value of property, plant and equipment includes the fair value of the asset retirement obligation and has been reflected in the consolidated balance sheets at cost, net of accumulated depreciation.
	Property, plant and equipment, net of salvage value, are depreciated using the straight-line method at rates based on the estimated useful lives for the assets or groups of assets, beginning in the first month of operation following acquisition or completion. We capitalize interest costs associated with major construction projects based on the effective interest rate on aggregate borrowings.
	Expenditures for major replacements and additions are capitalized. Expenditures for routine repairs and maintenance costs are charged to direct operating expense as incurred. The applicable costs and accumulated depreciation of assets that are sold, retired, or otherwise disposed of are removed from the accounts and the resulting gain or loss is recognized as a gain or loss on disposition of assets in the consolidated statements of operations.
	(j) Impairment of Long-Lived Assets and Assets To Be Disposed Of
	We review long-lived assets and certain identifiable intangible assets for impairment whenever events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying value of an asset to future net cash flows expected to be generated by the asset. If the carrying value of an asset exceeds its expected future cash flows, an impairment loss is recognized based on the excess of the carrying value of the impaired asset over its fair value. These future cash flows and fair values are estimates based on management’s judgment and assumptions. Assets to be disposed of are reported at the lower of the carrying amount or fair value less costs of disposition.
	(k) Asset Retirement Obligations
	The accounting standards established for asset retirement obligations require companies to recognize the liability for the fair value of a legal obligation to perform asset retirement activities that are conditional on a future event, if the amount can be reasonably estimated.
	We have asset retirement obligations with respect to our refinery due to various legal obligations to clean and/or dispose of these assets at the time they are retired. However, the majority of these assets can be used for extended and indeterminate periods of time provided that they are properly maintained and/or upgraded. It is our practice and intent to continue to maintain these assets and make improvements based on technological advances. When a date or range of dates can reasonably be estimated for the retirement of these assets or any component of these assets, we will estimate the cost of performing the retirement activities and record a liability for the fair value of that cost using established present value techniques.
	(l) Turnarounds and Chemical Catalysts Costs
	We record the cost of planned major refinery maintenance, referred to as turnarounds, and chemical catalyst used in the refinery process units, which are typically replaced in conjunction with planned turnarounds, in “Other assets” in the consolidated balance sheets. Turnaround and catalyst costs are deferred and amortized on a straight-line basis beginning the month after the completion of the turnaround and ending immediately prior to the next scheduled turnaround. The amortization of deferred turnaround and chemical catalyst costs are presented in depreciation and amortization in the consolidated statements of operations.
	(m) Earnings per Limited Partner Unit
	Earnings per unit applicable to limited partners is computed by dividing limited partners’ interest in net income by the weighted average number of outstanding common units.
	(n) Income Taxes
	We are a partnership for U.S. federal income tax purposes and thus our income is taxed directly to our owners. As a result, we do not incur U.S. federal income taxes.
	Alon Energy is subject to the Texas franchise tax and our operations are included in the consolidated Texas franchise tax return of Alon Energy. For financial reporting purposes, Texas franchise tax is calculated as if a separate return was filed.
	Net income for financial statement purposes may differ significantly from taxable income reportable to unitholders as a result of differences between the tax and financial reporting bases of assets and liabilities and the taxable income allocation requirements under the partnership agreement.
	(o) Environmental Expenditures
	Environmental expenditures are expensed or capitalized depending on their future economic benefit. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefit are expensed. Liabilities for expenditures of a non-capital nature are recorded when environmental assessment and/or remediation is probable, and the costs can be reasonably estimated. Environmental liabilities represent the estimated costs to investigate and remediate contamination at our properties. This estimate is based on internal and third-party assessments of the extent of the contaminations, the selected remediation technology and review of applicable environmental regulations.
	Costs of future expenditures for environmental remediation obligations are not discounted to their present value unless payments are fixed or reliably determinable. Recoveries of environmental remediation costs from other parties are recorded as assets when the receipt is deemed probable (Note 15). Estimates are updated to reflect changes in factual information, available technology or applicable laws and regulations.
	Substantially all amounts accrued are expected to be paid out over the next 15 years. The level of future expenditures for environmental remediation obligations is impossible to determine with any degree of reliability.
	(p) Commitments and Contingencies
	Liabilities for loss contingencies arising from claims, assessments, litigation, fines and penalties and other sources are recorded when it is probable that a liability has been incurred and the amount of the assessment and/or remediation can be reasonably estimated. Legal costs incurred in connection with loss contingencies are expensed as incurred.

Earnings_Per_Unit

Earnings Per Unit	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Earnings Per Unit	'
	Earnings Per Unit
	The following is a summary of our net income for the period after the completion of the Offering through December 31, 2012:
		Alon USA Partners, LP
		November 27, 2012 through December 31, 2012
	Net sales	$	324,237
	Operating costs and expenses:
	Cost of sales	264,960
	Direct operating expenses	10,687
	Selling, general and administrative expenses	2,153
	Depreciation and amortization	4,632
	Total operating costs and expenses	282,432
	Operating income	41,805
	Interest expense	(4,335		)
	Interest expense - related parties	—
	Other income (loss), net	(2		)
	Income before state income tax expense	37,468
	State income tax expense	348
	Net income attributable to Alon USA Partners, LP	$	37,120
	Weighted average common units outstanding (in thousands)	62,500
	Earnings per limited partner unit	$	0.59
	Earnings per limited partner unit is computed by dividing limited partners’ interest in net income by the weighted average number of outstanding common units during the period. Our net income is allocated entirely to the limited partners as the General Partner has a non-economic interest in the Partnership.
	Earnings per limited partner unit is only calculated for the Partnership subsequent to the Offering, as there was no outstanding public equity prior to November 27, 2012. Payments made to our unitholders are determined in relation to actual distributions declared and are not based on the net income allocations used in the calculation of earnings per limited partner unit.

Fair_Value

Fair Value	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Disclosures [Text Block]	'
	Fair Value
	We determine fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. We classify financial assets and financial liabilities into the following fair value hierarchy:
	•	Level 1 -     valued based on quoted prices in active markets for identical assets and liabilities;
	•	Level 2 -     valued based on quoted prices for similar assets and liabilities in active markets, and inputs other than quoted prices that are observable for the asset or liability; and
	•	Level 3 -     valued based on unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities.
	As required, we utilize valuation techniques that maximize the use of observable inputs (levels 1 and 2) and minimize the use of unobservable inputs (level 3) within the fair value hierarchy. Alon generally applies the “market approach” to determine fair value. This method uses pricing and other information generated by market transactions for identical or comparable assets and liabilities. Assets and liabilities are classified within the fair value hierarchy based on the lowest level (least observable) input that is significant to the measurement in its entirety.
	The carrying amounts of our cash and cash equivalents, receivables, payables and accrued liabilities approximate fair value due to the short-term maturities of these assets and liabilities. The reported amounts of long-term debt approximate fair value. Derivative instruments are carried at fair value, which are based on quoted market prices. Derivative instruments and the Renewable Identification Numbers (“RINs”) obligation are our only assets and liabilities measured at fair value on a recurring basis.
	The RINs obligation represents the period-end deficit for the purchase of RINs necessary to satisfy the requirement to blend biofuels into the products we have produced. Our RINs obligation is based on the RINs deficit and the price of those RINs as of the balance sheet date. The RINs obligation is categorized as Level 2 of the fair value hierarchy and is measured at fair value using the market approach based on quoted prices from an independent pricing service.
	The following table sets forth the assets and liabilities measured at fair value on a recurring basis, by input level, in the consolidated balance sheets as of December 31, 2013 and 2012:
		Level 1		Level 2		Level 3		Total
	As of December 31, 2013
	Assets:
	Commodity contracts (futures and forwards)	$	22	$	—	$	—	$	22
	Liabilities:
	Fair value hedge	—		2,304		—		2,304
	RINs obligation	—		334		—		334
	As of December 31, 2012
	Assets:
	Commodity contracts (futures and forwards)	$	2,365	$	—	$	—	$	2,365
	Liabilities:
	Fair value hedge	—		327		—		327

Derivative_Financial_Instrumen

Derivative Financial Instruments	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Instruments and Hedging Activities Disclosure [Text Block]	'
	Derivative Financial Instruments
	Mark to Market
	Commodity Derivatives. We selectively utilize crude oil and refined product commodity derivative contracts to reduce the risk associated with potential price changes on committed obligations. We do not speculate using derivative instruments. Credit risk on our derivative instruments is mitigated by transacting with counterparties meeting established collateral and credit criteria.
	Fair Value Hedge
	Fair value hedges are used to hedge price volatility of certain refining inventories and firm commitments to purchase inventories. The gain or loss on a derivative instrument designated and qualifying as a fair value hedge, as well as the offsetting gain or loss on the hedged item attributable to the hedged risk, is recognized in earnings in the same period.
	As of December 31, 2013, we have accounted for certain commodity contracts as fair value hedges with contract purchase volumes of 234 thousand barrels of crude oil with remaining contract terms through May 2019.
	The following table presents the effect of derivative instruments on the consolidated statements of financial position:
		As of December 31, 2013
		Asset Derivatives						Liability Derivatives
		Balance Sheet						Balance Sheet
		Location		Fair Value				Location		Fair Value
	Derivatives not designated as hedging instruments:
	Commodity contracts (futures and forwards)	Accounts receivable		$	303			Accrued liabilities		$	(281	)
	Total derivatives not designated as hedging instruments			$	303					$	(281	)
	Derivatives designated as hedging instruments:
	Fair value hedge			$	—			Other non-current liabilities		$	(2,304	)
	Total derivatives designated as hedging instruments			—						(2,304		)
	Total derivatives			$	303					$	(2,585	)
		As of December 31, 2012
		Asset Derivatives						Liability Derivatives
		Balance Sheet						Balance Sheet
		Location		Fair Value				Location		Fair Value
	Derivatives not designated as hedging instruments:
	Commodity contracts (futures and forwards)	Accounts receivable		$	2,365					$	—
	Total derivatives not designated as hedging instruments			$	2,365					$	—
	Derivatives designated as hedging instruments:
	Fair value hedge			$	—			Other non-current liabilities		$	(327	)
	Total derivatives designated as hedging instruments			—						(327		)
	Total derivatives			$	2,365					$	(327	)
	The following tables present the effect of derivative instruments on the consolidated statements of operations:
	Derivatives in fair value hedging relationships:
				Gain (Loss) Recognized in Income
				Year Ended December 31,
		Location		2013				2012					2011
													Predecessor
	Fair value hedge	Cost of sales		$	(1,977	)		$	(327	)			$	—
	Total derivatives			$	(1,977	)		$	(327	)			$	—
	Derivatives not designated as hedging instruments:
				Gain (Loss) Recognized in Income
				Year Ended December 31,
		Location		2013				2012					2011
													Predecessor
	Commodity contracts (futures & forwards)	Cost of sales		$	4,516			$	7,038				$	(1,486	)
	Commodity contracts (swaps) (1)	Cost of sales		—				(13,951		)			—
	Total derivatives			$	4,516			$	(6,913	)			$	(1,486	)
	___________
	-1	Related to derivatives with a related party.
	Offsetting Assets and Liabilities
	Our derivative financial instruments are subject to master netting arrangements to manage counterparty credit risk associated with derivatives and we offset the fair value amounts recorded for derivative instruments to the extent possible under these agreements on our consolidated balance sheets.
	The following table presents offsetting information regarding our derivatives by type of transaction as of December 31, 2013 and 2012:
		Gross Amounts of Recognized Assets (Liabilities)				Gross Amounts offset in the Statement of Financial Position				Net Amounts of Assets (Liabilities) Presented in the Statement of Financial Position				Gross Amounts Not offset in the Statement of Financial Position					Net Amount
														Financial Instruments			Cash Collateral Pledged
	As of December 31, 2013
	Commodity Derivative Assets:
	Futures & forwards	$	514			$	(211	)		$	303			$	(281	)	$	—	$	22
	Commodity Derivative Liabilities:
	Futures & forwards	(492		)		211				(281		)		281			—		—
	Fair value hedge	(2,304		)		—				(2,304		)		—			—		(2,304		)
	As of December 31, 2012
	Commodity Derivative Assets:
	Futures & forwards	$	4,306			$	(1,941	)		$	2,365			$	—		$	—	$	2,365
	Commodity Derivative Liabilities:
	Futures & forwards	(1,941		)		1,941				—				—			—		—
Fair value hedge	(327		)		—				(327		)		—			—		(327		)
Compliance Program Market Risk
We are obligated by government regulations to blend a certain percentage of biofuels into the products we produce that are consumed in the U.S. We purchase biofuels from third parties and blend those biofuels into our products, and each gallon of biofuel purchased includes a RIN. To the degree we are unable to blend biofuels at the required percentage, a RINs deficit is generated and we must acquire that number of RINs by the annual reporting deadline in order to remain in compliance with applicable regulations.
We are exposed to market risk related to the volatility in the price of credits needed to comply with these governmental and regulatory programs. We manage this risk by purchasing biofuel credits when prices are deemed favorable utilizing fixed price purchase contracts. Some of these contracts are derivative instruments; however, we elect the normal purchase and sale exception and do not record these contracts at their fair values.
The cost of meeting our obligations under these compliance programs was $14,917 for the year ended December 31, 2013. These amounts are reflected in cost of sales. We were not subject to the Renewable Fuel Standards 2 requirements for the years ended December 31, 2012 and 2011.

Significant_Customers

Significant Customers	12 Months Ended
	Dec. 31, 2013
Significant Customers [Abstract]	'
Schedule of Revenue by Major Customers by Reporting Segments [Table Text Block]	'
	Significant Customers
	For the year ended December 31, 2013, we had two third party customers and related party customers which account for approximately 40% of net sales. Individually, third party customers accounted for 12% and 10% of net sales and related party customers accounted for 18% of net sales for the year ended December 31, 2013.
	For the year ended December 31, 2012, we had two third party customers and related party customers which account for approximately 37% of net sales. Individually, third party customers accounted for 12% and 10% of net sales and related party customers accounted for 15% of net sales for the year ended December 31, 2012.
	For the year ended December 31, 2011, we had two third party customers and related party customers which account for approximately 41% of net sales. Individually, third party customers accounted for 15% and 12% of net sales and related party customers accounted for 14% of net sales for the year ended December 31, 2011.
	At December 31, 2013 and 2012, 27% and 24%, respectively, of total third party and related party accounts and other receivables, net were from significant customers discussed above.

Inventories

Inventories	12 Months Ended
	Dec. 31, 2013
Inventory Disclosure [Abstract]	'
Inventory Disclosure [Text Block]	'
	Inventories
	Carrying value of inventories consisted of the following:
		As of December 31,
		2013		2012
	Crude oil, refined products and blendstocks	$	25,246	$	24,661
	Crude oil inventory consigned to others (Note 8)	14,214		23,086
	Materials and supplies	9,686		9,287
	Total inventories	$	49,146	$	57,034
	Reductions of inventory volumes during 2013 and 2011 resulted in a liquidation of LIFO inventory layers. The liquidation increased cost of sales by $1,091 during 2013 and decreased cost of sales by $42,702 during 2011. There were no liquidations of LIFO inventory layers during 2012.
	Market values of crude oil, refined products and blendstock inventories exceeded LIFO costs by $21,216 and $12,477 at December 31, 2013 and 2012, respectively.

Inventory_Financing_Agreement

Inventory Financing Agreement	12 Months Ended
	Dec. 31, 2013
Inventory Financing Agreement [Abstract]	'
Inventory Financing Agreements [Text Block]	'
	Inventory Financing Agreement
	The Partnership has entered into a Supply and Offtake Agreement and other associated agreements (together the “Supply and Offtake Agreement”), with J. Aron & Company (“J. Aron”). Pursuant to the Supply and Offtake Agreement, (i) J. Aron agreed to sell to us, and we agreed to buy from J. Aron, at market prices, crude oil for processing at the Big Spring refinery and (ii) we agreed to sell to J. Aron, and J. Aron agreed to buy from us, at market prices, certain refined products produced at the Big Spring refinery.
	The Supply and Offtake Agreement also provided for the sale, at market prices, of our crude oil and certain refined product inventories to J. Aron, the lease to J. Aron of crude oil and refined product storage facilities, and to identify prospective purchasers of refined products on J. Aron’s behalf. The Supply and Offtake Agreement was amended in February 2013 and has an initial term that expires in May 2019. J. Aron may elect to terminate the Supply and Offtake Agreement prior to the expiration of the initial term beginning in May 2016 and upon each anniversary thereof, on six months prior notice. We may elect to terminate in May 2018 on six months prior notice.
	Following the expiration or termination of the Supply and Offtake Agreement, we are obligated to purchase the crude oil and refined product inventories then owned by J. Aron and located at the Big Spring refinery.
	At December 31, 2013 and 2012, we had current receivables of $11,640 and current payables of $16,038, respectively, to J. Aron for sales and purchases, non-current liabilities related to the original financing of $24,482 and $31,842, respectively, and a consignment inventory receivable representing a deposit paid to J. Aron of $6,290 and $6,290, respectively.
	Additionally, we had current payables of $263 at December 31, 2013 and current receivables of $4,136 at December 31, 2012 for forward commitments related to month-end consignment inventory target levels differing from projected levels and the associated pricing with these inventory level differences.

Property_Plant_and_Equipment_N

Property, Plant, and Equipment, Net	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment, Net [Abstract]	'
Property, Plant and Equipment Disclosure [Text Block]	'
	Property, Plant and Equipment, Net
	Property, plant and equipment, net consisted of the following:
		As of December 31,
		2013			2012
	Refining facilities	$	677,085		$	652,910
	Accumulated depreciation	(204,200		)	(169,849		)
	Property, plant and equipment, net	$	472,885		$	483,061
	The useful lives of depreciable assets used to determine depreciation expense were 3 to 20 years, with an average life of 18 years.
	Capitalized interest for the years ended December 31, 2013, 2012 and 2011 was $1,083, $1,013 and $713, respectively. Depreciation expense for the years ended December 31, 2013, 2012 and 2011 was $34,392, $33,221 and $31,133, respectively.

Other_Assets_Net

Other Assets, Net	12 Months Ended
	Dec. 31, 2013
Other Assets Disclosure [Abstract]	'
Other Assets Disclosure [Text Block]	'
	Other Assets, Net
	Other assets, net consisted of the following:
		As of December 31,
		2013		2012
	Deferred turnaround and chemical catalyst cost	$	7,774	$	7,622
	Deferred debt issuance costs	7,782		9,449
	Receivable from supply agreement	6,290		6,290
	Other	9,420		8,460
	Total other assets	$	31,266	$	31,821
	Debt issuance costs are amortized over the term of the related debt using the effective interest method. Amortization of debt issuance costs was $1,990, $2,105 and $1,450 for the years ended December 31, 2013, 2012 and 2011, respectively, and is recorded as interest expense in the consolidated statements of operations.

Accrued_Liabilities_and_Other_

Accrued Liabilities and Other Non-Current Liabilities	12 Months Ended
	Dec. 31, 2013
Other Liabilities Disclosure [Abstract]	'
Accrued Liabilities and Other Non-Current Liabilities [Text Block]	'
	Accrued Liabilities and Other Non-Current Liabilities
	Accrued liabilities and other non-current liabilities consisted of the following:
		As of December 31,
		2013		2012
	Accrued Liabilities:
	Taxes other than income taxes, primarily excise taxes	$	30,354	$	28,112
	Accrued finance charges	1,365		1,927
	Environmental accrual (Note 15)	1,307		831
	Other	11,466		11,348
	Total accrued liabilities	$	44,492	$	42,218
	Other Non-Current Liabilities:
	Consignment inventory obligation	$	24,482	$	31,842
	Environmental accrual (Note 15)	5,640		5,516
	Asset retirement obligations	1,973		1,890
	Other	2,799		2,799
	Total other non-current liabilities	$	34,894	$	42,047
	The following table summarizes the activity relating to the asset retirement obligations for the years ended December 31, 2013 and 2012:
		As of December 31,
		2013		2012
	Balance at beginning of year	$	1,890	$	1,789
	Accretion expense	83		79
	Additions	—		22
	Balance at end of year	$	1,973	$	1,890

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Tax Disclosure [Text Block]	'
	Income Taxes
	We are a partnership for U.S. federal income tax purposes and thus our income is taxed directly to our owners. As a result, we do not incur U.S. federal income taxes.
	We are unable to readily determine the net difference in the bases of our assets and liabilities for financial and tax reporting purposes because individual unitholders have different investment bases depending upon the timing and price of acquisition of their partnership units.

Indebtedness

Indebtedness	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Debt Disclosure [Text Block]	'
	Indebtedness
	Debt consisted of the following:
		As of December 31,
		2013			2012
	Term loan credit facility	$	244,322		$	246,311
	Revolving credit facility	100,000			49,000
	Total debt	344,322			295,311
	Less: Current portion	2,500			2,500
	Total long-term debt	$	341,822		$	292,811
	Partnership Term Loan Credit Facility. In connection with the Offering, we were assigned $250,000 of the aggregate principal balance of the Alon USA Energy term loan (the “Partnership Term Loan”). The Partnership Term Loan requires principal payments of $2,500 per annum paid in quarterly installments until maturity in November 2018.
	The Partnership Term Loan bears interest at a rate equal to the sum of (i) the Eurodollar rate (with a floor of 1.25% per annum) plus (ii) a margin of 8.00% per annum for a per annum rate of 9.25%, based on current Eurodollar market rates at December 31, 2013.
	The Partnership Term Loan is secured by a first priority lien on all of our fixed assets and other specified property, as well as on our general partner interest held by the General Partner, and a second lien on our cash, accounts receivables, inventories and related assets.
	The Partnership Term Loan contains restrictive covenants, such as restrictions on liens, mergers, consolidations, sales of assets, additional indebtedness, different businesses, certain lease obligations and certain restricted payments. The Partnership Term Loan does not contain any maintenance financial covenants.
	At December 31, 2013 and 2012, the Partnership Term Loan had an outstanding balance (net of unamortized discount) of $244,322 and $246,311, respectively.
	Revolving Credit Facility. We have a $240,000 revolving credit facility (the “Revolving Credit Facility”) that will mature in March 2016. The Revolving Credit Facility can be used both for borrowings and the issuance of letters of credit subject to a limit of the lesser of the facility amount or the borrowing base amount under the facility.
	Borrowings under the Revolving Credit Facility bear interest at the Eurodollar rate plus 3.50% per annum subject to an overall minimum interest rate of 4.00%.
	The Revolving Credit Facility is secured by a first lien on our cash, accounts receivables, inventories and related assets and a second lien on our fixed assets.
	The Revolving Credit Facility contains certain restrictive covenants including maintenance financial covenants. At December 31, 2013, we were in compliance with these maintenance financial covenants.
	Borrowings of $100,000 and $49,000 were outstanding under the Revolving Credit Facility at December 31, 2013 and 2012, respectively. At December 31, 2013 and 2012, outstanding letters of credit under the Revolving Credit Facility were $109,772 and $58,759, respectively.
	The aggregate scheduled maturities of long-term debt for each of the five years subsequent to December 31, 2013 are as follows:
	2014	$	2,500
	2015	2,500
	2016	102,500
	2017	2,500
	2018	234,322
	Total	$	344,322
	Interest and financing expense included the following:
		Year Ended December 31,
		2013			2012			2011
								Predecessor
	Interest expense on third party debt	$	25,815		$	9,454		$	5,889
	Letters of credit and finance charges	13,241			11,628			10,093
	Amortization of debt issuance costs	1,990			2,105			1,450
	Amortization of original issuance discount	511			61			—
	Capitalized interest	(1,083		)	(1,013		)	(713		)
	Total interest expense	$	40,474		$	22,235		$	16,719

Partners_Equity

Partners' Equity	12 Months Ended
	Dec. 31, 2013
Partners' Capital Notes [Abstract]	'
Partners' Capital Notes Disclosure [Text Block]	'
	Partners' Equity (unit values in dollars)
	We had 62,502,467 common public units outstanding as of December 31, 2013. Alon Energy owned 51,000,000 of our common units as of December 31, 2013 which constitutes 81.6% ownership interest in us.
	Cash Distributions. We have adopted a policy pursuant to which we will distribute all of the available cash generated each quarter, as defined in the partnership agreement and subject to the approval of the board of directors of the General Partner. The per unit amount of available cash to be distributed each quarter, if any, will be distributed within 60 days following the end of such quarter.
	During the year ended December 31, 2013, we paid cash distributions of $172,506, or $2.76 per unit. As the Partnership was formed in November 2012, cash distributions were not paid during the years ended December 31, 2012 and 2011. During the years ended December 31, 2012 and 2011, our Predecessor made net cash payments to Alon Energy of $410,106 and $201,402, respectively.
	Restricted Units. We, through our general partner, have adopted the Alon USA Partners, LP 2012 Long-Term Incentive Plan (the “LTIP”) for the employees, consultants and the directors of the Partnership, the General Partner and its affiliates who perform services for us. The LTIP provides grants of options, unit appreciation rights, restricted units, phantom units, unit awards, substitute awards, other unit-based awards, cash awards, performance awards and distribution equivalent rights. The maximum aggregate number of common units that may be issued under the LTIP shall not exceed 3,125,000 units.
	During the year ended December 31, 2013, we granted awards totaling 2,467 restricted common units at an average grant date price of $20.27
	per unit to non-employee directors of the General Partner. The restricted common units granted to the non-employee directors vest over a period of three years, assuming continued service at vesting.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies Disclosure [Text Block]	'
	Commitments and Contingencies
	(a) Leases
	We have long-term lease commitments for land, office facilities and related equipment and various equipment and facilities used in the storage and transportation of refined products. In most cases we expect that in the normal course of business, our leases will be renewed or replaced by other leases. We have commitments under long-term operating leases for certain buildings, land, equipment, and pipelines expiring at various dates over the next ten years. Certain long-term operating leases relating to buildings, land and pipelines include options to renew for additional periods. At December 31, 2013, minimum lease payments on operating leases were as follows:
	Year ending December 31:
	2014	$	9,068
	2015	8,744
	2016	8,583
	2017	8,464
	2018	4,928
	2019 and thereafter	262
	Total	$	40,049
	Total rental expense was $11,396, $11,735 and $12,190 for the years ended December 31, 2013, 2012 and 2011, respectively. Contingent rentals and subleases were not significant.
	(b) Commitments
	In the normal course of business, we have entered into long-term commitments to purchase, at market prices, utilities such as natural gas, electricity and water for use by our refinery, terminals and pipelines. We are also party to various refined product and crude oil supply and exchange agreements. These agreements are typically short-term in nature or provide terms for cancellation.
	We have a pipelines and terminals agreement with Holly Energy Partners (“HEP”) through February 2020 with three additional five year renewal terms exercisable at our sole option. Pursuant to the pipelines and terminals agreement, we have committed to transport and store minimum volumes of refined products in these pipelines and terminals. The tariff rates applicable to the transportation of refined products on the pipelines are variable, with a base fee which is reduced for volumes exceeding defined volumetric targets. The agreement provides for the reduction of the minimum volume requirement under certain circumstances. The service fees for the storage of refined products in the terminals are initially set at rates competitive in the marketplace.
	We have a throughput and deficiency agreement with Sunoco Pipeline, LP (“Sunoco”) that gives us the option to transport crude oil through the Amdel Pipeline either (1) westbound from the Nederland Terminal to the Big Spring refinery, or (2) eastbound from the Big Spring refinery to the Nederland Terminal for further barge transportation to Alon Energy’s Krotz Springs, Louisiana refinery. Our minimum throughput commitment is 15,645 bpd. The agreement is for five years from the operational date of September 2012 with an option to extend the agreement by four additional thirty-month periods.
	We have an arrangement with Centurion through June 2021. This arrangement gives us transportation pipeline capacity to ship crude oil from Midland to the Big Spring refinery using Centurion’s approximately forty-mile long pipeline system from Midland to Roberts Junction and our three-mile pipeline from Roberts Junction to the Big Spring refinery which we lease to Centurion. Our minimum throughput commitment is 25,000 bpd.
	(c) Contingencies
	The Partnership is involved in various legal actions arising in the ordinary course of business. We believe the ultimate disposition of these matters will not have a material effect on our financial position, results of operations or liquidity.
	(d) Environmental
	We are subject to loss contingencies pursuant to federal, state, and local environmental laws and regulations. These laws and regulations govern the discharge of materials into the environment and may require us to incur future obligations to investigate the effects of the release or disposal of certain petroleum, chemical, and mineral substances at various sites; to remediate or restore these sites and to compensate others for damage to property and natural resources. These contingent obligations relate to sites owned by the Partnership and our past or present operations. We are currently participating in environmental investigations, assessments and cleanups pertaining to the refinery, pipelines and terminals. We may be involved in additional future environmental investigations, assessments and cleanups. The magnitude of future costs are unknown and will depend on factors such as the nature and contamination at many sites, the timing, extent and method of the remedial actions which may be required, and the determination of our liability in proportion to other responsible parties.
	We have an environmental agreement with HEP pursuant to which we agreed to indemnify HEP against costs and liabilities incurred by HEP to the extent resulting from the existence of environmental conditions at the pipelines or terminals or from violations of environmental laws with respect to the pipelines and terminals occurring prior to February 28, 2005. Our environmental indemnification obligations under the environmental agreement expire after February 28, 2015. In addition, our indemnity obligations are subject to HEP first incurring $100 of damages as a result of pre-existing environmental conditions or violations. Our environmental indemnity obligations are further limited to an aggregate indemnification amount of $20,000, including any amounts that we have paid to HEP with respect to indemnification for breaches of our representations and warranties under a contribution agreement. With respect to any remediation required for environmental conditions existing prior to February 28, 2005, we have the option under the environmental agreement to perform such remediation ourself in lieu of indemnifying HEP for their costs of performing such remediation. Pursuant to this option, we continue to perform the ongoing remediation at the Abilene and Wichita Falls terminals. Any remediation required under the terms of the environmental agreement is limited to the standards under the applicable environmental laws as in effect at February 28, 2005.
	We have an environmental agreement with Sunoco pursuant to which we agreed to indemnify Sunoco against costs and liabilities incurred by Sunoco to the extent resulting from the existence of environmental conditions at the pipelines or from violations of environmental laws with respect to the pipelines occurring prior to March 1, 2006. With respect to any remediation required for environmental conditions existing prior to March 1, 2006, we have the option to perform such remediation ourself in lieu of indemnifying Sunoco for their costs of performing such remediation.
	We have accrued environmental remediation obligations of $6,947 ($1,307 current liability and $5,640 non-current liability at December 31, 2013 and $6,347 ($831 current liability and $5,516 non-current liability) at December 31, 2012. Environmental liabilities with payments that are fixed or reliably determinable have been discounted to present value at a rate of 3.38%.
	The table below summarizes our environmental liability accruals:
		As of December 31,
		2013		2012
	Discounted environmental liabilities	$	5,815	$	5,717
	Undiscounted environmental liabilities	1,132		630
	Total accrued environmental liabilities	$	6,947	$	6,347
	As of December 31, 2013, the estimated future payments of environmental obligations for which discounts have been applied are as follows:
	Year ending December 31,
	2014	$	783
	2015	783
	2016	673
	2017	603
	2018	523
	2019 and thereafter	3,825
	Discounted environmental liabilities, gross	7,190
	Less: Discount applied	1,375
	Discounted environmental liabilities	$	5,815

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions Disclosure [Text Block]	'
	Related Party Transactions
	Sales and Receivables
	Sales to related parties include motor fuels and asphalt sold to other Alon Energy subsidiaries at prices substantially determined by reference to market commodity pricing information. These sales are included in net sales in the consolidated statements of operations. Accounts receivable from related parties includes sales of motor fuels and are shown separately on the consolidated balance sheets.
	Costs Allocated from Alon Energy
	(a)	Corporate Overhead Allocations
	The Partnership is a subsidiary of Alon Energy and is operated as a component of the integrated operations of Alon Energy. As such, the executive officers of Alon Energy, who are employed by another subsidiary of Alon Energy, also serve as executive officers of the General Partner and Alon Energy’s other subsidiaries. Alon Energy performs general corporate and administrative services and functions for us and their other subsidiaries, which include accounting, treasury, cash management, tax, information technology, insurance administration and claims processing, legal, environmental, risk management, audit, payroll and employee benefit processing, and internal audit services. Alon Energy allocates the expenses actually incurred in performing these services to the Partnership based primarily on the estimated amount of time the individuals performing such services devote to our business and affairs relative to the amount of time they devote to the business and affairs of Alon Energy’s other subsidiaries. The management of Alon Energy and the General Partner consider these allocations to be reasonable. We record the amount of such allocations as selling, general and administrative expenses within our consolidated statements of operations. Our allocation for selling, general and administrative expenses was $11,731, $10,952 and $10,336 for the years ended December 31, 2013, 2012 and 2011, respectively.
	(b)	Labor Costs
	We have no employees, and as a result, actual employee expense costs for Alon Energy employees working in our operations have been allocated and recorded as payroll expense and included in direct operating expenses within our consolidated statements of operations. Our share of Alon Energy’s employee expense costs included in direct operating expenses was $24,401, $23,064 and $21,598 for the years ended December 31, 2013, 2012 and 2011, respectively.
	(c)	Insurance Costs
	Insurance costs related to the Big Spring refinery and wholesale marketing operations are allocated to us by Alon Energy based on estimated insurance premiums on a stand-alone basis relative to Alon Energy’s total insurance premium. Our allocation for insurance costs included in direct operating expenses was $10,494, $9,992 and $8,476 for the years ended December 31, 2013, 2012 and 2011, respectively.
	Subordinated Debt
	Our Predecessor had subordinated debt notes with Alon Energy and certain of its subsidiaries. These notes were to mature in January 2018. The notes had no prepayment penalty or any covenant requirements. The interest rates charged on these notes ranged from 6% to 10%. Interest expense pertaining to the subordinated notes is disclosed separately on the consolidated statements of operations. In conjunction with the Offering, we repaid $171,120 of the subordinated debt notes and Alon Energy contributed to us the remaining outstanding subordinated debt note balance of $178,163. As a result of this prepayment and contribution, there was no remaining subordinated debt balance at December 31, 2013 and 2012.
	Agreements with Alon Energy
	We have entered into the following agreements with Alon Energy in connection with the closing of the Offering:
	(a)	Omnibus Agreement
	Under the terms of the omnibus agreement between the Partnership and Alon Energy, we have the right of first refusal if Alon Energy or any of its controlled affiliates has the opportunity to acquire a controlling interest in any refinery and related crude oil and refined product logistic assets, including non-retail transportation terminal sales, and that operate in Arizona, Arkansas, Colorado, Kansas, New Mexico, Oklahoma or Texas. In addition, pursuant to the terms of the omnibus agreement, we will have a 60-day exclusive right of negotiation if Alon Energy or any of its controlled affiliates decide to attempt to sell any refinery and related crude oil and refined product logistic assets, including non-retail transportation terminal sales, that operate in Arizona, Arkansas, Colorado, Kansas, New Mexico, Oklahoma or Texas.
	(b)	Services Agreement
	The Services Agreement among the Partnership, the General Partner and Alon Energy addresses certain aspects of our relationship with the General Partner and Alon Energy, including the provision by Alon Energy or its service subsidiary to us of certain general and administrative services and our agreement to reimburse Alon Energy for such services; and the provision by Alon Energy or its service subsidiary to us of such employees as may be necessary to operate and manage our business, and our agreement to reimburse Alon Energy for the expenses associated with such employees.
	Pursuant to the Services Agreement, we have agreed to reimburse Alon Energy or its service subsidiary for (i) all reasonable direct and indirect costs and expenses incurred by it in connection with the performance of these services and (ii) all other reasonable expenses allocable to the Partnership or the General Partner or otherwise incurred by Alon Energy in connection with the operation of our business.
	(c)	Tax Sharing Agreement
	Under the terms of the Tax Sharing Agreement by and among the Partnership and Alon Energy, we must reimburse Alon Energy for our share of state and local income and other taxes borne by Alon Energy due to of our results being included in a combined or consolidated tax return filed by Alon Energy.
	(d)	Fuel Supply Agreement
	Pursuant to the terms of the 20-year Fuel Supply Agreement between the Partnership and Southwest Convenience Stores, LLC (“Southwest”), a subsidiary of Alon Energy, we supply substantially all of the motor fuel requirements of Alon Energy’s retail convenience stores. The volume of motor fuels sold under the Fuel Supply Agreement is determined monthly based upon Southwest’s estimated requirements. Southwest purchases such motor fuels at a price equal to the price per unit in effect at the time of delivery less applicable terminal discounts plus all applicable freight, taxes, pipeline tariff and delivery place differentials.
	The Fuel Supply Agreement additionally provides for (i) Southwest’s mandatory participation in our credit card payment network, (ii) Southwest’s use of the “Alon” name and related marks in connection with the use of the credit card payment network and the resale of the motor fuels purchased pursuant to the Fuel Supply Agreement and (iii) marketing services for the benefit of Southwest (at an additional cost).
	(e)	Asphalt Supply Agreement
	We also entered into a 20-year Asphalt Supply Agreement with Paramount Petroleum Corporation (“Paramount”), a subsidiary of Alon Energy, under which Paramount purchases all of the asphalt that we produce. The volume of asphalt sold pursuant to the Asphalt Supply Agreement is based upon actual production, but we are required to provide good faith non-binding forecasts of its monthly production estimates for each contract year.
	Products are sold under the Asphalt Supply Agreement at prices equal to the three day average price for such product, determined by reference to the value derived from the pricing formula set forth in the Asphalt Supply Agreement for such product on the day of delivery or lifting and for the two business days prior to the date of delivery or lifting. Products with a contract term exceeding one year require the parties to meet annually to reexamine the price for such product.
	Distributions
	During the year ended December 31, 2013, we paid cash distributions of $172,506, or $2.76 per unit. The total cash distribution paid to Alon Energy was $140,760. As the Partnership was formed in November 2012, cash distributions were not paid during the years ended December 31, 2012 and 2011. During the years ended December 31, 2012 and 2011, our Predecessor made net cash payments to Alon Energy of $410,106 and $201,402, respectively.

Quarterly_Information_unaudite

Quarterly Information (unaudited)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Quarterly Financial Information [Text Block]	'
	Quarterly Information (unaudited)
	Selected financial data by quarter is set forth in the table below:
		Quarters
		First		Second		Third			Fourth		Full Year
	2013
	Net sales	$	804,167	$	865,694	$	881,902		$	878,524	$	3,430,287
	Operating income (loss)	103,813		54,750		(3,932		)	24,046		178,677
	Net income (loss) available to common unitholders	93,525		45,321		(16,120		)	13,496		136,222
	Earnings (loss) per limited partner unit	$	1.5	$	0.73	$	(0.26	)	$	0.22	$	2.18
	Weighted average shares outstanding	62,501		62,502		62,502			62,502		62,502
	2012 (1)
	Net sales	$	884,274	$	823,769	$	943,148		$	825,626	$	3,476,817
	Operating income	57,899		111,093		130,241			124,119		423,352
	Net income available to common unitholders	48,076		100,223		120,367			113,232		381,898
	Earnings per limited partner unit (2)	$	—	$	—	$	—		$	0.59	$	0.59
	Weighted average shares outstanding	—		—		—			62,500		62,500
	_______________________
	-1	The information presented includes the results of operations of our Predecessor for periods prior to the completion of the Offering.
	-2	Earnings per limited partner unit is not presented for periods prior to the completion of the Offering as there was no common equity or potential common equity publicly traded during those periods.

Subsequent_Event

Subsequent Event	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events [Text Block]	'
	Subsequent Event
	Partnership Distribution
	On February 13, 2014 the Board of the General Partner approved a cash distribution to our common unitholders of $0.18 per common unit. The cash distribution was paid on March 3, 2014 to unitholders of record at the close of business on February 24, 2014.

Significant_Accounting_Policie

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Consolidation, Policy [Policy Text Block]	'
	Basis of Presentation
	The consolidated financial statements and related notes for the periods beginning and following November 27, 2012, include the accounts of the Partnership and its subsidiaries. Additionally, the accompanying financial statements and related notes for periods presented through November 26, 2012 present the combined financial position, results of operations, cash flows and partners’ equity of Alon USA Partners, LP Predecessor (“Predecessor”), our predecessor for accounting purposes, at historical cost. All significant intercompany balances and transactions have been eliminated.
Use of Estimates, Policy [Policy Text Block]	'
	Use of Estimates
	These consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America (“U.S. GAAP”), which requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Revenue Recognition, Policy [Policy Text Block]	'
	Revenue Recognition
	Substantially all of our revenues are derived from the sale of refined products. Revenues from sales of refined products are earned and realized upon transfer of title to the customer based on the contractual terms of delivery (including payment terms and prices). Generally, title transfers at the refinery or terminal when the refined product is loaded into the common carrier pipelines, trucks or railcars (free on board origin). In some situations, title transfers at the customer’s destination (free on board destination).
	We occasionally enter into refined product buy/sell arrangements, which involve linked purchases and sales related to refined product sales contracts entered into to address location, quality or grade requirements. These buy/sell transactions are included on a net basis in sales in the consolidated statements of operations and profits are recognized when the exchanged product is sold.
	Revenue from our inventory financing agreement (Note 8) is reported on a gross basis as we are considered a principal in this agreement.
	In the ordinary course of business, logistical and refinery production schedules necessitate the occasional sale of crude oil to third parties. All purchases and sales of crude oil are recorded net in cost of sales in the consolidated statements of operations.
Cost Classifications, Policy [Policy Text Block]	'
	Cost Classifications
	Cost of sales includes principally crude oil, blending materials, other raw materials and transportation costs. Cost of sales excludes depreciation and amortization, which is presented separately in the consolidated statements of operations.
	Direct operating expenses include costs associated with the actual operations of the refinery, such as energy and utility costs, routine maintenance, labor, insurance and environmental compliance costs. These costs also include actual costs incurred by Alon Energy and allocated to us. All operating costs associated with our crude oil and product pipelines are considered to be transportation costs and are reflected in cost of sales in the consolidated statements of operations.
	Selling, general and administrative expenses primarily include corporate overhead costs and marketing expenses. These costs also include actual costs incurred by Alon Energy and allocated to us.
	Interest expense includes interest expense, letters of credit, financing costs associated with crude oil purchases, financing fees, and amortization of both original issuance discount and deferred debt issuance costs but excludes capitalized interest.
Cash and Cash Equivalents, Policy [Policy Text Block]	'
	Cash and Cash Equivalents
	All highly-liquid instruments with a maturity of three months or less at the time of purchase are considered to be cash equivalents. Cash equivalents are stated at cost, which approximates market value.
Trade and Other Accounts Receivable, Policy [Policy Text Block]	'
	Accounts Receivable
	Financial instruments that potentially subject us to concentration of credit risk consist primarily of trade accounts receivables. Credit is extended based on evaluation of the customer’s financial condition and in certain circumstances collateral, such as letters of credit, prepayments or guarantees are required, as management deems appropriate. Reserve for bad debts is based on a combination of current sales and specific identification methods.
	Credit risk is minimized as a result of the ongoing credit assessment of our customers and a lack of concentration in our customer base. Credit losses are charged to allowance for doubtful accounts when deemed uncollectible. Our allowance for doubtful accounts is reflected as a reduction of accounts receivable in the consolidated balance sheets.
	The balance in allowance for doubtful accounts was $277 for each of the years ended December 31, 2013, 2012 and 2011
Inventory, Policy [Policy Text Block]	'
	Inventories
	Crude oil, refined products and blendstocks (including inventory consigned to others) are stated at the lower of cost or market. Cost is determined under the last-in, first-out (“LIFO”) valuation method. Cost of crude oil, refined products and blendstock inventories in excess of market value are charged to cost of sales. Such charges are subject to reversal in subsequent periods, not to exceed LIFO cost, if prices recover. Materials and supplies are stated at average cost.
	Crude oil inventory consigned to others represents inventory that was sold to third parties, which we are obligated to repurchase at the end of the respective agreements (Note 8). As a result of this requirement to repurchase the inventory, no revenue was recorded on these transactions and the inventory volumes remain valued under the LIFO method.
Derivatives, Policy [Policy Text Block]	'
	Hedging Activity
	We participate in Alon Energy’s company-wide risk management program. All derivative instruments are recorded in the consolidated balance sheets as either assets or liabilities measured at their fair value. We consider all commodity forwards, futures and option contracts to be part of our risk management strategy. We have elected not to designate these commodity contracts as cash flow hedges for financial accounting purposes. Accordingly, net unrealized gains and losses for changes in the fair value on open commodity derivative contracts are recognized in cost of sales in the consolidated statements of operations.
	The derivative transaction related to the inventory financing agreement has been designated as a fair value hedge of inventory. The gain or loss on the derivative instrument designated and qualifying as a fair value hedge, as well as the offsetting gain or loss on the hedged item attributable to the hedged risk, is recognized in earnings in the same period.
Property, Plant and Equipment, Policy [Policy Text Block]	'
	Property, Plant and Equipment
	The carrying value of property, plant and equipment includes the fair value of the asset retirement obligation and has been reflected in the consolidated balance sheets at cost, net of accumulated depreciation.
	Property, plant and equipment, net of salvage value, are depreciated using the straight-line method at rates based on the estimated useful lives for the assets or groups of assets, beginning in the first month of operation following acquisition or completion. We capitalize interest costs associated with major construction projects based on the effective interest rate on aggregate borrowings.
	Expenditures for major replacements and additions are capitalized. Expenditures for routine repairs and maintenance costs are charged to direct operating expense as incurred. The applicable costs and accumulated depreciation of assets that are sold, retired, or otherwise disposed of are removed from the accounts and the resulting gain or loss is recognized as a gain or loss on disposition of assets in the consolidated statements of operations.
Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block]	'
	Impairment of Long-Lived Assets and Assets To Be Disposed Of
	We review long-lived assets and certain identifiable intangible assets for impairment whenever events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying value of an asset to future net cash flows expected to be generated by the asset. If the carrying value of an asset exceeds its expected future cash flows, an impairment loss is recognized based on the excess of the carrying value of the impaired asset over its fair value. These future cash flows and fair values are estimates based on management’s judgment and assumptions. Assets to be disposed of are reported at the lower of the carrying amount or fair value less costs of disposition.
Asset Retirement Obligations, Policy [Policy Text Block]	'
	Asset Retirement Obligations
	The accounting standards established for asset retirement obligations require companies to recognize the liability for the fair value of a legal obligation to perform asset retirement activities that are conditional on a future event, if the amount can be reasonably estimated.
	We have asset retirement obligations with respect to our refinery due to various legal obligations to clean and/or dispose of these assets at the time they are retired. However, the majority of these assets can be used for extended and indeterminate periods of time provided that they are properly maintained and/or upgraded. It is our practice and intent to continue to maintain these assets and make improvements based on technological advances. When a date or range of dates can reasonably be estimated for the retirement of these assets or any component of these assets, we will estimate the cost of performing the retirement activities and record a liability for the fair value of that cost using established present value techniques.
Property, Plant and Equipment, Planned Major Maintenance Activities, Policy [Policy Text Block]	'
	Turnarounds and Chemical Catalysts Costs
	We record the cost of planned major refinery maintenance, referred to as turnarounds, and chemical catalyst used in the refinery process units, which are typically replaced in conjunction with planned turnarounds, in “Other assets” in the consolidated balance sheets. Turnaround and catalyst costs are deferred and amortized on a straight-line basis beginning the month after the completion of the turnaround and ending immediately prior to the next scheduled turnaround. The amortization of deferred turnaround and chemical catalyst costs are presented in depreciation and amortization in the consolidated statements of operations.
Earnings Per Unit, Policy [Policy Text Block]	'
	per Limited Partner Unit
	Earnings per unit applicable to limited partners is computed by dividing limited partners’ interest in net income by the weighted average number of outstanding common units.
Income Tax, Policy [Policy Text Block]	'
	Income Taxes
	We are a partnership for U.S. federal income tax purposes and thus our income is taxed directly to our owners. As a result, we do not incur U.S. federal income taxes.
	Alon Energy is subject to the Texas franchise tax and our operations are included in the consolidated Texas franchise tax return of Alon Energy. For financial reporting purposes, Texas franchise tax is calculated as if a separate return was filed.
	Net income for financial statement purposes may differ significantly from taxable income reportable to unitholders as a result of differences between the tax and financial reporting bases of assets and liabilities and the taxable income allocation requirements under the partnership agreement.
Environmental Costs, Policy [Policy Text Block]	'
	Environmental Expenditures
	Environmental expenditures are expensed or capitalized depending on their future economic benefit. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefit are expensed. Liabilities for expenditures of a non-capital nature are recorded when environmental assessment and/or remediation is probable, and the costs can be reasonably estimated. Environmental liabilities represent the estimated costs to investigate and remediate contamination at our properties. This estimate is based on internal and third-party assessments of the extent of the contaminations, the selected remediation technology and review of applicable environmental regulations.
	Costs of future expenditures for environmental remediation obligations are not discounted to their present value unless payments are fixed or reliably determinable. Recoveries of environmental remediation costs from other parties are recorded as assets when the receipt is deemed probable (Note 15). Estimates are updated to reflect changes in factual information, available technology or applicable laws and regulations.
	Substantially all amounts accrued are expected to be paid out over the next 15 years. The level of future expenditures for environmental remediation obligations is impossible to determine with any degree of reliability.
Commitments and Contingencies, Policy [Policy Text Block]	'
	Commitments and Contingencies
	Liabilities for loss contingencies arising from claims, assessments, litigation, fines and penalties and other sources are recorded when it is probable that a liability has been incurred and the amount of the assessment and/or remediation can be reasonably estimated. Legal costs incurred in connection with loss contingencies are expensed as incurred.

Earnings_Per_Unit_Tables

Earnings Per Unit (Tables)	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]	'
	The following is a summary of our net income for the period after the completion of the Offering through December 31, 2012:
		Alon USA Partners, LP
		November 27, 2012 through December 31, 2012
	Net sales	$	324,237
	Operating costs and expenses:
	Cost of sales	264,960
	Direct operating expenses	10,687
	Selling, general and administrative expenses	2,153
	Depreciation and amortization	4,632
	Total operating costs and expenses	282,432
	Operating income	41,805
	Interest expense	(4,335		)
	Interest expense - related parties	—
	Other income (loss), net	(2		)
	Income before state income tax expense	37,468
	State income tax expense	348
	Net income attributable to Alon USA Partners, LP	$	37,120
	Weighted average common units outstanding (in thousands)	62,500
	Earnings per limited partner unit	$	0.59

Fair_Value_Tables

Fair Value (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	'
	The following table sets forth the assets and liabilities measured at fair value on a recurring basis, by input level, in the consolidated balance sheets as of December 31, 2013 and 2012:
		Level 1		Level 2		Level 3		Total
	As of December 31, 2013
	Assets:
	Commodity contracts (futures and forwards)	$	22	$	—	$	—	$	22
	Liabilities:
	Fair value hedge	—		2,304		—		2,304
	RINs obligation	—		334		—		334
	As of December 31, 2012
	Assets:
	Commodity contracts (futures and forwards)	$	2,365	$	—	$	—	$	2,365
	Liabilities:
	Fair value hedge	—		327		—		327

Derivative_Financial_Instrumen1

Derivative Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]	'
	The following table presents the effect of derivative instruments on the consolidated statements of financial position:
		As of December 31, 2013
		Asset Derivatives						Liability Derivatives
		Balance Sheet						Balance Sheet
		Location		Fair Value				Location		Fair Value
	Derivatives not designated as hedging instruments:
	Commodity contracts (futures and forwards)	Accounts receivable		$	303			Accrued liabilities		$	(281	)
	Total derivatives not designated as hedging instruments			$	303					$	(281	)
	Derivatives designated as hedging instruments:
	Fair value hedge			$	—			Other non-current liabilities		$	(2,304	)
	Total derivatives designated as hedging instruments			—						(2,304		)
	Total derivatives			$	303					$	(2,585	)
		As of December 31, 2012
		Asset Derivatives						Liability Derivatives
		Balance Sheet						Balance Sheet
		Location		Fair Value				Location		Fair Value
	Derivatives not designated as hedging instruments:
	Commodity contracts (futures and forwards)	Accounts receivable		$	2,365					$	—
	Total derivatives not designated as hedging instruments			$	2,365					$	—
	Derivatives designated as hedging instruments:
	Fair value hedge			$	—			Other non-current liabilities		$	(327	)
	Total derivatives designated as hedging instruments			—						(327		)
	Total derivatives			$	2,365					$	(327	)
Schedule of Fair Value Hedging Instruments, Statements of Financial Performance and Financial Position, Location [Table Text Block]	'
	Derivatives in fair value hedging relationships:
				Gain (Loss) Recognized in Income
				Year Ended December 31,
		Location		2013				2012					2011
													Predecessor
	Fair value hedge	Cost of sales		$	(1,977	)		$	(327	)			$	—
	Total derivatives			$	(1,977	)		$	(327	)			$	—
Derivative Instruments, Gain (Loss) [Table Text Block]	'
	Derivatives not designated as hedging instruments:
				Gain (Loss) Recognized in Income
				Year Ended December 31,
		Location		2013				2012					2011
													Predecessor
	Commodity contracts (futures & forwards)	Cost of sales		$	4,516			$	7,038				$	(1,486	)
	Commodity contracts (swaps) (1)	Cost of sales		—				(13,951		)			—
	Total derivatives			$	4,516			$	(6,913	)			$	(1,486	)
	___________
	-1	Related to derivatives with a related party.
Summary of offsetting derivative instruments by type [Table Text Block]	'
	The following table presents offsetting information regarding our derivatives by type of transaction as of December 31, 2013 and 2012:
		Gross Amounts of Recognized Assets (Liabilities)				Gross Amounts offset in the Statement of Financial Position				Net Amounts of Assets (Liabilities) Presented in the Statement of Financial Position				Gross Amounts Not offset in the Statement of Financial Position					Net Amount
														Financial Instruments			Cash Collateral Pledged
	As of December 31, 2013
	Commodity Derivative Assets:
	Futures & forwards	$	514			$	(211	)		$	303			$	(281	)	$	—	$	22
	Commodity Derivative Liabilities:
	Futures & forwards	(492		)		211				(281		)		281			—		—
	Fair value hedge	(2,304		)		—				(2,304		)		—			—		(2,304		)
	As of December 31, 2012
	Commodity Derivative Assets:
	Futures & forwards	$	4,306			$	(1,941	)		$	2,365			$	—		$	—	$	2,365
	Commodity Derivative Liabilities:
	Futures & forwards	(1,941		)		1,941				—				—			—		—
	Fair value hedge	(327		)		—				(327		)		—			—		(327		)

Inventories_Tables

Inventories (Tables)	12 Months Ended
	Dec. 31, 2013
Inventory Disclosure [Abstract]	'
Schedule of Inventory, Current [Table Text Block]	'
	Carrying value of inventories consisted of the following:
		As of December 31,
		2013		2012
	Crude oil, refined products and blendstocks	$	25,246	$	24,661
	Crude oil inventory consigned to others (Note 8)	14,214		23,086
	Materials and supplies	9,686		9,287
	Total inventories	$	49,146	$	57,034

Property_Plant_and_Equipment_N1

Property, Plant, and Equipment, Net (Tables)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment, Net [Abstract]	'
Property, Plant and Equipment [Table Text Block]	'
	Property, plant and equipment, net consisted of the following:
		As of December 31,
		2013			2012
	Refining facilities	$	677,085		$	652,910
	Accumulated depreciation	(204,200		)	(169,849		)
	Property, plant and equipment, net	$	472,885		$	483,061

Other_Assets_Net_Tables

Other Assets, Net (Tables)	12 Months Ended
	Dec. 31, 2013
Other Assets Disclosure [Abstract]	'
Schedule of Other Assets [Table Text Block]	'
	Other assets, net consisted of the following:
		As of December 31,
		2013		2012
	Deferred turnaround and chemical catalyst cost	$	7,774	$	7,622
	Deferred debt issuance costs	7,782		9,449
	Receivable from supply agreement	6,290		6,290
	Other	9,420		8,460
	Total other assets	$	31,266	$	31,821

Accrued_Liabilities_and_Other_1

Accrued Liabilities and Other Non-Current Liabilities (Tables)	12 Months Ended
	Dec. 31, 2013
Accrued Liabilities and Other Liabilities [Abstract]	'
Schedule of Accrued Liabilities [Table Text Block]	'
	Accrued liabilities and other non-current liabilities consisted of the following:
		As of December 31,
		2013		2012
	Accrued Liabilities:
	Taxes other than income taxes, primarily excise taxes	$	30,354	$	28,112
	Accrued finance charges	1,365		1,927
	Environmental accrual (Note 15)	1,307		831
	Other	11,466		11,348
	Total accrued liabilities	$	44,492	$	42,218
	Other Non-Current Liabilities:
	Consignment inventory obligation	$	24,482	$	31,842
	Environmental accrual (Note 15)	5,640		5,516
	Asset retirement obligations	1,973		1,890
	Other	2,799		2,799
	Total other non-current liabilities	$	34,894	$	42,047
Schedule of Change in Asset Retirement Obligation [Table Text Block]	'
	The following table summarizes the activity relating to the asset retirement obligations for the years ended December 31, 2013 and 2012:
		As of December 31,
		2013		2012
	Balance at beginning of year	$	1,890	$	1,789
	Accretion expense	83		79
	Additions	—		22
	Balance at end of year	$	1,973	$	1,890

Indebtedness_Tables

Indebtedness (Tables)	12 Months Ended
	Dec. 31, 2013
Schedule of Interest Expense [Abstract]	'
Schedule of Long-term Debt Instruments [Table Text Block]	'
	Debt consisted of the following:
		As of December 31,
		2013			2012
	Term loan credit facility	$	244,322		$	246,311
	Revolving credit facility	100,000			49,000
	Total debt	344,322			295,311
	Less: Current portion	2,500			2,500
	Total long-term debt	$	341,822		$	292,811
Schedule of Maturities of Long-term Debt [Table Text Block]	'
	The aggregate scheduled maturities of long-term debt for each of the five years subsequent to December 31, 2013 are as follows:
	2014	$	2,500
	2015	2,500
	2016	102,500
	2017	2,500
	2018	234,322
	Total	$	344,322
Schedule of Debt [Table Text Block]	'
	Interest and financing expense included the following:
		Year Ended December 31,
		2013			2012			2011
								Predecessor
	Interest expense on third party debt	$	25,815		$	9,454		$	5,889
	Letters of credit and finance charges	13,241			11,628			10,093
	Amortization of debt issuance costs	1,990			2,105			1,450
	Amortization of original issuance discount	511			61			—
	Capitalized interest	(1,083		)	(1,013		)	(713		)
	Total interest expense	$	40,474		$	22,235		$	16,719

Commitments_and_Contingencies_

Commitments and Contingencies Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]	'
	At December 31, 2013, minimum lease payments on operating leases were as follows:
	Year ending December 31:
	2014	$	9,068
	2015	8,744
	2016	8,583
	2017	8,464
	2018	4,928
	2019 and thereafter	262
	Total	$	40,049
Schedule of Accrued Environmental Obligations [Table Text Block]	'
	The table below summarizes our environmental liability accruals:
		As of December 31,
		2013		2012
	Discounted environmental liabilities	$	5,815	$	5,717
	Undiscounted environmental liabilities	1,132		630
	Total accrued environmental liabilities	$	6,947	$	6,347
Schedule of Estimated Undiscounted Cash Flows for Discounted Environmental Remediation Liabilities in Future Periods [Table Text Block]	'
	As of December 31, 2013, the estimated future payments of environmental obligations for which discounts have been applied are as follows:
	Year ending December 31,
	2014	$	783
	2015	783
	2016	673
	2017	603
	2018	523
	2019 and thereafter	3,825
	Discounted environmental liabilities, gross	7,190
	Less: Discount applied	1,375
	Discounted environmental liabilities	$	5,815

Quarterly_Information_unaudite1

Quarterly Information (unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Schedule of Quarterly Financial Information [Table Text Block]	'
	Selected financial data by quarter is set forth in the table below:
		Quarters
		First		Second		Third			Fourth		Full Year
	2013
	Net sales	$	804,167	$	865,694	$	881,902		$	878,524	$	3,430,287
	Operating income (loss)	103,813		54,750		(3,932		)	24,046		178,677
	Net income (loss) available to common unitholders	93,525		45,321		(16,120		)	13,496		136,222
	Earnings (loss) per limited partner unit	$	1.5	$	0.73	$	(0.26	)	$	0.22	$	2.18
	Weighted average shares outstanding	62,501		62,502		62,502			62,502		62,502
	2012 (1)
	Net sales	$	884,274	$	823,769	$	943,148		$	825,626	$	3,476,817
	Operating income	57,899		111,093		130,241			124,119		423,352
	Net income available to common unitholders	48,076		100,223		120,367			113,232		381,898
	Earnings per limited partner unit (2)	$	—	$	—	$	—		$	0.59	$	0.59
	Weighted average shares outstanding	—		—		—			62,500		62,500
	_______________________
	-1	The information presented includes the results of operations of our Predecessor for periods prior to the completion of the Offering.
	-2	Earnings per limited partner unit is not presented for periods prior to the completion of the Offering as there was no common equity or potential common equity publicly traded during those periods.

Description_and_Nature_of_Busi1

Description and Nature of Business (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Nov. 26, 2012	Nov. 26, 2012	Dec. 31, 2013
			Partner Type of Partners' Capital, Affiliated	Partner Type of Partners' Capital, Affiliated	Partner Type of Partners' Capital, Affiliated	IPO [Member]	Maximum [Member]
Limited Partners' Capital Account	'	'	'	'	'	'	'
Partners' Capital Account, Units, Sold in Public Offering	'	'	'	'	'	11,500,000	'
Sale of stock, price per share	'	'	'	'	'	$16	'
Common units, shares outstanding	62,502,467	62,500,000	51,000,000	'	51,000,000	'	'
Ownership Percentage held by Parent	81.60%	'	'	81.60%	'	'	'
Throughput, Average	'	'	'	'	'	'	70,000

Summary_of_Significant_Account1

Summary of Significant Accounting Policies Allowance for Doubtful Accounts (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Thousands, unless otherwise specified
Receivables [Abstract]	'	'	'
Allowance for Doubtful Accounts Receivable, Current	$277	$277	$277

Earnings_Per_Unit_Details

Earnings Per Unit (Details) (USD $)

3 Months Ended

12 Months Ended

1 Months Ended

In Thousands, except Per Share data, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Alon USA Partners, LP [Member]

Net sales (1)

$878,524

$881,902

$865,694

$804,167

$825,626

$943,148

$823,769

$884,274

$3,430,287

[1]

$3,476,817

[1]

$3,207,969

[1]

$324,237

Operating costs and expenses:

'

'

'

'

'

'

'

'

'

'

'

'

Cost of sales

'

'

'

'

'

'

'

'

3,073,044

2,883,741

2,722,918

264,960

Direct operating expenses

'

'

'

'

'

'

'

'

110,940

100,908

98,178

10,687

Selling, general and administrative expenses

'

'

'

'

'

'

'

'

22,276

22,807

15,633

2,153

Depreciation and amortization

'

'

'

'

'

'

'

'

45,329

46,009

40,448

4,632

Total operating costs and expenses

'

'

'

'

'

'

'

'

3,251,589

3,053,465

2,877,177

282,432

Operating income

24,046

-3,932

54,750

103,813

124,119

130,241

111,093

57,899

178,677

423,352

330,792

41,805

Interest expense

'

'

'

'

'

'

'

'

-25,815

-9,454

-5,889

-4,335

Interest expense - related parties

'

'

'

'

'

'

'

'

0

-15,691

-17,067

0

Other income (loss), net

'

'

'

'

'

'

'

'

23

8

18

-2

Income before state income tax expense

'

'

'

'

'

'

'

'

138,226

385,434

297,024

37,468

State income tax expense

'

'

'

'

'

'

'

'

2,004

3,536

2,597

348

Net income attributable to Alon USA Partners, LP

'

'

'

'

'

'

'

'

$136,222

$37,120

'

$37,120

Weighted average common units outstanding (in thousands)

'

'

'

'

'

'

'

'

'

'

'

62,500

Earnings per limited partner unit

$0.22

($0.26)

$0.73

$1.50

$0.59

[2]

'

'

'

$2.18

$0.59

'

$0.59

[1]

Includes sales to related parties of $600,710, $588,828 and $553,253 for the years ended December 31, 2013, 2012 and 2011, respectively.

[2]

Earnings per limited partner unit is not presented for periods prior to the completion of the Offering as there was no common equity or potential common equity publicly traded during those periods.

Fair_Value_Details

Fair Value (Details) (Fair Value, Measurements, Recurring, USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Liabilities:	'	'
RINs obligation	$334	'
Commodity contracts (futures and forwards)	'	'
Assets:	'	'
Commodity contracts (futures and forwards)	22	2,365
Fair value hedges	'	'
Liabilities:	'	'
Fair value hedge	2,304	327
Level 1	'	'
Liabilities:	'	'
RINs obligation	0	'
Level 1 | Commodity contracts (futures and forwards)	'	'
Assets:	'	'
Commodity contracts (futures and forwards)	22	2,365
Level 1 | Fair value hedges	'	'
Liabilities:	'	'
Fair value hedge	0	0
Level 2	'	'
Liabilities:	'	'
RINs obligation	334	'
Level 2 | Commodity contracts (futures and forwards)	'	'
Assets:	'	'
Commodity contracts (futures and forwards)	0	0
Level 2 | Fair value hedges	'	'
Liabilities:	'	'
Fair value hedge	2,304	327
Level 3	'	'
Liabilities:	'	'
RINs obligation	0	'
Level 3 | Commodity contracts (futures and forwards)	'	'
Assets:	'	'
Commodity contracts (futures and forwards)	0	0
Level 3 | Fair value hedges	'	'
Liabilities:	'	'
Fair value hedge	$0	$0

Schedule_of_Derivative_Instrum

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$303	$2,365
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	-281	0
Derivative Instruments in Hedges, Assets, at Fair Value	0	0
Derivative Instruments and Hedges, Assets	303	2,365
Derivative Instruments in Hedges, Liabilities, at Fair Value	-2,304	-327
Derivative Instruments and Hedges, Liabilities	-2,585	-327
Commodity contracts (futures and forwards) | Accounts Receivable	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	303	2,365
Commodity contracts (futures and forwards) | Accrued Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	-281	0
Commodity Contract [Member] | Accounts Receivable	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair Value Hedge Assets	0	'
Commodity Contract [Member] | Other Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair Value Hedge Assets	'	0
Commodity Contract [Member] | Other Noncurrent Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair Value Hedge Liabilities	($2,304)	($327)

Schedule_of_Fair_Value_Hedging

Schedule of Fair Value Hedging Instruments (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Gain (Loss) on Fair Value Hedges Recognized in Earnings	($1,977)	($327)	$0
Commodity Contract [Member] | Cost of Sales [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Gain (Loss) on Fair Value Hedges Recognized in Earnings	($1,977)	($327)	$0

Schedule_of_Derivative_Instrum1

Schedule of Derivative Instruments, Gain (Loss) in Statements of Financial Performance (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$4,516	($6,913)	($1,486)
Commodity contracts (futures and forwards) | Cost of Sales [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	4,516	7,038	-1,486
Swap [Member] | Cost of Sales [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$0	($13,951)	$0

Schedule_of_Offsetting_Derivat

Schedule of Offsetting Derivative Instruments by Type (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Commodity contracts (futures and forwards)	'	'
Schedule of Offsetting Derivative Instruments by Type [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	$514	$4,306
Derivative Asset, Fair Value, Gross Liability	-211	-1,941
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	303	2,365
Derivative Asset, Not Subject to Master Netting Arrangement	-281	0
Derivative, Collateral, Obligation to Return Cash	0	0
Derivative Asset, Fair Value, Amount Offset Against Collateral	22	2,365
Derivative Liability, Fair Value, Gross Liability	-492	-1,941
Derivative Liability, Fair Value, Gross Asset	211	1,941
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	-281	0
Derivative Liability, Not Subject to Master Netting Arrangement	281	0
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability, Fair Value, Amount Offset Against Collateral	0	0
Commodity Contract [Member]	'	'
Schedule of Offsetting Derivative Instruments by Type [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	-2,304	-327
Derivative Liability, Fair Value, Gross Asset	0	0
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	-2,304	-327
Derivative Liability, Not Subject to Master Netting Arrangement	0	0
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability, Fair Value, Amount Offset Against Collateral	($2,304)	($327)

Derivative_Financial_Instrumen2

Derivative Financial Instruments Textuals (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
	barrels
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	234,057
Compliance Program Costs	$14,917

Significant_Customers_Details

Significant Customers (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Sales	'	'	'
Major Customer	'	'	'
Concentration Risk, Percentage	40.00%	37.00%	41.00%
Accounts Receivable	'	'	'
Major Customer	'	'	'
Concentration Risk, Percentage	27.00%	24.00%	'
Third Party Customer A | Sales	'	'	'
Major Customer	'	'	'
Concentration Risk, Percentage	12.00%	12.00%	15.00%
Third Party Customer B | Sales	'	'	'
Major Customer	'	'	'
Concentration Risk, Percentage	10.00%	10.00%	12.00%
Related Party | Sales	'	'	'
Major Customer	'	'	'
Concentration Risk, Percentage	18.00%	15.00%	14.00%

Schedule_of_Inventory_Details

Schedule of Inventory (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Inventory Disclosure [Abstract]	'	'
Crude oil, refined products and blendstocks	$25,246	$24,661
Crude oil inventory consigned to others (Note 8)	14,214	23,086
Materials and supplies	9,686	9,287
Total inventories	$49,146	$57,034

Inventories_Textuals_Details

Inventories Textuals (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2011	Dec. 31, 2012
Inventory Disclosure [Abstract]	'	'	'
Effect of LIFO Inventory Liquidation on Income	$1,091	($42,702)	'
Excess of Replacement or Current Costs over Stated LIFO Value	$21,216	'	$12,477

Inventory_Financing_Agreement_

Inventory Financing Agreement (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Accounts payable	($280,774)	($202,121)
Recorded Unconditional Purchase Obligation	24,482	31,842
Receivable from supply agreement	6,290	6,290
J.Aron [Member]	'	'
Receivables, Net, Current	11,640	'
Accounts payable	'	-16,038
Receivable from supply agreement	6,290	6,290
Consigned inventory [Member] | Commodity contracts (futures and forwards)	'	'
Derivative liability	263	'
Derivative assets	'	$4,136

Property_Plant_and_Equipment_N2

Property, Plant, and Equipment, Net (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Property, Plant and Equipment [Line Items]	'	'
Refining facilities	$677,085	$652,910
Accumulated depreciation	-204,200	-169,849
Property, plant and equipment, net	$472,885	$483,061

Property_Plant_and_Equipment_N3

Property, Plant, and Equipment, Net Textuals (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Property, Plant and Equipment [Abstract]	'	'	'
Interest Costs Capitalized	($1,083)	($1,013)	($713)
Depreciation	$34,392	$33,221	$31,133

Other_Assets_Net_Details

Other Assets, Net (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Other Assets, Net:	'	'	'
Deferred turnaround and chemical catalyst cost	$7,774	$7,622	'
Deferred debt issuance costs	7,782	9,449	'
Receivable from supply agreement	6,290	6,290	'
Other	9,420	8,460	'
Total other assets	31,266	31,821	'
Other Assets (Textuals)	'	'	'
Amortization of debt issuance costs	$1,990	$2,105	$1,450

Accrued_Liabilities_and_Other_2

Accrued Liabilities and Other Non-Current Liabilities (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Accrued Liabilities:	'	'
Taxes other than income taxes, primarily excise taxes	$30,354	$28,112
Accrued finance charges	1,365	1,927
Environmental accrual (Note 15)	1,307	831
Other	11,466	11,348
Total accrued liabilities	44,492	42,218
Other Non-Current Liabilities:	'	'
Consignment inventory obligation	24,482	31,842
Environmental accrual (Note 15)	5,640	5,516
Asset retirement obligations	1,973	1,890
Other	2,799	2,799
Total other non-current liabilities	34,894	42,047
Asset Retirement Obligation:	'	'
Balance at beginning of year	1,890	1,789
Accretion expense	83	79
Additions	0	22
Balance at end of year	$1,973	$1,890

Indebtedness_Details

Indebtedness (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Maturities of Long-term Debt [Abstract]	'	'	'
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$2,500	'	'
Long-term Debt, Maturities, Repayments of Principal in Year Two	2,500	'	'
Long-term Debt, Maturities, Repayments of Principal in Year Three	102,500	'	'
Long-term Debt, Maturities, Repayments of Principal in Year Four	2,500	'	'
Long-term Debt, Maturities, Repayments of Principal in Year Five	234,322	'	'
Long-term Debt, Gross	344,322	'	'
Schedule of Interest Expense [Abstract]	'	'	'
Interest Expense, Debt	25,815	9,454	5,889
Interest Expense, Other	13,241	11,628	10,093
Amortization of debt issuance costs	1,990	2,105	1,450
Amortization of original issuance discount	511	61	0
Interest Costs Capitalized	-1,083	-1,013	-713
Interest Expense	40,474	22,235	16,719
Schedule of Long-Term Debt Summary [Abstract]	'	'	'
Term loan credit facility	244,322	246,311	'
Revolving credit facility	100,000	49,000	'
Total debt	344,322	295,311	'
Less: Current portion	2,500	2,500	'
Total long-term debt	$341,822	$292,811	'

Indebtedness_Textuals_Details

Indebtedness Textuals (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]	'	'
Term loan credit facility	$244,322,000	$246,311,000
Debt Instrument, Covenant Compliance	'we were in compliance with these maintenance financial covenants	'
Revolving credit facility	100,000,000	49,000,000
Letters of Credit Outstanding, Amount	109,772,000	58,759,000
Partnership Term Loan [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt Instrument, Face Amount	250,000,000	'
Alon USA LP Credit Facility [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt Instrument, Face Amount	$240,000	'

Partners_Equity_Details

Partners' Equity (Details) (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Nov. 26, 2012
				Partner Type of Partners' Capital, Affiliated	Partner Type of Partners' Capital, Affiliated	Partner Type of Partners' Capital, Affiliated
Distributions Made to Members or Limited Partners [Abstract]	'	'	'	'	'	'
Distribution Made to Limited Partner, Cash Distributions Paid	$172,506	'	'	$140,760	'	'
Distribution Made to Limited Partner, Distributions Paid, Per Unit	$2.76	'	'	'	'	'
Payments of Distributions to Affiliates	$0	$410,106	$201,402	'	'	'
Limited Partners' Capital Account	'	'	'	'	'	'
Common units, shares outstanding	62,502,467	62,500,000	'	51,000,000	'	51,000,000
Ownership Percentage held by Parent	81.60%	'	'	'	81.60%	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Additional Disclosures [Abstract]	'	'	'	'	'	'
Stock Issued During Period, Shares, Restricted Stock Award, Gross	2,467	'	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$20.27	'	'	'	'	'

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Commitments and Contingencies Disclosure [Abstract]	'	'	'
Operating Leases, Future Minimum Payments Due, Next Twelve Months	$9,068	'	'
Operating Leases, Future Minimum Payments, Due in Two Years	8,744	'	'
Operating Leases, Future Minimum Payments, Due in Three Years	8,583	'	'
Operating Leases, Future Minimum Payments, Due in Four Years	8,464	'	'
Operating Leases, Future Minimum Payments, Due in Five Years	4,928	'	'
Operating Leases, Future Minimum Payments, Due Thereafter	262	'	'
Operating Leases, Future Minimum Payments Due	40,049	'	'
Operating Leases, Rent Expense	$11,396	$11,735	$12,190

Commitments_and_Contingencies_2

Commitments and Contingencies Schedule of Estimated Undiscounted Cash Flows for Discounted Environmental Remediation Liabilities (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Environmental Remediation Obligations [Abstract]	'	'
Accrual for Environmental Loss Contingencies, Undiscounted, Due in Next Twelve Months	$783	'
Accrual for Environmental Loss Contingencies, Undiscounted, Due in Second Year	783	'
Accrual for Environmental Loss Contingencies, Undiscounted, Due in Third Year	673	'
Accrual for Environmental Loss Contingencies, Undiscounted, Due in Fourth Year	603	'
Accrual for Environmental Loss Contingencies, Undiscounted, Due in Fifth Year	523	'
Accrual for Environmental Loss Contingencies, Undiscounted, Due after Fifth Year	3,825	'
Accrual for Environmental Loss Contingencies, Gross	7,190	'
Accrual for Environmental Loss Contingencies, Discount	1,375	'
Accrual for Environmental Loss Contingencies, Net, Total	$5,815	$5,717

Commitments_and_Contingencies_3

Commitments and Contingencies Accrued Environmental Obligations (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Accrual for Environmental Loss Contingencies Disclosure [Abstract]	'	'
Accrued Environmental Loss Contingencies, Current	$1,307	$831
Accrued Environmental Loss Contingencies, Noncurrent	5,640	5,516
Accrual for Environmental Loss Contingencies, Discount Rate	3.38%	'
Accrued Environmental Obligations [Abstract]	'	'
Discounted environmental liabilities	5,815	5,717
Undiscounted environmental liabilities	1,132	630
Total accrued environmental liabilities	$6,947	$6,347

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Related Party Expense, Allocated Corporate Overhead Costs	$11,731	$10,952	$10,336
Related Party Expense, Allocated Labor Costs	24,401	23,064	21,598
Related Party Expense, Allocated Insurance Costs	10,494	9,992	8,476
Repayments of Related Party Debt	0	171,120	0
Conversion of Subordinated Debt - Related Parties	'	178,163	'
Distribution Made to Limited Partner, Cash Distributions Paid	172,506	'	'
Distribution Made to Limited Partner, Distributions Paid, Per Unit	$2.76	'	'
Net cash payments to Alon Energy	0	410,106	201,402
Partner Type of Partners' Capital, Affiliated	'	'	'
Distribution Made to Limited Partner, Cash Distributions Paid	140,760	'	'
Alon Energy [Member]	'	'	'
Conversion of Subordinated Debt - Related Parties	'	$178,163	'

Quarterly_Information_unaudite2

Quarterly Information (unaudited) (Details) (USD $)	3 Months Ended									12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012		Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Quarterly Financial Data [Abstract]	'	'	'	'	'		'	'	'	'		'		'
Net sales	$878,524	$881,902	$865,694	$804,167	$825,626		$943,148	$823,769	$884,274	$3,430,287	[1]	$3,476,817	[1]	$3,207,969	[1]
Operating Income (Loss)	24,046	-3,932	54,750	103,813	124,119		130,241	111,093	57,899	178,677		423,352		330,792
Net income available to common unitholders	$13,496	($16,120)	$45,321	$93,525	$113,232		$120,367	$100,223	$48,076	$136,222		$381,898		$294,427
Earnings per limited partner unit	$0.22	($0.26)	$0.73	$1.50	$0.59	[2]	'	'	'	$2.18		$0.59		'
Weighted average common units outstanding (in thousands)	62,502	62,502	62,502	62,501	62,500		'	'	'	62,502		62,500		'
[1]	Includes sales to related parties of $600,710, $588,828 and $553,253 for the years ended December 31, 2013, 2012 and 2011, respectively.
[2]	Earnings per limited partner unit is not presented for periods prior to the completion of the Offering as there was no common equity or potential common equity publicly traded during those periods.

Subsequent_Event_Details

Subsequent Event (Details) (USD $)	12 Months Ended		0 Months Ended	3 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Feb. 13, 2014	Dec. 31, 2013
			Dividend Declared [Member]	Dividend Declared [Member]
Subsequent Event [Line Items]	'	'	'	'
Distribution Made to Limited Partner, Declaration Date	'	'	13-Feb-14	'
Cash distribution per limited partner unit	$2.76	$0	'	$0.18
Distribution Made to Limited Partner, Distribution Date	'	'	3-Mar-14	'
Distribution Made to Limited Partner, Date of Record	'	'	24-Feb-14	'