CVR Refining 10-Q 4 Nov 13 2013 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2013	Oct. 29, 2013
Document and Entity Information	'	'
Entity Registrant Name	'CVR Refining, LP	'
Entity Central Index Key	'0001558785	'
Document Type	'10-Q	'
Document Period End Date	30-Sep-13	'
Amendment Flag	'false	'
Current Fiscal Year End Date	'--12-31	'
Entity Current Reporting Status	'Yes	'
Entity Filer Category	'Non-accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	147,600,000
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'Q3	'

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$250.50	$153.10
Accounts receivable, net of allowance for doubtful accounts of $2.5 and $1.9, including $0.3 and $0.6 due from affiliates at September 30, 2013 and December 31, 2012, respectively	233.4	204.5
Inventories	647.3	499.5
Prepaid expenses and other current assets, including $1.3 and $0.9 due from affiliates at September 30, 2013 and December 31, 2012, respectively	134.6	27
Insurance receivable	0	1.3
Total current assets	1,265.80	885.4
Property, plant, and equipment, net of accumulated depreciation	1,395.60	1,351.60
Deferred financing costs, net	10.5	14.4
Insurance receivable	4	4
Other long-term assets, including $0.1 and $0.4 due from affiliates at September 30, 2013 and December 31, 2012, respectively	10.6	3.1
Total assets	2,686.50	2,258.50
Current liabilities:	'	'
Note payable and capital lease obligations	1.2	1.1
Accounts payable, including $13.4 and $0.4 due to affiliates at September 30, 2013 and December 31, 2012, respectively	349.1	364.7
Personnel accruals	12.5	14
Accrued taxes other than income taxes	19.5	29.5
Accrued expenses and other current liabilities, including $0.2 due to affiliates at September 30, 2013 and December 31, 2012	64.5	93.4
Total current liabilities	446.8	502.7
Long-term liabilities:	'	'
Long-term debt and capital lease obligations, net of current portion, including $11.5 million due to affiliates at September 30, 2013	561.7	772.1
Accrued environmental liabilities, net of current portion	1.4	1.6
Other long-term liabilities, including $1.2 and $1.3 due to affiliates at September 30, 2013 and December 31, 2012, respectively	1.3	1.3
Total long-term liabilities	564.4	775
Commitments and contingencies	'	'
Partners’ capital:	'	'
Common unitholders, 147,600,000 units issued and outstanding at September 30, 2013	1,675.30	0
General partner’s interest	0	0
Limited partner interest	0	980.8
Total partners’ capital	1,675.30	980.8
Total liabilities and partners’ capital	$2,686.50	$2,258.50

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, except Share data, unless otherwise specified
Statement of Financial Position [Abstract]	'	'
Accounts receivable, allowance for doubtful accounts	$2.50	$1.90
Accounts receivable, due from affiliates	0.3	0.6
Prepaid expenses and other current assets, due from affiliates	1.3	0.9
Other long-term assets, due from affiliates	0.1	0.4
Accounts payable, due to affiliates	13.4	0.4
Accrued expenses and other current liabilities, with affiliates	0.2	0.2
Long term debt and capital lease obligations, net of current portion, due to affiliates	11.5	0
Other long-term liabilities, due to affiliates	$1.20	$1.30
Common unitholders, units issued (in shares)	147,600,000	'
Common unitholders, units outstanding (in shares)	147,600,000	'

CONDENSED_CONSOLIDATED_AND_COM

CONDENSED CONSOLIDATED AND COMBINED STATEMENTS OF OPERATIONS (USD $)	3 Months Ended			9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012	Sep. 30, 2013		Sep. 30, 2012
Income Statement [Abstract]	'		'	'		'
Net sales	$1,910.50		$2,337.40	$6,322.60		$6,465.50
Operating costs and expenses:	'		'	'		'
Cost of product sold (exclusive of depreciation and amortization)	1,734.70		1,694.10	5,317		5,191
Direct operating expenses (exclusive of depreciation and amortization)	104.7		88.8	274.5		253.1
Selling, general and administrative expenses (exclusive of depreciation and amortization)	18.9		21.2	57.8		67.5
Depreciation and amortization	28.8		27.5	85.2		80.4
Total operating costs and expenses	1,887.10		1,831.60	5,734.50		5,592
Operating income	23.4		505.8	588.1		873.5
Other income (expense):	'		'	'		'
Interest expense and other financing costs	-10		-18.2	-34.8		-56
Interest income	0.1		0	0.3		0
Gain (loss) on derivatives, net	72.5		-168.9	173		-277.4
Loss on extinguishment of debt	0		0	-26.1		0
Other income (expense), net	0		-0.1	0.1		0.6
Total other income (expense)	62.6		-187.2	112.5		-332.8
Income before income tax expense	86		318.6	700.6		540.7
Income tax expense	0		0	0		0
Net income	86		318.6	700.6		540.7
Net income subsequent to initial public offering (January 23, 2013 through September 30, 2013)	$86		'	$622.80		'
Net income per common unit – basic (in usd per unit)	$0.58	[1]	'	$4.22	[1]	'
Net income per common unit – diluted (in usd per unit)	$0.58	[1]	'	$4.22	[1]	'
Weighted-average common units outstanding:	'		'	'		'
Basic (in units)	147.6		'	147.6		'
Diluted (in units)	147.6		'	147.6		'
[1]	Represents net income per common unit since closing the Partnership’s initial public offering on January 23, 2013. See Note 10 to the condensed consolidated and combined financial statements.

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN PARTNERS' CAPITAL (USD $)	Total	January issuance of common units	May issuance of additional common units	Common units	Common units	Common units	Limited Partner Interest
In Millions, except Share data, unless otherwise specified					January issuance of common units	May issuance of additional common units
Balance at Dec. 31, 2012	$980.80	'	'	'	'	'	$980.80
Increase (Decrease) in Stockholders' Equity	'	'	'	'	'	'	'
Net income attributable to period from January 1, 2013 through January 22, 2013	77.8	'	'	'	'	'	77.8
Share-based compensation – affiliates attributable to the period from January 1, 2013 through January 22, 2013	0.8	'	'	'	'	'	0.8
Distributions to affiliates, net	-150	'	'	'	'	'	-150
Conversion of limited partner interest to common units and general partner interest	'	'	'	909.4	'	'	-909.4
Conversion of limited partner interest to common units and general partner interest (in units)	'	'	'	147,600,000	'	'	'
Issuance of common units to public, net of offering costs	'	653.6	393.6	'	653.6	393.6	'
Issuance of common units to public, net of offering costs (in units)	'	'	'	'	'	13,209,236	'
Distributions to affiliates, net	-85.1	'	'	-85.1	'	'	'
May redemption of common units from CVR Refining Holdings, LLC	-394	'	'	-394	'	'	'
May redemption of common units from CVR Refining Holdings, LLC (in units)	'	'	'	-13,209,236	'	'	'
Share-based compensation - affiliates	7.5	'	'	7.5	'	'	'
Cash distributions to common unitholders - Affiliates	-345.5	'	'	-345.5	'	'	'
Cash distributions to common unitholders - Non-affiliates	-87	'	'	-87	'	'	'
Net income attributable to the period from January 23, 2013 through September 30, 2013	622.8	'	'	622.8	'	'	'
Balance at Sep. 30, 2013	$1,675.30	'	'	$1,675.30	'	'	'
Balance (in units) at Sep. 30, 2013	'	'	'	147,600,000	'	'	'

CONDENSED_CONSOLIDATED_AND_COM1

CONDENSED CONSOLIDATED AND COMBINED STATEMENTS OF CASH FLOWS (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Cash flows from operating activities:	'	'
Net income	$700.60	$540.70
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation and amortization	85.2	80.4
Allowance for doubtful accounts	0.6	0.6
Amortization of deferred financing costs	1.5	5.1
Amortization of original issue discount	0	0.4
Amortization of original issue premium	0	-2.6
Loss on disposition of assets	0	1
Loss on extinguishment of debt	26.1	0
Share-based compensation - affiliates	8.3	15.6
(Gain) loss on derivatives, net	-173	277.4
Current period settlements on derivative contracts	-3.9	-80.4
Changes in assets and liabilities:	'	'
Accounts receivable	-29.5	-99.5
Inventories	-147.8	118.6
Prepaid expenses and other current assets	-8.6	18
Insurance receivable	1.3	0.7
Other long-term assets	0.1	2.6
Accounts payable	-4.5	-90.5
Accrued expenses and other liabilities	27.3	11.1
Accrued environmental liabilities	-0.2	-0.1
Other long-term liabilities	-0.1	0.1
Net cash provided by operating activities	483.4	799.2
Cash flows from investing activities:	'	'
Capital expenditures	-140.8	-82.8
Proceeds from sale of assets	0.1	0.4
Net cash used in investing activities	-140.7	-82.4
Cash flows from financing activities:	'	'
Payment of capital lease obligations	-0.7	-0.7
Payments on senior secured notes	-243.4	0
Payment of deferred financing costs	-0.4	-2
Revolving debt borrowings - affiliates	11.5	0
Proceeds from issuance of common units, net of offering costs	'	0
Redemption of common units from CVR Refining Holdings, LLC	-394	0
Net distributions to parent	0	-637.3
Distributions to affiliates	-235.1	0
Net cash used in financing activities	-245.3	-640
Net increase in cash and cash equivalents	97.4	76.8
Cash and cash equivalents, beginning of period	153.1	2.7
Cash and cash equivalents, end of period	250.5	79.5
Supplemental disclosures:	'	'
Cash paid for interest net of capitalized interest of $1.7 and $3.0 in 2013 and 2012, respectively	32.5	36.5
Non-cash investing and financing activities:	'	'
Construction in process additions included in accounts payable	26.3	17.6
Change in accounts payable related to construction in process additions	-11.1	-2.3
January issuance of common units	'	'
Cash flows from financing activities:	'	'
Proceeds from issuance of common units, net of offering costs	655.7	'
May issuance of common units	'	'
Cash flows from financing activities:	'	'
Proceeds from issuance of common units, net of offering costs	393.6	'
Affiliates	'	'
Cash flows from financing activities:	'	'
Distributions to common unitholders – non-affiliates	-345.5	0
Non-affiliates	'	'
Cash flows from financing activities:	'	'
Distributions to common unitholders – non-affiliates	($87)	$0

CONDENSED_CONSOLIDATED_AND_COM2

CONDENSED CONSOLIDATED AND COMBINED STATEMENTS OF CASH FLOWS (Parenthetical) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Statement of Cash Flows [Abstract]	'	'
Capitalized interest	$1.70	$3

Formation_of_the_Partnership_O

Formation of the Partnership, Organization and Nature of Business	9 Months Ended
	Sep. 30, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Formation of the Partnership, Organization and Nature of Business	'
	Formation of the Partnership, Organization and Nature of Business
	CVR Refining, LP and subsidiaries (referred to as “CVR Refining” or the “Partnership”) is an independent petroleum refiner and marketer of high value transportation fuels. As of September 30, 2013, Coffeyville Resources, LLC (referred to as “CRLLC”) a wholly-owned subsidiary of CVR Energy, Inc. (referred to as “CVR Energy”), owns 100% of our general partner interest and approximately 71% of our limited partner interests. As of September 30, 2013, IEP (defined below) owns approximately 82% of CVR Energy.
	In preparation for the initial public offering (the "Initial Public Offering") of CVR Refining, on December 31, 2012, CRLLC contributed all of its interests in the operating subsidiaries which constitute its petroleum refining and related logistics business, as well as Coffeyville Finance Inc. ("Coffeyville Finance"), a finance subsidiary formed to serve as a co-issuer of debt securities, to a newly-formed subsidiary, CVR Refining, LLC ("Refining LLC"). The operating subsidiaries that were contributed to Refining LLC include the following entities: Wynnewood Energy Company, LLC ("WEC"); Wynnewood Refining Company, LLC ("WRC"); Coffeyville Resources Refining & Marketing, LLC ("CRRM"); Coffeyville Resources Crude Transportation, LLC ("CRCT"); Coffeyville Resources Terminal, LLC ("CRT"); and Coffeyville Resources Pipeline, LLC ("CRP"). The entities that were contributed by CRLLC to Refining LLC in connection with the Initial Public Offering are referred to herein as the "Refining Subsidiaries." CVR Refining Holdings, LLC ("CVR Refining Holdings"), a wholly-owned subsidiary of CRLLC, contributed its 100% membership interest in Refining LLC to the Partnership on December 31, 2012. In connection with the closing of the Initial Public Offering, CVR Refining Holdings and its subsidiary were issued a designated number of common units of the Partnership, which equated to approximately an 81% limited partner interest. CRLLC retained its other assets, including its ownership interests in CVR Partners, LP ("CVR Partners"), a NYSE traded manufacturer of nitrogen fertilizer, and its general partner.
	The contribution of entities as discussed above by CRLLC to Refining LLC is not considered a business combination accounted for under the purchase method as it is a transfer of assets under common control and, accordingly, balances were transferred at their historical cost. The combined financial statements for the periods prior to the contribution have been prepared using the Refining Subsidiaries' historical basis in the assets and liabilities, and include all revenues, costs, assets and liabilities attributed to these entities.
	Initial Public Offering of CVR Refining, LP
	On January 23, 2013, the Partnership completed its Initial Public Offering. The Partnership sold 24,000,000 common units to the public at a price of $25.00 per common unit. Additionally, on January 30, 2013, the Partnership sold an additional 3,600,000 common units to the public at a price of $25.00 per common unit in connection with the underwriters’ exercise of their option to purchase additional common units. The common units, which are listed on the NYSE, began trading on January 17, 2013 under the symbol "CVRR."
	The net proceeds to CVR Refining of approximately $653.6 million after deducting underwriting discounts and commissions and offering expenses from the Initial Public Offering have been, or will be, utilized as follows:
	•	approximately $253.0 million was used to repurchase CRLLC’s 10.875% senior secured notes due 2017 (including accrued interest);
	•	approximately $54.0 million was used to fund the turnaround expenses at the Wynnewood refinery that were incurred during the fourth quarter of 2012;
	•	approximately $85.1 million was distributed to CRLLC;
	•	approximately $160.0 million will be used to fund certain maintenance and environmental capital expenditures through 2014; and
	•	the balance of the proceeds of approximately $101.5 million has been allocated to be utilized for general corporate purposes.
	Prior to the closing of the Initial Public Offering, the Partnership distributed approximately $150.0 million of cash on hand to CRLLC. Subsequent to the closing of the Initial Public Offering and through May 19, 2013, common units held by public security holders represented approximately 19% of all outstanding limited partner interests (this includes common units held by an affiliate of Icahn Enterprises, representing approximately 3% of all outstanding limited partner interests) and CVR Refining Holdings held common units approximating 81% of all outstanding limited partner interests.
	Underwritten Offering
	On May 20, 2013, the Partnership completed an underwritten offering (the “Underwritten Offering”) by selling 12,000,000 common units to the public at a price of $30.75 per unit. American Entertainment Properties Corporation (“AEPC”), an affiliate of Icahn Enterprises LP, also purchased an additional 2,000,000 common units at the public offering price in a privately negotiated transaction with a CVR Energy subsidiary, which was completed on May 29, 2013. In connection with the Underwritten Offering, on June 10, 2013, the Partnership sold an additional 1,209,236 common units to the public at a price of $30.75 per unit in connection with a partial exercise by the underwriters of their option to purchase additional common units. The transactions described in this paragraph are collectively referred to as the “Transactions.”
	CVR Refining utilized proceeds of approximately $394.0 million from the Underwritten Offering (including the underwriters’ option) to redeem 13,209,236 common units from CVR Refining Holdings, an indirect wholly-owned subsidiary of CVR Energy. The Partnership did not receive any of the proceeds from the sale of common units by a CVR Energy subsidiary to AEPC.
	Subsequent to the closing of the Transactions and as of September 30, 2013, public security holders held approximately 29% of all outstanding limited partner interests (including common units held by affiliates of Icahn Enterprises, representing approximately 4% of all outstanding limited partner interests), and CVR Refining Holdings held approximating 71% of all outstanding limited partner interests. In addition, CVR Refining Holdings owns 100% of the Partnership’s general partner, CVR Refining GP, LLC, which holds a non-economic general partner interest.
	The Partnership's general partner, CVR Refining GP, LLC, manages the Partnership's activities subject to the terms and conditions specified in the Partnership's partnership agreement. The Partnership's general partner is owned by CVR Refining Holdings, an indirect wholly-owned subsidiary of CVR Energy. The operations of the general partner, in its capacity as general partner, are managed by its board of directors. Actions by the general partner that are made in its individual capacity are made by CVR Refining Holdings as the sole member of the Partnership's general partner and not by the board of directors of the general partner. The members of the board of directors of the Partnership's general partner are not elected by the Partnership's unitholders and are not subject to re-election on a regular basis. The officers of the general partner manage the day-to-day affairs of the business.
	The Partnership has adopted a policy pursuant to which it will distribute all of the available cash it generates each quarter. The available cash for each quarter will be determined by the board of directors of the Partnership's general partner following the end of such quarter and will generally be distributed within 60 days of quarter end. The partnership agreement does not require that the Partnership make cash distributions on a quarterly basis or at all, and the board of directors of the general partner of the Partnership can change the distribution policy at any time.
	The Partnership entered into a services agreement on December 31, 2012, pursuant to which the Partnership and its general partner obtain certain management and other services from CVR Energy. In addition, by virtue of the fact that the Partnership is a controlled affiliate of CVR Energy, the Partnership is bound by an omnibus agreement entered into by CVR Energy, CVR Partners and the general partner of CVR Partners, pursuant to which the Partnership may not engage in, whether by acquisition or otherwise, the production, transportation or distribution, on a wholesale basis, of fertilizer in the contiguous United States, or a fertilizer restricted business, for so long as CVR Energy and certain of its affiliates continue to own at least 50% of CVR Partners' outstanding units.
	CVR Energy Transaction Agreement
	On April 18, 2012, CVR Energy entered into a Transaction Agreement (the “Transaction Agreement”) with IEP Energy LLC and certain of its affiliates (collectively “IEP”). Pursuant to the Transaction Agreement, IEP offered (the “Offer”) to purchase all of the issued and outstanding shares of CVR Energy’s common stock (the “IEP Acquisition”) for a price of $30.00 per share in cash, without interest, less any applicable withholding taxes, plus one non-transferable contingent cash payment (“CCP”) right for each share which represents the contractual right to receive an additional cash payment per share if a definitive agreement for the sale of CVR Energy was executed on or before August 18, 2013 and such transaction closed. As no sale of CVR Energy was executed by the date outlined in the Transaction Agreement, the CCPs expired on August 19, 2013.
	On May 7, 2012, IEP announced that control of CVR Energy had been acquired through the Offer. As of September 30, 2013, IEP owned approximately 82% of the shares of CVR Energy.

Basis_of_Presentation

Basis of Presentation	9 Months Ended
	Sep. 30, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Basis of Presentation	'
	Basis of Presentation
	The accompanying condensed consolidated and combined financial statements have been prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) and in accordance with the rules and regulations of the Securities and Exchange Commission (the “SEC”). These condensed consolidated and combined financial statements should be read in conjunction with the December 31, 2012 audited consolidated and combined financial statements and notes thereto included in CVR Refining’s Annual Report on Form 10-K for the year ended December 31, 2012, which was filed with the SEC on March 14, 2013.
	Prior to the contribution of Refining LLC to the Partnership and entering into the services agreement on December 31, 2012, certain expenses incurred by CVR Energy and its affiliates were only indirectly attributable to its ownership of the refining and related logistics assets of CRLLC. As a result, certain assumptions and estimates were made in order to allocate a reasonable share of such expenses to CVR Refining, so that the financial statements reflect substantially all costs of doing business. Accounts and balances related to the refining and related logistics operations were based on a combination of specific identification and allocations. CVR Energy and CRLLC allocated various corporate overhead expenses based on a percentage of total refining and related logistics payroll to the total payrolls of their segments (i.e., the petroleum and fertilizer segments are comprised of CVR Refining and CVR Partners, respectively). See additional discussion in Note 15 ("Allocation of Costs").
	Beginning in 2013, the condensed consolidated financial statements include certain selling, general and administrative expenses (exclusive of depreciation and amortization) and direct operating expenses (exclusive of depreciation and amortization) that CVR Energy and its affiliates incurred on behalf of the Partnership. These related party transactions are governed by the services agreement originally entered into on December 31, 2012. See Note 16 ("Related Party Transactions") for additional discussion of the services agreement and billing and allocation of certain costs. The amounts charged or allocated to the Partnership are not necessarily indicative of the cost that the Partnership would have incurred had it operated as an independent entity.
	In the opinion of the Partnership’s management, the accompanying condensed consolidated and combined financial statements and related notes reflect all adjustments that are necessary to fairly present the financial position of the Partnership as of September 30, 2013 and December 31, 2012, the results of operations of the Partnership for the three and nine month periods ended September 30, 2013 and 2012, the changes in partners’ capital for the Partnership for the nine month period ended September 30, 2013 and the cash flows of the Partnership for the nine month periods ended September 30, 2013 and 2012.
	The preparation of condensed consolidated and combined financial statements in conformity with GAAP requires management to make estimates and assumptions that reflect the reported amounts of assets, liabilities, revenues and expenses. Actual results could differ from those estimates. Results of operations and cash flows are not necessarily indicative of the results that will be realized for the year ending December 31, 2013 or any other interim period.
	The Partnership has omitted net income per unit for the three and nine months ended September 30, 2012, because the Partnership operated under a different capital structure prior to the closing of the Initial Public Offering, and, as a result, the per unit data would not be meaningful to investors. Per unit data for the nine months ended September 30, 2013 is calculated since the closing of the Initial Public Offering on January 23, 2013.

Recent_Accounting_Pronouncemen

Recent Accounting Pronouncements	9 Months Ended
	Sep. 30, 2013
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]	'
Recent Accounting Pronouncements	'
	Recent Accounting Pronouncements
	In December 2011, the FASB issued ASU No. 2011-11, “Disclosures about Offsetting Assets and Liabilities” (“ASU 2011-11”). ASU 2011-11 retains the existing offsetting requirements and enhances the disclosure requirements to allow investors to better compare financial statements prepared under GAAP with those prepared under IFRS. On January 31, 2013, the FASB issued ASU No. 2013-01, “Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities” (“ASU 2013-01”). ASU 2013-01 limits the scope of the new balance sheet offsetting disclosures to derivatives, repurchase agreements and securities lending transactions. Both standards are effective for interim and annual periods beginning January 1, 2013 and are to be applied retrospectively. The Partnership adopted these standards as of January 1, 2013. The adoption of these standards expanded the Partnership’s condensed consolidated and combined financial statement footnote disclosures.

ShareBased_Compensation

Share-Based Compensation	9 Months Ended
	Sep. 30, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Share-Based Compensation	'
	Share‑Based Compensation
	Certain employees of CVR Refining and employees of CVR Energy who perform services for CVR Refining participate in the equity compensation plans of CVR Refining’s affiliates. Accordingly, CVR Refining has recorded compensation expense for these plans in accordance with SAB Topic 1-B and in accordance with guidance regarding the accounting for share-based compensation granted to employees of an equity method investee. All compensation expense related to these plans for full-time employees of CVR Refining has been allocated 100% to CVR Refining. For employees of CVR Energy performing services for CVR Refining, CVR Refining recorded share-based compensation relative to the percentage of time spent by each employee providing services to CVR Refining as compared to the total calculated share-based compensation by CVR Energy. CVR Refining is not responsible for payment of CVR Energy's share-based compensation and all expense amounts are recorded with a corresponding offset to increase or decrease to partners’ capital.
	Long-Term Incentive Plan—CVR Energy
	CVR Energy has a Long-Term Incentive Plan (“CVR Energy LTIP”) that permits the grant of options, stock appreciation rights, restricted stock, restricted stock units, dividend equivalent rights, share awards and performance awards (including performance share units, performance units and performance based restricted stock). As of September 30, 2013, only grants of restricted stock units under the CVR Energy LTIP remain outstanding. Individuals who are eligible to receive awards and grants under the CVR Energy LTIP include CVR Energy’s or its subsidiaries’ (including CVR Refining) employees, officers, consultants and directors.
	Restricted Shares
	Through the CVR Energy LTIP, shares of restricted stock and restricted stock units (collectively “restricted shares”) have been granted to employees of CVR Energy and CVR Refining. Restricted shares, when granted, were historically valued at the closing market price of CVR Energy’s common stock on the date of issuance and amortized to compensation expense on a straight-line basis over the vesting period of the common stock. These shares generally vest over a three-year period.
	The change of control and related Transaction Agreement in May 2012 triggered a modification to outstanding awards under the CVR Energy LTIP. Pursuant to the Transaction Agreement, all restricted shares scheduled to vest in 2012 were converted to restricted stock units whereby the recipient received cash settlement of the offer price of $30.00 per share in cash plus one CCP upon vesting. The CCPs expired on August 19, 2013. Restricted shares scheduled to vest in 2013, 2014 and 2015 were converted to restricted stock units whereby the awards will be settled in cash upon vesting in an amount equal to the lesser of the offer price or the fair market value as determined at the most recent valuation date of December 31 of each year. As a result of the modification, the Partnership was allocated additional share-based compensation of approximately $6.3 million for the nine months ended September 30, 2012. For awards vesting subsequent to 2012, the awards will be remeasured at each subsequent reporting date until they vest.
	In December 2012 and subsequent periods, restricted stock units were granted to certain employees of CVR Energy and its subsidiaries (including CVR Refining). The non-vested restricted stock units are scheduled to vest over three years, with one-third of the award vesting each year on the anniversary of the grant date, with the exception of awards granted to certain executive officers of CVR Energy that vest over one year. Each restricted stock unit represents the right to receive, upon vesting, a cash payment equal to (a) the fair market value of one share of CVR Energy's common stock, plus (b) the cash value of all dividends declared and paid per share of CVR Energy's common stock from the grant date to and including the vesting date. The awards will be remeasured at each subsequent reporting date until they vest.
	Additionally, CVR Energy approved a discretionary award of up to 62,920 restricted stock units to Mr. Lipinski, CVR Energy's Chief Executive Officer and President, on or before December 31, 2013. This discretionary award remains subject to the review and recommendation of the Compensation Committee and approval of the board of directors of CVR Energy, and is conditioned on Mr. Lipinski continuing to be employed through December 31, 2013. As such, no expense related to this discretionary award was recorded during the three and nine months ended September 30, 2013. To the extent awarded, the discretionary award will vest immediately, and include dividend equivalent rights for the time period commencing on December 28, 2012 through the date of the award.
	Assuming the allocation of costs from CVR Energy remains consistent with the allocation percentages in place at September 30, 2013, there was approximately $6.2 million of total unrecognized compensation cost related to restricted stock units and associated dividends to be recognized over a weighted-average period of approximately 0.75 years. Inclusion of the vesting table is not considered meaningful due to changes in allocation percentages that occur from time to time. The unrecognized compensation expense has been determined by the number of restricted stock units and associated dividends and respective allocation percentage for individuals for whom, as of September 30, 2013, compensation expense has been allocated to the Partnership. Compensation expense recorded for the three months ended September 30, 2013 and 2012 was approximately $2.1 million and $4.9 million, respectively. Compensation expense recorded for the nine months ended September 30, 2013 and 2012 was approximately $8.3 million and $15.6 million, respectively.
	Long-Term Incentive Plan – CVR Refining
	In connection with the Initial Public Offering, on January 16, 2013, the board of directors of the general partner of the Partnership adopted the CVR Refining, LP Long-Term Incentive Plan (the "CVR Refining LTIP"). Individuals who are eligible to receive awards under the CVR Refining LTIP include employees, officers, consultants and directors of CVR Refining and the general partner and their respective subsidiaries and parents. The CVR Refining LTIP provides for the grant 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, each in respect of common units. The maximum number of common units issuable under the CVR Refining LTIP is 11,070,000. On August 14, 2013, the Partnership filed a Form S-8 to register the common units. As of September 30, 2013, no awards have been granted under the plan.

Inventories

Inventories	9 Months Ended
	Sep. 30, 2013
Inventory Disclosure [Abstract]	'
Inventories	'
	Inventories
	Inventories consist primarily of domestic and foreign crude oil, blending stock and components, work-in-progress and refined fuels and by-products. Inventories are valued at the lower of the first-in, first-out (“FIFO”) cost or market for refined fuels and by-products for all periods presented. Refinery unfinished and finished products inventory values were determined using the ability-to-bear process, whereby raw materials and production costs are allocated to work-in-process and finished products based on their relative fair values. Other inventories, including other raw materials, spare parts, and supplies, are valued at the lower of moving-average cost, which approximates FIFO, or market. The cost of inventories includes inbound freight costs.
	Inventories consisted of the following:
		September 30,		December 31,
		2013		2012
		(in millions)
	Finished goods	$	353.8	$	269.5
	Raw materials and precious metals	185.6		158.1
	In-process inventories	78.5		42.7
	Parts and supplies	29.4		29.2
		$	647.3	$	499.5

Property_Plant_and_Equipment

Property, Plant, and Equipment	9 Months Ended
	Sep. 30, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant, and Equipment	'
	Property, Plant, and Equipment
	A summary of costs for property, plant, and equipment is as follows:
		September 30, 2013		December 31, 2012
		(in millions)
	Land and improvements	$	24.8	$	24
	Buildings	38.2		36.7
	Machinery and equipment	1,739.60		1,685.60
	Automotive equipment	16		14.3
	Furniture and fixtures	6.7		6.2
	Leasehold improvements	0.8		0.8
	Construction in progress	116.3		46
		1,942.40		1,813.60
	Accumulated depreciation	546.8		462
	Total property, plant and equipment, net	$	1,395.60	$	1,351.60
	Capitalized interest recognized as a reduction in interest expense for the three months ended September 30, 2013 and 2012 totaled approximately $0.7 million and $1.8 million, respectively. Capitalized interest recognized as a reduction in interest expense for the nine months ended September 30, 2013 and 2012 totaled approximately $1.7 million and $3.0 million, respectively. Land, buildings and equipment that are under a capital lease obligation had an original carrying value of approximately $24.8 million as of September 30, 2013 and December 31, 2012. Amortization of assets held under capital leases is included in depreciation expense.

Cost_Classifications

Cost Classifications	9 Months Ended
	Sep. 30, 2013
Costs and Expenses [Abstract]	'
Cost Classifications	'
	Cost Classifications
	Cost of product sold (exclusive of depreciation and amortization) includes cost of crude oil, other feedstocks, blendstocks, renewable identification numbers (“RINs”) and freight and distribution expenses. Cost of product sold excludes depreciation and amortization of approximately $1.2 million and $1.0 million for the three months ended September 30, 2013 and 2012, respectively. For the nine months ended September 30, 2013 and 2012, cost of product sold excludes depreciation and amortization of approximately $3.5 million and $2.5 million, respectively.
	Direct operating expenses (exclusive of depreciation and amortization) includes direct costs of labor, maintenance and services, energy and utility costs, property taxes, environmental compliance costs as well as chemicals and catalysts and other direct operating expenses. Direct operating expenses also include allocated non-cash share-based compensation for CVR Energy, as discussed in Note 4 ("Share‑Based Compensation"). Direct operating expenses exclude depreciation and amortization of approximately $27.5 million and $26.4 million for the three months ended September 30, 2013 and 2012, respectively. For the nine months ended September 30, 2013 and 2012, direct operating expenses exclude depreciation and amortization of approximately $81.4 million and $77.4 million, respectively.
	Selling, general and administrative expenses (exclusive of depreciation and amortization) consist primarily of direct and allocated legal expenses, treasury, accounting, marketing, human resources and maintaining the corporate and administrative offices in Texas, Kansas and Oklahoma. Selling, general and administrative expenses also include allocated non-cash share-based compensation expense from CVR Energy as discussed in Note 4 (“Share-Based Compensation”). Selling, general and administrative expenses exclude depreciation and amortization of approximately $0.1 million for each of the three months ended September 30, 2013 and 2012. For the nine months ended September 30, 2013 and 2012, selling, general and administrative expenses exclude depreciation and amortization of approximately $0.3 million and $0.5 million, respectively.

LongTerm_Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]	'
Long-Term Debt	'
	Long-Term Debt
	Long-term debt was as follows:
		September 30, 2013		December 31, 2012
		(in millions)
	10.875% Senior Secured Notes, due 2017, net of unamortized discount of $1.8 million as December 31, 2012	$	—	$	220.9
	6.5% Senior Notes, due 2022	500		500
	Intercompany credit facility	11.5		—
	Capital lease obligations	50.2		51.2
	Long-term debt	$	561.7	$	772.1
	Senior Secured Notes
	On April 6, 2010, CRLLC and its then wholly-owned subsidiary, Coffeyville Finance (together the “Issuers”), completed a private offering of $275.0 million aggregate principal amount of 9.0% First Lien Senior Secured Notes due 2015 (the "2010 First Lien Notes") and $225.0 million aggregate principal amount of 10.875% Second Lien Senior Secured Notes due 2017 (the "Second Lien Notes" and, together with the First Lien Notes, the "Old Notes"). The 2010 First Lien Notes were issued at 99.511% of their principal amount and the Second Lien Notes were issued at 98.811% of their principal amount. On December 15, 2011, the Issuers sold an additional $200.0 million aggregate principal amount of 9.0% First Lien Senior Secured Notes due 2015 (the "Additional First Lien Notes" and, together with the 2010 First Lien Notes, the “First Lien Notes”). The Additional First Lien Notes were sold at an issue price of 105.0%, plus accrued interest from October 1, 2011 of $3.7 million.
	The First Lien Notes were scheduled to mature on April 1, 2015, unless earlier redeemed or repurchased by the Issuers. See further discussion below related to the tender for and subsequent redemption of all of the outstanding First Lien Notes in the fourth quarter of 2012. The Second Lien Notes were scheduled to mature on April 1, 2017, unless earlier redeemed or repurchased by the Issuers. On January 23, 2013, $253.0 million of the proceeds from the Initial Public Offering were utilized to satisfy and discharge the indenture governing the Second Lien Notes. The amounts were used to (i) repay the face amount of all $222.8 million aggregate principal amount of Second Lien Notes then outstanding, (ii) pay the redemption premium of approximately $20.6 million and (iii) settle accrued interest with respect thereto in an amount of approximately $9.5 million. The repurchase of the Second Lien Notes resulted in a loss on extinguishment of debt of approximately $26.1 million for the nine months ended September 30, 2013, which includes the write-off of previously deferred financing fees of $3.7 million and unamortized original issue discount of $1.8 million.
	2022 Senior Secured Notes
	On October 23, 2012, Refining LLC and Coffeyville Finance completed a private offering of $500.0 million aggregate principal amount of 6.5% Second Lien Senior Secured Notes due 2022 (the "2022 Notes"). The 2022 Notes were issued at par. Refining LLC received approximately $492.5 million of cash proceeds, net of the underwriting fees, but before deducting other third-party fees and expenses associated with the offering. The 2022 Notes were secured by substantially the same assets that secured the then outstanding Second Lien Notes, subject to exceptions, until such time that the outstanding Second Lien Notes were satisfied and discharged in full, which occurred on January 23, 2013. The 2022 Notes are fully and unconditionally guaranteed by CVR Refining and each of Refining LLC’s existing domestic subsidiaries on a joint and several basis. CVR Refining has no independent assets or operations and Refining LLC is a 100% owned finance subsidiary of CVR Refining.  Prior to the satisfaction and discharge of the Second Lien Notes, which occurred on January 23, 2013, the 2022 Notes were also guaranteed by CRLLC. CVR Energy, CVR Partners and Coffeyville Nitrogen Fertilizers, LLC (“CRNF”) are not guarantors.
	A portion of the net proceeds from the offering of the 2022 Notes approximating $348.1 million were used to purchase approximately $323.0 million of the First Lien Notes pursuant to a tender offer and to settle accrued interest of approximately $1.8 million through October 23, 2012 and to pay related fees and expenses. Tendered notes were purchased at a premium of approximately $23.2 million in aggregate amount. CRLLC used the remaining proceeds from the offering to redeem the remaining $124.1 million of outstanding First Lien Notes and to settle accrued interest of approximately $1.6 million through November 23, 2012. Redeemed notes were purchased at a premium of approximately $8.4 million in aggregate amount.
	Previously deferred financing charges and unamortized original issuance premium related to the First Lien Notes totaled approximately $8.1 million and $6.3 million, respectively. As a result of the repayment of the First Lien Notes, a loss on extinguishment of debt of $33.4 million was recorded in the fourth quarter of 2012, which included the total premiums paid of $31.6 million and the write-off of previously deferred financing charges of $8.1 million, partially offset by the write-off of unamortized original issuance premium of $6.3 million.
	The debt issuance costs of the 2022 Notes totaled approximately $8.7 million and are being amortized over the term of the 2022 Notes as interest expense using the effective-interest amortization method. On September 17, 2013, Refining LLC and Coffeyville Finance consummated a registered exchange offer, whereby all $500.0 million of the outstanding 2022 Notes were exchanged for an equal principal amount of notes with identical terms that were registered under the Securities Act of 1933. The exchange offer fulfilled the Partnership's obligations contained in the registration rights agreement entered into in connection with the issuance of the 2022 Notes. The Partnership incurred approximately $0.1 million and $0.4 million of debt registration costs related to the registration and exchange offering during the three and nine months ended September 30, 2013, respectively, which are being amortized over the term of the 2022 Notes as interest expense using the effective-interest amortization method. The 2022 Notes mature on November 1, 2022, unless earlier redeemed or repurchased by the issuers. Interest is payable on the 2022 Notes semi-annually on May 1 and November 1 of each year, commencing on May 1, 2013.
	The 2022 Notes contain customary covenants for a financing of this type that limit, subject to certain exceptions, the incurrence of additional indebtedness or guarantees, the creation of liens on assets, the ability to dispose of assets, the ability to make certain payments on contractually subordinated debt, the ability to merge, consolidate with or into another entity and the ability to enter into certain affiliate transactions. The 2022 Notes provide that the Partnership can make distributions to holders of its common units provided, among other things, it has a minimum fixed charge coverage ratio and there is no default or event of default under the 2022 Notes. As of September 30, 2013, the Partnership was in compliance with the covenants contained in the 2022 Notes.
	At September 30, 2013, the estimated fair value of the 2022 Notes was approximately $485.6 million.These estimates of fair value are Level 2 as they were determined by quotations obtained from a broker dealer who makes a market in these and similar securities.
	Amended and Restated Asset Backed (ABL) Credit Facility
	On December 20, 2012, CRLLC, CVR Refining, Refining LLC and each of the operating subsidiaries of Refining LLC (collectively, the "Credit Parties") entered into an amended and restated ABL credit agreement (the "Amended and Restated ABL Credit Facility") with a group of lenders and Wells Fargo Bank, National Association ("Wells Fargo"), as administrative agent and collateral agent. The Amended and Restated ABL Credit Facility, which replaced the prior ABL credit facility, is scheduled to mature on December 20, 2017. Under the amended and restated facility, the Partnership assumed CRLLC's position as borrower and CRLLC's obligations under the facility upon closing of the Initial Public Offering on January 23, 2013.
	The Amended and Restated ABL Credit Facility is a senior secured asset based revolving credit facility in an aggregate principal amount of up to $400.0 million with an incremental facility, which permits an increase in borrowings of up to $200.0 million subject to receipt of additional lender commitments and certain other conditions. The proceeds of the loans may be used for capital expenditures and working capital and general corporate purposes of the Credit Parties and their subsidiaries. The Amended and Restated ABL Credit Facility provides for loans and letters of credit in an amount up to the aggregate availability under the facility, subject to meeting certain borrowing base conditions, with sub-limits of 10% of the total facility commitment for swingline loans and 90% of the total facility commitment for letters of credit.
	Borrowings under the Amended and Restated ABL Credit Facility bear interest at either a base rate or LIBOR plus an applicable margin. The applicable margin is (i) (a) 1.75% for LIBOR borrowings and (b) 0.75% for prime rate borrowings, in each case if quarterly average excess availability exceeds 50% of the lesser of the borrowing base and the total commitments and (ii) (a) 2.00% for LIBOR borrowings and (b) 1.00% for prime rate borrowings, in each case if quarterly average excess availability is less than or equal to 50% of the lesser of the borrowing base and the total commitments. The Amended and Restated ABL Credit Facility also requires the payment of customary fees, including an unused line fee of (i) 0.40% if the daily average amount of loans and letters of credit outstanding is less than 50% of the lesser of the borrowing base and the total commitments and (ii) 0.30% if the daily average amount of loans and letters of credit outstanding is equal to or greater than 50% of the lesser of the borrowing base and the total commitments. The Partnership will also be required to pay customary letter of credit fees equal to, for standby letters of credit, the applicable margin on LIBOR loans on the maximum amount available to be drawn under and, for commercial letters of credit, the applicable margin on LIBOR loans less 0.50% on the maximum amount available to be drawn under, and customary facing fees equal to 0.125% of the face amount of, each letter of credit.
	The Amended and Restated ABL Credit Facility also contains customary covenants for a financing of this type that limit the ability of the Credit Parties and their respective subsidiaries to, among other things, incur liens, engage in a consolidation, merger, purchase or sale of assets, pay dividends, incur indebtedness, make advances, investment and loans, enter into affiliate transactions, issue equity interests, or create subsidiaries and unrestricted subsidiaries. The amended and restated facility also contains a fixed charge coverage ratio financial covenant, as defined therein. The Partnership was in compliance with the covenants of the Amended and Restated ABL Credit Facility as of September 30, 2013.
	Lender and other third-party costs associated with the Amended and Restated ABL Credit Facility of $2.1 million were deferred and are being amortized to interest expense and other financing costs using a straight-line method over the term of the amended facility. In accordance with guidance provided by the FASB regarding the modification of revolving debt arrangements, a portion of the unamortized deferred costs associated with the prior ABL credit facility of approximately $2.8 million will continue to be amortized over the term of the Amended and Restated ABL Credit Facility.
	As of September 30, 2013, the Partnership had availability under the Amended and Restated ABL Credit Facility of $372.9 million and had letters of credit outstanding of approximately $27.1 million. There were no borrowings outstanding under the Amended and Restated ABL Credit Facility as of September 30, 2013.
	Intercompany Credit Facility
	On January 23, 2013, prior to the closing of the Initial Public Offering, the Partnership entered into a new $150.0 million senior unsecured revolving credit facility (the "intercompany credit facility") with CRLLC as the lender, to be used to fund growth capital expenditures. The intercompany credit facility is for a term of six years and bears interest at a rate of LIBOR plus 3% per annum, payable quarterly.
	The intercompany credit facility contains covenants that require the Partnership to, among other things, notify CRLLC of the occurrence of any default or event of default and provide CRLLC with information in respect of the Partnership’s business and financial status as it may reasonably require, including, but not limited to, copies of its unaudited quarterly financial statements and its audited annual financial statements. The Partnership was in compliance with the covenants of the intercompany credit facility as of September 30, 2013.
	In addition, the intercompany credit facility contains customary events of default, including, among others, failure to pay any sum payable when due; the occurrence of a default under other indebtedness in excess of $25.0 million; and the occurrence of an event that results in either (i) CRLLC no longer directly or indirectly controlling the general partner, or (ii) CRLLC and its affiliates no longer owning a majority of the Partnership’s equity interests. As of September 30, 2013, the Partnership had borrowings of $11.5 million outstanding and $138.5 million available under the intercompany credit facility.
	Capital Lease Obligations
	As a result of the acquisition of the Wynnewood refinery, CVR Refining acquired two leases accounted for as a capital lease and a finance obligation related to Magellan Pipeline Terminals, L.P. and Excel Pipeline LLC. The underlying assets and related depreciation were included in property, plant and equipment. The capital lease relates to a sales-lease back agreement with Sunoco Pipeline, L.P. for its membership interest in the Excel Pipeline. The lease has 193 months remaining through September 2029. The financing agreement relates to the Magellan Pipeline terminals, bulk terminal and loading facility. The lease has 192 months remaining and will expire in September 2029.

Partners_Capital_and_Partnersh

Partners' Capital and Partnership Distributions	9 Months Ended
	Sep. 30, 2013
Equity [Abstract]	'
Partners' Capital and Partnership Distributions	'
	Partners’ Capital and Partnership Distributions
	The Partnership had two types of partnership interests outstanding at September 30, 2013:
	•	common units; and
	•	a general partner interest, which is not entitled to any distributions, and which is held by the general partner.
	At September 30, 2013, the Partnership had a total of 147,600,000 common units issued and outstanding, of which 104,790,764 common units were owned by CVR Refining Holdings, a wholly-owned subsidiary of CVR Energy, representing approximately 71% of the total Partnership units outstanding.
	The board of directors of the Partnership's general partner has adopted a policy for the Partnership to distribute all available cash generated on a quarterly basis. Cash distributions will be made to the common unitholders of record on the applicable record date, generally within 60 days after the end of each quarter. Available cash for each quarter will be determined by the board of directors of the general partner following the end of such quarter. Available cash for each quarter will generally equal Adjusted EBITDA reduced for cash needed for debt service, reserves for environmental and maintenance capital expenditures, reserves for future major scheduled turnaround expenses and, to the extent applicable, reserves for future operating or capital needs that the board of directors of our general partner deems necessary or appropriate, if any. Adjusted EBITDA represents EBITDA (net income before interest expense, net, income tax expense, and depreciation amortization) adjusted for (i) FIFO impacts (favorable) unfavorable, (ii) share-based compensation, non-cash, (iii) loss on extinguishment of debt, (iv) major scheduled turnaround expenses, (v) (gain) loss on derivatives, net, (vi) current period settlements on derivative contracts and (vii) Wynnewood acquisition transaction fees and integration expenses. Available cash for distributions may be increased by previously established cash reserves, if any, and other excess cash, at the discretion of the board of directors of our general partner.
	The following is a summary of cash distributions paid to the Partnership’s unitholders during 2013 for the respective quarters to which the distributions relate:
		March 31, 2013(1)		30-Jun-13		Total Cash
						Distributions
						Paid in 2013
		(in millions, expect per common unit amounts)
	Amount paid to CVR Refining Holdings, LLC and affiliates	$	195.9	$	149.6	$	345.5
	Amounts paid to non-affiliates	37.3		49.7		87
	Total amount paid	$	233.2	$	199.3	$	432.5
	Per common unit	$	1.58	$	1.35	$	2.93
	Common units outstanding	147.6		147.6
	-1	The distribution for the period ended March 31, 2013 was adjusted to exclude the period from January 1, 2013 through January 22, 2013 (the period preceding the closing of the Initial Public Offering).

Net_Income_per_Common_Unit

Net Income per Common Unit	9 Months Ended
	Sep. 30, 2013
Earnings Per Share [Abstract]	'
Net Income per Common Unit	'
	Net Income per Common Unit
	The net income per common unit on the Condensed Consolidated and Combined Statements of Operations is based on the net income of the Partnership after the closing of its Initial Public Offering on January 23, 2013 through September 30, 2013, since this is the amount of net income that is attributable to the Partnership’s common units.
	The Partnership's net income is allocated wholly to the common units as the general partner does not have an economic interest.
	Basic and diluted net income per common unit is calculated by dividing net income by the weighted-average number of common units outstanding during the period and, when applicable, giving effect to unvested common units granted under the CVR Refining LTIP. No common units were issued or outstanding under the CVR Refining LTIP during the period.
	The following table illustrates the Partnership's calculation of net income per common unit:
		Three Months Ended		January 23, 2013 to
		September 30, 2013		30-Sep-13
		(in millions, except per unit data)
	Net income (from the closing of the offering on January 23, 2013 to September 30, 2013)	$	86	$	622.8
	Net income per common unit, basic	$	0.58	$	4.22
	Net income per common unit, diluted	$	0.58	$	4.22
	Weighted-average common units outstanding, basic	147.6		147.6
	Weighted-average common units outstanding, diluted	147.6		147.6

Income_Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2013
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	Income Taxes
	CVR Refining is treated as a partnership for U.S. federal income tax purposes. Generally, each common unitholder is required to take into account its respective share of CVR Refining's income, gains, loss and deductions. The Partnership is not subject to income taxes, except for a franchise tax in the state of Texas. The income tax liability of the common unitholders is not reflected in the condensed consolidated and combined financial statements of the Partnership.

Commitments_and_Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Commitments and Contingencies
	Leases and Unconditional Purchase Obligations
	The minimum required payments for CVR Refining’s operating lease agreements and unconditional purchase obligations are as follows:
		Operating		Unconditional
		Leases		Purchase Obligations(1)
		(in millions)
	Three months ending December 31, 2013	$	0.7	$	82.7
	Year Ending December 31,
	2014	2.3		108.5
	2015	1.4		96.7
	2016	1		89.6
	2017	0.3		88.4
	Thereafter	0.3		940.7
		$	6	$	1,406.60
	(1) This amount includes approximately $965.5 million payable ratably over eighteen years pursuant to petroleum transportation service agreements between CRRM and TransCanada Keystone Pipeline, LP (“TransCanada”). Under the agreements, CRRM receives transportation of at least 25,000 barrels per day of crude oil with a delivery point at Cushing, Oklahoma for a term of twenty years on TransCanada’s Keystone pipeline system. CRRM began receiving crude oil under the agreements in the first quarter of 2011.
	CVR Refining leases various equipment and real properties under long-term operating leases expiring at various dates. For each of the three months ended September 30, 2013 and 2012, lease expense totaled approximately $0.8 million. For the nine months ended September 30, 2013 and 2012, lease expense totaled approximately $2.5 million and $2.3 million, respectively. The lease agreements have various remaining terms. Some agreements are renewable, at CVR Refining’s option, for additional periods. It is expected, in the ordinary course of business, that leases will be renewed or replaced as they expire. Additionally, in the normal course of business, the Partnership has long-term commitments to purchase storage capacity and pipeline transportation services.
	Crude Oil Supply Agreement
	On August 31, 2012, CRRM and Vitol Inc. ("Vitol") entered into an Amended and Restated Crude Oil Supply Agreement (the "Vitol Agreement"). The Vitol Agreement amends and restates the Crude Oil Supply Agreement between CRRM and Vitol dated March 30, 2011, as amended. Under the Vitol Agreement, Vitol supplies the Partnership’s refineries with crude oil and intermediation logistics, which helps to reduce the Partnership's inventory position and mitigate crude oil pricing risk.
	The Vitol Agreement has an initial term commencing on August 31, 2012 and extending through December 31, 2014 (the "Initial Term"). Following the Initial Term, the Vitol Agreement will automatically renew for successive one-year terms (each such term, a "Renewal Term") unless either party provides the other with notice of nonrenewal at least 180 days prior to the expiration of the Initial Term or any Renewal Term.
	Litigation
	From time to time, CVR Refining is involved in various lawsuits arising in the normal course of business, including matters such as those described below under “Environmental, Health, and Safety (“EHS”) Matters.” Liabilities related to such litigation are recognized when the related costs are probable and can be reasonably estimated. These provisions are reviewed at least quarterly and adjusted to reflect the impacts of negotiations, settlements, rulings, advice of legal counsel, and other information and events pertaining to a particular case. It is possible that management’s estimates of the outcomes will change due to uncertainties inherent in litigation and settlement negotiations. In the opinion of management, the ultimate resolution of any other litigation matters is not expected to have a material adverse effect on the accompanying condensed consolidated and combined financial statements. There can be no assurance that management’s beliefs or opinions with respect to liability for potential litigation matters are accurate.
	Flood, Crude Oil Discharge and Insurance
	Crude oil was discharged from CVR Refining’s Coffeyville refinery on July 1, 2007, due to the short amount of time available to shut down and secure the refinery in preparation for the flood that occurred on June 30, 2007. In May 2008, in connection with the discharge, CVR Refining received notices of claims from sixteen private claimants under the Oil Pollution Act (“OPA”) in an aggregate amount of approximately $4.4 million (plus punitive damages). In August 2008, those claimants filed suit against CVR Refining in the United States District Court for the District of Kansas in Wichita (the “Angleton Case”). In October 2009 and June 2010, companion cases to the Angleton Case were filed in the United States District Court for the District of Kansas in Wichita, seeking a total of approximately $3.2 million (plus punitive damages) for three additional plaintiffs as a result of the July 1, 2007 crude oil discharge. CVR Refining has settled all of the claims with the plaintiffs from the Angleton Case and has settled all of the claims except for one of the plaintiffs from the companion cases. The settlements did not have a material adverse effect on the condensed consolidated and combined financial statements. CVR Refining believes that the resolution of the remaining claim will not have a material adverse effect on the condensed consolidated and combined financial statements.
	On October 25, 2010, CVR Refining received a letter from the United States Coast Guard on behalf of the U.S. Environmental Protection Agency (the “EPA”) seeking approximately $1.8 million in oversight cost reimbursement. CVR Refining responded by asserting defenses to the Coast Guard’s claim for oversight costs. On September 23, 2011, the United States Department of Justice (“DOJ”), acting on behalf of the EPA and the United States Coast Guard, filed suit against CRRM in the United States District Court for the District of Kansas seeking recovery from CRRM related to alleged non-compliance with the Clean Air Act’s Risk Management Program (“RMP”), the Clean Water Act (“CWA”) and the OPA. CRRM reached an agreement with the DOJ resolving its claims under the CWA and the OPA. The agreement is memorialized in a Consent Decree that was filed with and approved by the Court on February 12, 2013 and March 25, 2013, respectively (the “2013 Consent Decree”). On April 19, 2013, CRRM paid a civil penalty (including accrued interest) in the amount of $0.6 million for the CWA violations and reimbursed the Coast Guard for oversight costs under OPA in the amount of $1.7 million. The 2013 Consent Decree also requires CRRM to make small capital upgrades to the Coffeyville refinery crude oil tank farm, develop flood procedures and provide employee training. The parties also reached an agreement to settle DOJ’s RMP claims, which was filed with and approved by the Court on May 21, 2013 and July 2, 2013, respectively, and provided for a civil penalty of $0.3 million. On July 29, 2013, CRRM paid the civil penalty related to the RMP settlement agreement.
	CVR Refining is seeking insurance coverage for this release and for the ultimate costs for remediation and third-party property damage claims. On July 10, 2008, CRRM filed a lawsuit in the United States District Court for the District of Kansas against certain of its environmental insurance carriers requesting insurance coverage indemnification for the June/July 2007 flood and crude oil discharge losses. Each insurer reserved its rights under various policy exclusions and limitations and cited potential coverage defenses. Although the Court has now issued summary judgment opinions that eliminate the majority of the insurance defendants’ reservations and defenses, CVR Refining cannot be certain of the ultimate amount or timing of such recovery because of the difficulty inherent in projecting the ultimate resolution of the claims. CVR Refining has received $25.0 million of insurance proceeds under its primary environmental liability insurance policy which constitutes full payment of the primary pollution liability policy limit.
	The lawsuit with the insurance carriers under the environmental policies remains the only unsettled lawsuit with the insurance carriers related to these events.
	Environmental, Health, and Safety (“EHS”) Matters
	CRRM, CRCT, CRT and WRC are subject to various stringent federal, state, and local EHS rules and regulations. Liabilities related to EHS matters are recognized when the related costs are probable and can be reasonably estimated. Estimates of these costs are based upon currently available facts, existing technology, site-specific costs, and currently enacted laws and regulations. In reporting EHS liabilities, no offset is made for potential recoveries.
	CRRM, CRCT, WRC and CRT own and/or operate manufacturing and ancillary operations at various locations directly related to petroleum refining and distribution. Therefore, CRRM, CRCT, WRC and CRT have exposure to potential EHS liabilities related to past and present EHS conditions at these locations. Under the Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”), the Resource Conservation and Recovery Act (“RCRA”), and related state laws, certain persons may be liable for the release or threatened release of hazardous substances. These persons include the current owner or operator of property where a release or threatened release occurred, any persons who owned or operated the property when the release occurred, and any persons who disposed of, or arranged for the transportation or disposal of, hazardous substances at a contaminated property. Liability under CERCLA is strict, and under certain circumstances, joint and several, so that any responsible party may be held liable for the entire cost of investigating and remediating the release of hazardous substances. Similarly, the OPA generally subjects owners and operators of facilities to strict, joint and several liability for all containment and clean-up costs, natural resource damages, and governmental oversight costs arising from oil spills into waters of the United States, which has been broadly interpreted to include virtually any water bodies including intermittent streams and water bodies.
	CRRM and CRT have agreed to perform corrective actions at the Coffeyville, Kansas refinery and the now-closed Phillipsburg, Kansas terminal facility, pursuant to Administrative Orders on Consent issued under RCRA to address historical contamination by the prior owners (RCRA Docket No. VII-94-H-0020 and Docket No. VII-95-H-011, respectively). As of September 30, 2013 and December 31, 2012, environmental accruals of approximately $1.8 million and $2.3 million respectively, were reflected in the Condensed Consolidated Balance Sheets for probable and estimated costs for remediation of environmental contamination under the RCRA Administrative Orders, for which approximately $0.4 million and $0.7 million, respectively, are included in other current liabilities. The Partnership’s accruals were determined based on an estimate of payment costs through 2031, for which the scope of remediation was arranged with the EPA, and were discounted at the appropriate risk free rates at September 30, 2013 and December 31, 2012, respectively. The accruals include estimated closure and post-closure costs of approximately $0.8 million for two landfills at both September 30, 2013 and December 31, 2012. The estimated future payments for these required obligations are as follows:
		Amount
		(in millions)
	Three months ending December 31, 2013	$	0.2
	Year Ending December 31,
	2014	0.4
	2015	0.2
	2016	0.1
	2017	0.1
	Thereafter	1.1
	Undiscounted total	2.1
	Less amounts representing interest at 2.34%	0.3
	Accrued environmental liabilities at September 30, 2013	$	1.8
	Management periodically reviews and, as appropriate, revises its environmental accruals. Based on current information and regulatory requirements, management believes that the accruals established for environmental expenditures are adequate.
	CRRM, CRCT, WRC and CRT are subject to extensive and frequently changing federal, state and local, environmental and health and safety laws and regulations governing the emission and release of hazardous substances into the environment, the treatment and discharge of waste water, the storage, handling, use and transportation of petroleum and the characteristics and composition of gasoline and diesel fuels. The ultimate impact of complying with evolving laws and regulations is not always clearly known or determinable due in part to the fact that our operations may change over time and certain implementing regulations for laws, such as the federal Clean Air Act, have not yet been finalized, are under governmental or judicial review or are being revised. These laws and regulations could result in increased capital, operating and compliance costs.
	In 2007, the EPA promulgated the Mobile Source Air Toxic II (“MSAT II”) rule that requires the reduction of benzene in gasoline by 2011. CRRM and WRC are considered to be small refiners under the MSAT II rule and compliance with the rule is extended until 2015 for small refiners. However, the change in control resulting from the IEP Acquisition in 2012 caused the companies to lose small refiner status. Accordingly, the MSAT II projects have been accelerated by three months. Total capital expenditures to comply with the rule are expected to be approximately $63.0 million for CRRM and $105.0 million for WRC. As of September 30, 2013, approximately $19.1 million and $35.4 million had been spent related to these projects by CRRM and WRC, respectively.
	CVR Refining is subject to the Renewable Fuel Standard ("RFS") which requires refiners to blend "renewable fuels" in with their transportation fuels or purchase renewable fuel credits, known as RINs, in lieu of blending. The EPA is required to determine and publish the applicable annual renewable fuel percentage standards for each compliance year by November 30 for the forthcoming year. The percentage standards represent the ratio of renewable fuel volume to gasoline and diesel volume. On August 6, 2013 the EPA announced the final 2013 renewable fuel standard would be raised to 9.74%. Beginning in 2011, the Coffeyville refinery was required to blend renewable fuels into its transportation fuel or purchase RINs in lieu of blending, and in 2013, the Wynnewood refinery will be required to comply unless the Wynnewood refinery receives relief from the rule in 2013 based on the "disproportionate economic impact" of the rule on the Wynnewood refinery. From time to time, CVR Refining may purchase RINs on the open market or waiver credits for cellulosic biofuels from the EPA in order to comply with RFS. While CVR Refining cannot predict the future prices of RINs or waiver credits, the cost of purchasing RINs has been extremely volatile and has significantly increased over the last year. The cost of RINs for the three and nine month periods ended September 30, 2012 was approximately $7.1 million and $16.5 million, respectively, and the cost of RINs for the three and nine month periods ended September 30, 2013 was approximately $57.4 million and $155.0 million, respectively. As of September 30, 2013 and December 31, 2012, CVR Refining’s biofuel blending obligation was approximately $47.5 million and $1.1 million, respectively, which was recorded in accrued expenses and other current liabilities in the Condensed Consolidated Balance Sheets. The ultimate cost of RINs for the Partnership in 2013 is difficult to estimate. In particular, the cost of RINs is dependent upon a variety of factors, which include the price at which RINs can be purchased, transportation fuel production levels, the mix of the Partnership's petroleum products, as well as the fuel blending performed at the Partnership’s refineries, all of which can vary significantly from quarter to quarter.
	In 2013, the EPA proposed "Tier 3" gasoline sulfur standards. Based on the proposed standards, CRRM anticipates it will incur less than $20.0 million of capital expenditures to install controls in order to meet the anticipated new standards. The project is expected to be completed during the Coffeyville refinery’s next scheduled turnaround in 2016. It is not anticipated that the Wynnewood refinery will require additional controls or capital expenditures to meet the anticipated new standard.
	In March 2004, CRRM and CRT entered into a Consent Decree (the “2004 Consent Decree”) with the EPA and the Kansas Department of Health and Environment (the “KDHE”) to resolve air compliance concerns raised by the EPA and KDHE related to Farmland Industries Inc.’s prior ownership and operation of the Coffeyville crude oil refinery and the now-closed Phillipsburg terminal facilities. Under the 2004 Consent Decree, CRRM agreed to install controls to reduce emissions of sulfur dioxide, nitrogen oxides and particulate matter from its FCCU by January 1, 2011. In addition, pursuant to the 2004 Consent Decree, CRRM and CRT assumed clean-up obligations at the Coffeyville refinery and the now-closed Phillipsburg terminal facilities.
	In March 2012, CRRM entered into a "Second Consent Decree" with the EPA, which replaces the 2004 Consent Decree, as amended (other than certain financial assurance provisions associated with corrective action at the refinery and terminal under RCRA). The Second Consent Decree gives CRRM more time to install the FCCU controls from the 2004 Consent Decree and expands the scope of the settlement so that it is now considered a "global settlement" under the EPA's "National Petroleum Refining Initiative." Under the National Petroleum Refining Initiative, the EPA alleged industry-wide non-compliance with four "marquee" issues under the Clean Air Act: New Source Review, Flaring, Leak Detection and Repair, and Benzene Waste Operations NESHAP. The National Petroleum Refining Initiative has resulted in most U.S. refineries (representing more than 90% of the US refining capacity) entering into consent decrees requiring the payment of civil penalties and the installation of air pollution control equipment and enhanced operating procedures. Under the Second Consent Decree, the Partnership was required to pay a civil penalty of approximately $0.7 million and complete the installation of FCCU controls required under the 2004 Consent Decree, add controls to certain heaters and boilers and enhance certain work practices relating to wastewater and fugitive emissions. The remaining costs of complying with the Second Consent Decree are expected to be approximately $40.0 million. CRRM also agreed to complete a voluntary environmental project that will reduce air emissions and conserve water at an estimated cost of approximately $1.2 million. Additional incremental capital expenditures associated with the Second Consent Decree will not be material and will be limited primarily to the retrofit and replacement of heaters and boilers over a five to seven year timeframe. The Second Consent Decree was entered by the U.S. District Court for the District of Kansas on April 19, 2012.
	WRC entered into a Consent Order with the Oklahoma Department of Environmental Quality (the "ODEQ") in August 2011 (the "Wynnewood Consent Order"). The Wynnewood Consent Order addresses certain historic Clean Air Act compliance issues related to the operations of the refinery by the prior owner. Under the Wynnewood Consent Order, WRC paid a civil penalty of $950,000, and agreed to install certain controls, enhance certain compliance programs, and undertake additional testing and auditing. A substantial portion of the costs of complying with the Wynnewood Consent Order were expended during the last turnaround in 2012. The remaining costs are expected to be $3.0 million. In consideration for entering into the Wynnewood Consent Order, WRC received a release from liability from ODEQ for matters described in the ODEQ order.
	From time to time, ODEQ conducts inspections of the Wynnewood refinery and identifies areas of alleged noncompliance. ODEQ routinely pursues enforcement related to the alleged noncompliance seeking civil penalties and injunctive relief, which may necessitate the installation of controls. ODEQ has advised the company that it is preparing to issue a full compliance evaluation report covering the period from 2010 through 2013. The agency has indicated that it will pursue enforcement related to the alleged noncompliance and that it expects to enter into a second Consent Order with the Company, which would necessitate the payment of a civil penalty and the implementation of injunctive relief to address the alleged noncompliance. The costs of any such enforcement action cannot be predicted at this time. However, based on our experience related to Clean Air Act enforcement and control requirements, the Company does not anticipate that the costs of any civil penalties, required additional controls or operational changes would be material.
	WRC has entered into a series of Clean Water Act consent orders with ODEQ. The latest Consent Order (the “CWA Consent Order”), which supersedes other consent orders, became effective in September 2011. The CWA Consent Order addresses alleged non-compliance by WRC with its Oklahoma Pollutant Discharge Elimination System permit limits. The CWA Consent Order requires WRC to take corrective action steps, including undertaking studies to determine whether the Wynnewood refinery’s wastewater treatment plant capacity is sufficient. The Wynnewood refinery may need to install additional controls or make operational changes to satisfy the requirements of the CWA Consent Order. The cost of additional controls, if any, cannot be predicted at this time. However, based on our experience with wastewater treatment and controls, the Partnership does not anticipate that the costs of any required additional controls or operational changes would be material.
	Environmental expenditures are capitalized when such expenditures are expected to result in future economic benefits. For the three months ended September 30, 2013 and 2012, capital expenditures were approximately $35.5 million and $7.7 million, respectively, and were incurred to improve the environmental compliance and efficiency of the operations. For the nine months ended September 30, 2013 and 2012, capital expenditures were approximately $73.5 million and $18.4 million, respectively, and were incurred to improve the environmental compliance and efficiency of the operations.
	CRRM, CRCT, WRC and CRT each believe it is in substantial compliance with existing EHS rules and regulations. There can be no assurance that the EHS matters described above or other EHS matters which may develop in the future will not have a material adverse effect on the Partnership's business, financial condition, or results of operations.
	Wynnewood Refinery Incident
	On September 28, 2012, the Wynnewood refinery experienced an explosion in a boiler unit during start up after a short outage as part of the turnaround process. Two employees were fatally injured. Damage at the refinery was limited to the boiler. Additionally, there was no environmental impact. The refinery was in the final stages of shutdown for turnaround maintenance at the time of the incident. The Partnership has completed an internal investigation of the incident and cooperated with OSHA in its investigation. OSHA also conducted a general inspection of the facility during the boiler incident investigation. In March 2013, OSHA completed its investigation and communicated its citations to WRC. OSHA also placed WRC in its Severe Violators Enforcement Program (“SVEP”). WRC is vigorously contesting the citations and OSHA’s placement of WRC in the SVEP. Any penalties associated with OSHA’s citations are not expected to have a material adverse effect on the condensed consolidated and combined financial statements. On September 25, 2013, WRC agreed to pay a small civil penalty to settle, rather than defend claims alleged by the EPA under the Clean Air Act's general duty clause related to the boiler incident. In addition to the above, the spouses of the two employees fatally injured have filed a civil lawsuit against WRC, CVR Refining and CVR Energy in Fort Bend County, Texas. The civil suit is in its preliminary stages and it is currently too early to assess a potential outcome.

Fair_Value_Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	Fair Value Measurements
	In accordance with ASC Topic 820 — Fair Value Measurements and Disclosures (“ASC 820”), the Partnership utilizes the market approach to measure fair value for its financial assets and liabilities. The market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets, liabilities or a group of assets or liabilities, such as a business.
	ASC 820 utilizes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three broad levels. The following is a brief description of those three levels:
	•	Level 1 — Quoted prices in active markets for identical assets and liabilities
	•	Level 2 — Other significant observable inputs (including quoted prices in active markets for similar assets or liabilities)
	•	Level 3 — Significant unobservable inputs (including the Partnership’s own assumptions in determining the fair value)
	The following table sets forth the assets and liabilities measured at fair value on a recurring basis, by input level, as of September 30, 2013 and December 31, 2012:
		September 30, 2013
		Level 1		Level 2			Level 3		Total
		(in millions)
	Location and Description
	Other current assets (derivative agreements)	$	—	$	101.9		$	—	$	101.9
	Other long-term assets (derivative agreements)	—		8.2			—		8.2
	Total Assets	$	—	$	110.1		$	—	$	110.1
		December 31, 2012
		Level 1		Level 2			Level 3		Total
		(in millions)
	Location and Description
	Other long-term assets (derivative agreements)	$	—	$	0.9		$	—	$	0.9
	Total Assets	$	—	$	0.9		$	—	$	0.9
	Other current liabilities (derivative agreements)	—		(67.7		)	—		(67.7		)
	Other current liabilities (biofuel blending obligation)	—		(1.1		)	—		(1.1		)
	Total Liabilities	$	—	$	(68.8	)	$	—	$	(68.8	)
	As of September 30, 2013 and December 31, 2012, the only financial assets and liabilities that are measured at fair value on a recurring basis are CVR Refining’s derivative instruments and the uncommitted biofuel blending obligation. Additionally, the fair value of the debt issuances is disclosed in Note 8 ("Long-Term Debt"). The commodity derivative contracts and the uncommitted biofuel blending obligation which use fair value measurements are valued using broker quoted market prices of similar instruments, which are considered level 2 inputs. As of September 30, 2013, CVR Refining's biofuel blending obligation was fully committed. CVR Refining had no transfers of assets or liabilities between any of the above levels during the nine months ended September 30, 2013.

Derivative_Financial_Instrumen

Derivative Financial Instruments	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Financial Instruments	'
	Derivative Financial Instruments
	Gain (loss) on derivatives, net and current period settlements on derivative contracts were as follows:
		Three Months Ended September 30,					Nine Months Ended September 30,
		2013		2012			2013			2012
		(in millions)
	Current period settlements on derivative contracts	$	33.9	$	(53.2	)	$	(3.9	)	$	(80.4	)
	Gain (loss) on derivatives, net	$	72.5	$	(168.9	)	$	173		$	(277.4	)
	CVR Refining is subject to price fluctuations caused by supply conditions, weather, economic conditions and other factors. To manage price risk on crude oil and other inventories and to fix margins on certain future production, CVR Refining from time to time enters into various commodity derivative transactions.
	CVR Refining has adopted accounting standards which impose extensive record-keeping requirements in order to designate a derivative financial instrument as a hedge. CVR Refining holds derivative instruments, such as exchange-traded crude oil futures and certain over-the-counter forward swap agreements, which it believes provide an economic hedge on future transactions, but such instruments are not designated as hedges for GAAP purposes. Gains or losses related to the change in fair value and periodic settlements of these derivative instruments are classified as gain (loss) on derivatives, net in the Condensed Consolidated and Combined Statements of Operations. There are no premiums paid or received at inception of the derivative contracts and upon settlement, there is no cost recovery associated with these contracts.
	CVR Refining maintains a margin account to facilitate other commodity derivative activities. A portion of this account may include funds available for withdrawal. These funds are included in cash and cash equivalents within the Condensed Consolidated Balance Sheets. The maintenance margin balance is included within other current assets within the Condensed Consolidated Balance Sheets. Dependent upon the position of the open commodity derivatives, the amounts are accounted for as an other current asset or an other current liability within the Condensed Consolidated Balance Sheets. From time to time, CVR Refining may be required to deposit additional funds into this margin account. The fair value of the open commodity positions as of September 30, 2013 was an immaterial net loss included in accrued expenses and other current liabilities. For the three months ended September 30, 2013 and 2012, CVR Refining recognized a net gain of $0.1 million and a net loss of $7.1 million, respectively, which are recorded in gain (loss) on derivatives, net in the Condensed Consolidated and Combined Statements of Operations. For the nine months ended September 30, 2013 and 2012, CVR Refining recognized net losses of $2.3 million and $11.0 million, respectively, which are recorded in gain (loss) on derivatives, net in the Condensed Consolidated and Combined Statements of Operations.
	Commodity Swap
	CVR Refining enters into commodity swap contracts in order to fix the margin on a portion of future production. The physical volumes are not exchanged and these contracts are net settled with cash. The contract fair value of the commodity swaps is reflected on the Condensed Consolidated Balance Sheets with changes in fair value currently recognized in the Condensed Consolidated and Combined Statements of Operations. Quoted prices for similar assets or liabilities in active markets (Level 2) are considered to determine the fair values for the purpose of marking to market the hedging instruments at each period end. At September 30, 2013 and December 31, 2012, CVR Refining had open commodity hedging instruments consisting of 20.6 million barrels and 23.3 million barrels of crack spreads, respectively, primarily to fix the margin on a portion of its future gasoline and distillate production. The fair value of the outstanding contracts at September 30, 2013 was a net unrealized gain of $110.1 million, of which $101.9 million is included in current assets and $8.2 million is included in non-current assets. For the three months ended September 30, 2013 and 2012, CVR Refining recognized a net gain of $72.4 million and a net loss of $161.8 million, respectively, which are recorded in gain (loss) on derivatives, net in the Condensed Consolidated and Combined Statements of Operations. For the nine months ended September 30, 2013 and 2012, CVR Refining recognized a net gain of $175.3 million and a net loss of $266.4 million, respectively, which are recorded in gain (loss) on derivatives, net in the Condensed Consolidated and Combined Statements of Operations.
	Counterparty Credit Risk
	CVR Refining's exchange-traded crude oil futures and certain over-the-counter forward swap agreements are potentially exposed to concentrations of credit risk as a result of economic conditions and periods of uncertainty and illiquidity in the credit and capital markets. The Partnership manages credit risk on its exchange-traded crude oil futures by completing trades with an exchange clearinghouse, which subjects the trades to mandatory margin requirements until the contract settles. The Partnership also monitors the creditworthiness of its commodity swap counterparties and assesses the risk of nonperformance on a quarterly basis. Counterparty credit risk identified as a result of this assessment is recognized as a valuation adjustment to the fair value of the commodity swaps recorded in the Condensed Consolidated Balance Sheets. As of September 30, 2013, the counterparty credit risk adjustment was not material to the condensed consolidated and combined financial statements. Additionally, the Partnership does not require any collateral to support commodity swaps into which it enters; however, it does have master netting arrangements that allow for the setoff of amounts receivable from and payable to the same party, which mitigates the risk associated with nonperformance.
	Offsetting Assets and Liabilities
	The commodity swaps and other commodity derivatives agreements discussed above include multiple derivative positions with a number of counterparties for which CVR Refining has entered into agreements governing the nature of the derivative transactions. Each of the counterparty agreements provides for the right to setoff each individual derivative position to arrive at the net receivable due from the counterparty or payable owed by CVR Refining. As a result of the right to setoff, CVR Refining’s recognized assets and liabilities associated with the outstanding derivative positions have been presented net in the Condensed Consolidated Balance Sheets. In accordance with guidance issued by the FASB related to “Disclosures about Offsetting Assets and Liabilities,” the tables below outline the gross amounts of the recognized assets and liabilities and the gross amounts offset in the Condensed Consolidated Balance Sheets for the various types of open derivative positions.
	The offsetting assets and liabilities for CVR Refining’s derivatives as of September 30, 2013 are recorded as current assets and non-current assets in prepaid expenses and other current assets and other long-term assets, respectively, in the Condensed Consolidated Balance Sheets as follows:
		As of September 30, 2013
	Description	Gross Current Assets		Gross			Net			Cash			Net
				Amounts			Current Assets			Collateral			Amount
				Offset			Presented			Not Offset
		(in millions)
	Commodity Swaps	$	104.1	$	(2.2	)	$	101.9		$	—		$	101.9
	Total	$	104.1	$	(2.2	)	$	101.9		$	—		$	101.9
		As of September 30, 2013
	Description	Gross Non-Current Assets		Gross			Net			Cash			Net
				Amounts			Non-Current Assets			Collateral			Amount
				Offset			Presented			Not Offset
		(in millions)
	Commodity Swaps	$	8.2	$	—		$	8.2		$	—		$	8.2
	Total	$	8.2	$	—		$	8.2		$	—		$	8.2
	The offsetting assets and liabilities for CVR Refining’s derivatives as of December 31, 2012 are recorded as non-current assets in other long-term assets in the Condensed Consolidated Balance Sheets and as current liabilities in other current liabilities in the Condensed Consolidated Balance Sheets as follows:
		As of December 31, 2012
	Description	Gross Non-Current Assets		Gross			Net			Cash			Net
				Amounts			Non-Current Assets			Collateral			Amount
				Offset			Presented			Not Offset
		(in millions)
	Commodity Swaps	$	0.9	$	—		$	0.9		$	—		$	0.9
	Total	$	0.9	$	—		$	0.9		$	—		$	0.9
		As of December 31, 2012
	Description	Gross		Gross			Net			Cash			Net
		Current Liabilities		Amounts			Current Liabilities			Collateral			Amount
				Offset			Presented			Not Offset
		(in millions)
	Commodity Swaps	$	74.2	$	(6.5	)	$	67.7		$	—		$	67.7
	Total	$	74.2	$	(6.5	)	$	67.7		$	—		$	67.7

Allocation_of_Costs

Allocation of Costs	9 Months Ended
	Sep. 30, 2013
Allocation of Costs	'
Allocation of Costs	'
	Allocation of Costs
	Prior to the contribution of Refining LLC to the Partnership and entering into the services agreement with CVR Energy on December 31, 2012, certain expenses incurred by CVR Energy and its affiliates were only indirectly attributable to its ownership of the refining and related logistics assets of CRLLC. Accordingly, the historical combined financial statements for the three and nine months ended September 30, 2012 have been prepared in accordance with SAB Topic 1-B, as more fully explained in Note 2. These rules require allocations of costs for salaries and benefits, depreciation, rent, accounting and legal services, and other general and administrative expenses. CVR Energy and CRLLC allocated general and administrative expenses to CVR Refining based on allocation methodologies that management considers reasonable and result in an allocation of the historical cost of doing business borne by CVR Energy and CRLLC on behalf of CVR Refining. These allocations may not be indicative of the cost of future operations. For the three and nine months ended September 30, 2013, amounts incurred by CVR Energy and its affiliates on behalf of Partnership have been governed and billed in accordance with the services agreement entered into between the Partnership and CVR Energy on December 31, 2012 as more fully described in Note 16 ("Related Party Transaction").
	CVR Refining's Combined Statements of Operations for the three and nine months ended September 30, 2012 reflect all of the expenses that CRLLC and CVR Energy incurred on CVR Refining's behalf. CVR Refining's financial statements therefore include certain expenses incurred by CVR Energy and CRLLC which may include, but are not necessarily limited to, the following:
	• Officer and employee salaries and share-based compensation;
	• Rent or depreciation;
	• Advertising;
	• Accounting, tax, legal and information technology services;
	• Other selling, general and administrative expenses;
	• Costs for defined contribution plans, medical and other employee benefits; and
	• Financing costs, including interest and losses on extinguishment of debt.
	Selling, general and administrative expense allocations were based primarily on the nature of the expense incurred, with the exception of compensation and compensation related expenses. Compensation expenses, including share-based compensation, are allocated to CVR Refining as governed by percentages determined by management to be reasonable and in line with the nature of an individual's roles and responsibilities. Allocations related to share-based compensation are more fully described in Note 4 ("Share‑Based Compensation"). Cost allocations, either allocated or billed, of $3.0 million and $14.4 million were included in direct operating expenses (exclusive of depreciation and amortization) and selling, general and administrative expenses (exclusive of depreciation and amortization), respectively, for the three months ended September 30, 2012. Cost allocations, either allocated or billed, of $8.8 million and $48.9 million were included in direct operating expenses (exclusive of depreciation and amortization) and selling, general and administrative expenses (exclusive of depreciation and amortization), respectively, for the nine months ended September 30, 2012.

Related_Party_Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	In connection with the formation of CVR Refining in September 2012 and the Partnership’s Initial Public Offering in January 2013, CVR Refining and CRRM entered into certain agreements with CVR Energy and its subsidiaries that govern the business relations among CVR Refining, its general partner and CRRM on the one hand, and CVR Energy and its subsidiaries, on the other hand. CRRM has previously entered into other agreements with CVR Partners and its subsidiary. Certain of the agreements described below were amended and restated on April 13, 2011 in connection with the initial public offering of CVR Partners; the agreements are described as in effect at September 30, 2013. Amounts owed to CVR Refining and CRRM from CVR Energy and its subsidiaries with respect to these agreements are included in accounts receivable, prepaid expenses and other current assets, and other long-term assets, on the Condensed Consolidated Balance Sheets. Conversely, amounts owed to CVR Energy and its subsidiaries by CVR Refining and CRRM with respect to these agreements are included in accounts payable, accrued expenses and other current liabilities, long-term debt and other long-term liabilities, on CVR Refining’s Condensed Consolidated Balance Sheets.
	Feedstock and Shared Services Agreement
	CRRM entered into a feedstock and shared services agreement with CRNF under which the two parties provide feedstock and other services to one another. These feedstocks and services are utilized in the respective production processes of CRRM's Coffeyville, Kansas refinery and CRNF's nitrogen fertilizer plant.
	Pursuant to the feedstock agreement, CRRM and CRNF have the obligation to transfer excess hydrogen to one another. Net monthly sales of hydrogen to CRNF have been reflected as net sales for CVR Refining. Net monthly receipts of hydrogen from CRNF have been reflected in cost of product sold (exclusive of depreciation and amortization) for CVR Refining. For the three months ended September 30, 2013 and 2012, the net sales generated from the sale of hydrogen to CRNF were approximately $0.3 million and $0.1 million, respectively. For the nine months ended September 30, 2013 and 2012, the net sales generated from the sale of hydrogen to CRNF were approximately $0.6 million and $0.2 million, respectively. For the three months ended September 30, 2013 and 2012, CVR Refining also recognized $0.8 million and $0.3 million of cost of product sold (exclusive of depreciation and amortization) related to the purchase of excess hydrogen from the nitrogen fertilizer facility, respectively. For the nine months ended September 30, 2013 and 2012, CVR Refining also recognized $4.7 million and $6.0 million of cost of product sold (exclusive of depreciation and amortization) related to the purchase of excess hydrogen from the nitrogen fertilizer facility, respectively. At September 30, 2013 and December 31, 2012, there was approximately $0.8 million and $0.2 million, respectively, of payables included in accounts payable on the Condensed Consolidated Balance Sheets associated with unpaid balances related to hydrogen.
	The agreement provides that both parties must deliver high-pressure steam to one another under certain circumstances. Net reimbursed or (paid) direct operating expenses recorded during the three months ended September 30, 2013 and 2012 were approximately $(8,000) and $(2,000), respectively, related to high-pressure steam. Net reimbursed or (paid) direct operating expenses recorded during the nine months ended September 30, 2013 and 2012 were approximately $10,000 and $42,000, respectively, related to high-pressure steam. Reimbursements or paid amounts for each of the years on a gross basis were nominal.
	CRNF is also obligated to make available to CRRM any nitrogen produced by the Linde air separation plant that is not required for the operation of the nitrogen fertilizer plant, as determined by CRNF in a commercially reasonable manner. Direct operating expenses associated with nitrogen purchased by CRRM from CRNF for the three months ended September 30, 2013 and 2012, were approximately $0.1 million and $0.4 million, respectively. Direct operating expenses associated with nitrogen purchased by CRRM from CRNF for the nine months ended September 30, 2013 and 2012, were approximately $0.4 million and $1.3 million, respectively. No amounts were paid by CRNF to CRRM for any of the periods presented.
	The agreement also provides a mechanism pursuant to which CRNF transfers a tail gas stream to CRRM. For the three months ended September 30, 2013 and 2012, CRRM recognized approximately $0 and $0.1 million, respectively, of direct operating expenses generated from the purchase of tail gas from CRNF. For the nine months ended September 30, 2013 and 2012, CRRM recognized approximately $0.1 million and $0.2 million, respectively of direct operating expenses generated from the purchase of tail gas from CRNF.
	In April 2011, in connection with the tail gas stream, CRRM installed a pipe between the Coffeyville, Kansas refinery and the nitrogen fertilizer plant to transfer the tail gas. CRNF has agreed to pay CRRM the cost of installing the pipe over the next three years and in the fourth year provide an additional 15% to cover the cost of capital. At September 30, 2013 and December 31, 2012, an asset of approximately $0.4 million and $0.5 million, respectively, was included in other current assets and approximately $0.1 million and $0.4 million, respectively, was included in other non-current assets with an offset liability of approximately $0.2 million in other current liabilities and approximately $1.2 million and $1.3 million, respectively, in other non-current liabilities in the Condensed Consolidated Balance Sheets.
	CRNF also provided finished product tank capacity to CRRM under the agreement. Approximately $0.1 million and $0 was incurred by CRRM for the use of tank capacity for the three months ended September 30, 2013 and 2012. Approximately $0.3 million and $0.1 million, respectively, was incurred by CRRM for the use of tank capacity for the nine months ended September 30, 2013 and 2012, respectively. This expense was recorded as direct operating expenses.
	The agreement has an initial term of 20 years, which will be automatically extended for successive five year renewal periods. Either party may terminate the agreement, effective upon the last day of a term, by giving notice no later than three years prior to a renewal date. The agreement will also be terminable by mutual consent of the parties or if one party breaches the agreement and does not cure within applicable cure periods and the breach materially and adversely affects the ability of the terminating party to operate its facility. Additionally, the agreement may be terminated in some circumstances if substantially all of the operations at the nitrogen fertilizer plant or the Coffeyville, Kansas refinery are permanently terminated, or if either party is subject to a bankruptcy proceeding or otherwise becomes insolvent.
	At September 30, 2013 and December 31, 2012, payables of $0.1 million and $0.2 million, respectively, were included in accounts payable on the Condensed Consolidated Balance Sheets associated with amounts yet to be paid related to components of the feedstock and shared services agreement, other than amounts associated with hydrogen purchases. At September 30, 2013 and December 31, 2012, receivables of $0.8 million and $0.4 million, respectively, were included in prepaid expenses and other current assets on the Condensed Consolidated Balance Sheets associated with receivables related to components of the feedstock and shared services agreement.
	Coke Supply Agreement
	CRRM entered into a coke supply agreement with CRNF pursuant to which CRRM supplies CRNF with pet coke. This agreement provides that CRRM must deliver to CRNF during each calendar year an annual required amount of pet coke equal to the lesser of (i) 100 percent of the pet coke produced at CRRM’s Coffeyville, Kansas petroleum refinery or (ii) 500,000 tons of pet coke. CRNF is also obligated to purchase this annual required amount. If during a calendar month CRRM produces more than 41,667 tons of pet coke, then CRNF will have the option to purchase the excess at the purchase price provided for in the agreement. If CRNF declines to exercise this option, CRRM may sell the excess to a third party.
	The price CRNF pays pursuant to the pet coke supply agreement is based on the lesser of a pet coke price derived from the price received for urea ammonium nitrate (“UAN”), or the UAN-based price, and a pet coke price index. The UAN-based price begins with a pet coke price of $25 per ton based on a price per ton for UAN (exclusive of transportation cost), or netback price, of $205 per ton, and adjusts up or down $0.50 per ton for every $1.00 change in the netback price. The UAN-based price has a ceiling of $40 per ton and a floor of $5 per ton.
	CRNF pays any taxes associated with the sale, purchase, transportation, delivery, storage or consumption of the pet coke. Amounts payable under the feedstock and shared services agreements can be offset with any amount receivable for pet coke.
	The agreement has an initial term of 20 years and will be automatically extended for successive five year renewal periods. Either party may terminate the agreement by giving notice no later than three years prior to a renewal date. The agreement is also terminable by mutual consent of the parties or if a party breaches the agreement and does not cure within applicable cure periods. Additionally, the agreement may be terminated in some circumstances if substantially all of the operations at the nitrogen fertilizer plant or the Coffeyville, Kansas refinery are permanently terminated, or if either party is subject to a bankruptcy proceeding or otherwise becomes insolvent.
	Net sales associated with the transfer of pet coke from CRRM to CRNF were approximately $1.7 million and $2.4 million for the three months ended September 30, 2013 and 2012, respectively. Net sales associated with the transfer of pet coke from CRRM to CRNF were approximately $7.0 million and $7.3 million for the nine months ended September 30, 2013 and 2012, respectively. Receivables of $0.3 million and $0.6 million related to the coke supply agreement were included in accounts receivable on the Condensed Consolidated Balance Sheets at September 30, 2013 and December 31, 2012, respectively.
	Terminal Operating and Lease Agreement
	On May 4, 2012, CRT entered into an operating and lease agreement with CRNF, under which it leases premises to CRNF located at Phillipsburg, Kansas, which CRNF uses as a UAN terminal. The initial term of the agreement will expire in May 2032, provided, however, that CRNF may terminate the lease at any time during the initial term by providing 180 days prior written notice. In addition, this agreement will automatically renew for successive five-year terms, provided that CRNF may terminate the agreement during any renewal term with at least 180 days written notice. CRNF will pay CRT $1.00 per year for rent, $4.00 per ton of UAN placed into the terminal and $4.00 per ton of UAN taken out of the terminal. For the three and nine months ended September 30, 2013, revenue related to the terminal operating and lease agreement totaled approximately $28,000 and $83,000, respectively. For each of the three and nine months ended September 30, 2012, revenue totaled approximately $12,000.
	Lease Agreement
	CRRM entered into a lease agreement with CRNF under which CRNF leases certain office and laboratory space. The initial term of the lease will expire in October 2017, provided, however, that CRNF may terminate the lease at any time during the initial term by providing 180 days prior written notice. In addition, CRNF has the option to renew the lease agreement for up to five additional one-year periods by providing CRRM with notice of renewal at least 60 days prior to the expiration of the then existing term. For the three months ended September 30, 2013 and 2012, amounts received related to the use of the office and laboratory space totaled approximately $27,000 and $26,000 For each of the nine months ended September 30, 2013 and 2012, amounts received related to the use of the office and laboratory space totaled approximately $0.1 million.
	Environmental Agreement
	CRRM entered into an environmental agreement with CRNF which provides for certain indemnification and access rights in connection with environmental matters affecting the Coffeyville, Kansas refinery and the nitrogen fertilizer plant. Generally, both CRRM and CRNF have agreed to indemnify and defend each other and each other's affiliates against liabilities associated with certain hazardous materials and violations of environmental laws that are a result of or caused by the indemnifying party's actions or business operations. This obligation extends to indemnification for liabilities arising out of off-site disposal of certain hazardous materials. Indemnification obligations of the parties will be reduced by applicable amounts recovered by an indemnified party from third parties or from insurance coverage.
	The agreement provides for indemnification in the case of contamination or releases of hazardous materials that were present but unknown at the time the agreement was entered into to the extent such contamination or releases were identified in reasonable detail through October 2012. The agreement further provides for indemnification in the case of contamination or releases which occur subsequent to the execution of the agreement.
	The term of the agreement is for at least 20 years, or for so long as the feedstock and shared services agreement is in force, whichever is longer.
	Services Agreement
	On December 31, 2012, CVR Refining entered into a services agreement with CVR Energy. CVR Refining obtains certain management and other services from CVR Energy pursuant to a services agreement between the Partnership, CVR Refining GP and CVR Energy. Under this agreement, the Partnership's general partner has engaged CVR Energy to conduct a substantial portion of its day-to-day business operations. CVR Energy provides CVR Refining with the following services under the agreement, among others:
	•	services from CVR Energy's employees in capacities equivalent to the capacities of corporate executive officers, except that those who serve in such capacities under the agreement shall serve the Partnership on a shared, part-time basis only, unless the Partnership and CVR Energy agree otherwise;
	•	administrative and professional services, including legal, accounting services, human resources, insurance, tax, credit, finance, government affairs and regulatory affairs;
	•	management of the Partnership's property and the property of its operating subsidiaries in the ordinary course of business;
	•	recommendations on capital raising activities to the board of directors of the Partnership's general partner, including the issuance of debt or equity interests, the entry into credit facilities and other capital market transactions;
	•	managing or overseeing litigation and administrative or regulatory proceedings, establishing appropriate insurance policies for the Partnership and providing safety and environmental advice;
	•	recommending the payment of distributions; and
	•	managing or providing advice for other projects, including acquisitions, as may be agreed by CVR Energy and the Partnership's general partner from time to time.
	As payment for services provided under the agreement, the Partnership, its general partner or subsidiaries must pay CVR Energy (i) all costs incurred by CVR Energy or its affiliates in connection with the employment of its employees, other than administrative personnel, who provide the Partnership services under the agreement on a full-time basis, but excluding share-based compensation; (ii) a prorated share of costs incurred by CVR Energy or its affiliates in connection with the employment of its employees, including administrative personnel, who provide the Partnership services under the agreement on a part-time basis, but excluding share-based compensation, and such prorated share shall be determined by CVR Energy on a commercially reasonable basis, based on the percentage of total working time that such shared personnel are engaged in performing services for the Partnership; (iii) a prorated share of certain administrative costs, including office costs, services by outside vendors, other sales, general and administrative costs and depreciation and amortization; and (iv) various other administrative costs in accordance with the terms of the agreement, including travel, insurance, legal and audit services, government and public relations and bank charges.
	Either CVR Energy or the Partnership's general partner may temporarily or permanently exclude any particular service from the scope of the agreement upon 180 days' notice. Beginning in January 2014, either CVR Energy or the Partnership's general partner may terminate the agreement upon at least 180 days' notice, but not more than one year's notice. Furthermore, the Partnership's general partner may terminate the agreement immediately if CVR Energy becomes bankrupt or dissolves or commences liquidation or winding-up procedures.
	In order to facilitate the carrying out of services under the agreement, CVR Refining and CVR Energy have granted one another certain royalty-free, non-exclusive and non-transferable rights to use one another's intellectual property under certain circumstances.
	The agreement also contains an indemnity provision whereby the Partnership, its general partner, and its subsidiaries, as indemnifying parties, agree to indemnify CVR Energy and its affiliates (other than the indemnifying parties themselves) against losses and liabilities incurred in connection with the performance of services under the agreement or any breach of the agreement, unless such losses or liabilities arise from a breach of the agreement by CVR Energy or other misconduct on its part, as provided in the agreement. The agreement contains a provision stating that CVR Energy is an independent contractor under the agreement and nothing in the agreement may be construed to impose an implied or express fiduciary duty owed by CVR Energy, on the one hand, to the recipients of services under the agreement, on the other hand. The agreement prohibits recovery of lost profits or revenue, or special, incidental, exemplary, punitive or consequential damages from CVR Energy or certain affiliates, except in cases of gross negligence, willful misconduct, bad faith, reckless disregard in performance of services under the agreement, or fraudulent or dishonest acts.
	Net amounts incurred under the services agreement for the three months ended September 30, 2013 were approximately $22.0 million. Of these charges approximately $15.4 million were included in selling, general and administrative expenses (exclusive of depreciation and amortization). In addition, $6.6 million were included in direct operating expenses (exclusive of depreciation and amortization). Net amounts incurred under the services agreement for the nine months ended September 30, 2013 were approximately $64.5 million. Of these charges approximately $45.4 million were included in selling, general and administrative expenses (exclusive of depreciation and amortization). In addition, $19.1 million were included in direct operating expenses (exclusive of depreciation and amortization). At September 30, 2013, payables of $12.6 million were included in accounts payable on the Condensed Consolidated Balance Sheets with respect to amounts billed in accordance with the services agreement. See Note 15 ("Allocation of Costs") for costs allocated to CVR Refining for the three and nine months ended September 30, 2012 prior to this services agreement going into effect on December 31, 2012.
	Limited Partnership Agreement
	In connection with the Initial Public Offering, CVR Refining GP and CVR Refining Holdings entered into the first amended and restated agreement of limited partnership of the Partnership, dated January 23, 2013.
	The Partnership's general partner manages the Partnership's operations and activities as specified in the partnership agreement. The general partner of the Partnership is managed by its board of directors. CVR Refining Holdings has the right to select the directors of the general partner. Actions by the general partner that are made in its individual capacity are made by CVR Refining Holdings as the sole member of the general partner and not by its board of directors. The members of the board of directors of the general partner are not elected by the unitholders and are not subject to re-election on a regular basis by the unitholders. The officers of the general partner manage the day-to-day affairs of the Partnership's business.
	The partnership agreement provides that the Partnership will reimburse its general partner for all direct and indirect expenses it incurs or payments it makes on behalf of the Partnership (including salary, bonus, incentive compensation and other amounts paid to any person to perform services for the Partnership or for its general partner in connection with operating the Partnership). For the three and nine months ended September 30, 2013, approximately $0.1 million and $0.2 million, respectively, was incurred under the partnership agreement.
	Intercompany Credit Facility
	On January 23, 2013, prior to the closing of the Initial Public Offering, the Partnership entered into a $150.0 million intercompany credit facility, with CRLLC as the lender, to be used to fund growth capital expenditures. The intercompany credit facility is for a term of six years and bears interest at a rate of LIBOR plus 3% per annum. As of September 30, 2013, the Partnership had borrowings of $11.5 million outstanding. See Note 8 ("Long-Term Debt") for additional discussion of the intercompany credit facility.
	Insight Portfolio Group
	Insight Portfolio Group LLC (“Insight Portfolio Group”) is an entity formed by Mr. Icahn in order to maximize the potential buying power of a group of entities with which Mr. Icahn has a relationship in negotiating with a wide range of suppliers of goods, services and tangible and intangible property at negotiated rates. In January 2013, CVR Energy acquired a minority equity interest in Insight Portfolio Group. The Partnership participates in Insight Portfolio Group’s buying group through its relationship with CVR Energy. The Partnership may purchase a variety of goods and services as members of the buying group at prices and on terms that management believes would be more favorable than those which would be achieved on a stand-alone basis.
	International Truck Purchase
	During the three months ended September 30, 2013, the Partnership purchased seven trucks from a subsidiary of Navistar International Corporation ("Navistar") for approximately $0.8 million. Mr. Icahn, CVR Energy's majority stockholder, indirectly owns approximately 17% of Navistar's outstanding common stock.

Subsequent_Events

Subsequent Events	9 Months Ended
	Sep. 30, 2013
Subsequent Events [Abstract]	'
Subsequent Events	'
	Subsequent Events
	Distribution
	On October 31, 2013, the board of directors of the Partnership’s general partner declared a cash distribution for the third quarter of 2013 to the Partnership’s unitholders of $0.30 per common unit or $44.3 million in aggregate. The cash distribution will be paid on November 18, 2013 to unitholders of record at the close of business on November 11, 2013.

Inventories_Tables

Inventories (Tables)	9 Months Ended
	Sep. 30, 2013
Inventory Disclosure [Abstract]	'
Schedule of inventories	'
	Inventories consisted of the following:
		September 30,		December 31,
		2013		2012
		(in millions)
	Finished goods	$	353.8	$	269.5
	Raw materials and precious metals	185.6		158.1
	In-process inventories	78.5		42.7
	Parts and supplies	29.4		29.2
		$	647.3	$	499.5

Property_Plant_and_Equipment_T

Property, Plant, and Equipment (Tables)	9 Months Ended
	Sep. 30, 2013
Property, Plant and Equipment [Abstract]	'
Summary of costs for property, plant, and equipment	'
	A summary of costs for property, plant, and equipment is as follows:
		September 30, 2013		December 31, 2012
		(in millions)
	Land and improvements	$	24.8	$	24
	Buildings	38.2		36.7
	Machinery and equipment	1,739.60		1,685.60
	Automotive equipment	16		14.3
	Furniture and fixtures	6.7		6.2
	Leasehold improvements	0.8		0.8
	Construction in progress	116.3		46
		1,942.40		1,813.60
	Accumulated depreciation	546.8		462
	Total property, plant and equipment, net	$	1,395.60	$	1,351.60

LongTerm_Debt_Tables

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]	'
Schedule of long-term debt	'
	Long-term debt was as follows:
		September 30, 2013		December 31, 2012
		(in millions)
	10.875% Senior Secured Notes, due 2017, net of unamortized discount of $1.8 million as December 31, 2012	$	—	$	220.9
	6.5% Senior Notes, due 2022	500		500
	Intercompany credit facility	11.5		—
	Capital lease obligations	50.2		51.2
	Long-term debt	$	561.7	$	772.1

Partners_Capital_and_Partnersh1

Partners' Capital and Partnership Distributions (Tables)	9 Months Ended
	Sep. 30, 2013
Equity [Abstract]	'
Schedule of Distributions Made to Members or Limited Partners, by Distribution	'
	The following is a summary of cash distributions paid to the Partnership’s unitholders during 2013 for the respective quarters to which the distributions relate:
		March 31, 2013(1)		30-Jun-13		Total Cash
						Distributions
						Paid in 2013
		(in millions, expect per common unit amounts)
	Amount paid to CVR Refining Holdings, LLC and affiliates	$	195.9	$	149.6	$	345.5
	Amounts paid to non-affiliates	37.3		49.7		87
	Total amount paid	$	233.2	$	199.3	$	432.5
	Per common unit	$	1.58	$	1.35	$	2.93
	Common units outstanding	147.6		147.6
	-1	The distribution for the period ended March 31, 2013 was adjusted to exclude the period from January 1, 2013 through January 22, 2013 (the period preceding the closing of the Initial Public Offering).

Net_Income_per_Common_Unit_Tab

Net Income per Common Unit (Tables)	9 Months Ended
	Sep. 30, 2013
Earnings Per Share [Abstract]	'
Schedule of computations of the basic and diluted earnings per share	'
	The following table illustrates the Partnership's calculation of net income per common unit:
		Three Months Ended		January 23, 2013 to
		September 30, 2013		30-Sep-13
		(in millions, except per unit data)
	Net income (from the closing of the offering on January 23, 2013 to September 30, 2013)	$	86	$	622.8
	Net income per common unit, basic	$	0.58	$	4.22
	Net income per common unit, diluted	$	0.58	$	4.22
	Weighted-average common units outstanding, basic	147.6		147.6
	Weighted-average common units outstanding, diluted	147.6		147.6

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	9 Months Ended
	Sep. 30, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of minimum required payments for CVR Refining's operating lease agreements and unconditional purchase obligations	'
	The minimum required payments for CVR Refining’s operating lease agreements and unconditional purchase obligations are as follows:
		Operating		Unconditional
		Leases		Purchase Obligations(1)
		(in millions)
	Three months ending December 31, 2013	$	0.7	$	82.7
	Year Ending December 31,
	2014	2.3		108.5
	2015	1.4		96.7
	2016	1		89.6
	2017	0.3		88.4
	Thereafter	0.3		940.7
		$	6	$	1,406.60
	(1) This amount includes approximately $965.5 million payable ratably over eighteen years pursuant to petroleum transportation service agreements between CRRM and TransCanada Keystone Pipeline, LP (“TransCanada”). Under the agreements, CRRM receives transportation of at least 25,000 barrels per day of crude oil with a delivery point at Cushing, Oklahoma for a term of twenty years on TransCanada’s Keystone pipeline system. CRRM began receiving crude oil under the agreements in the first quarter of 2011.
Schedule of accrual for environmental loss contingencies	'
	The estimated future payments for these required obligations are as follows:
		Amount
		(in millions)
	Three months ending December 31, 2013	$	0.2
	Year Ending December 31,
	2014	0.4
	2015	0.2
	2016	0.1
	2017	0.1
	Thereafter	1.1
	Undiscounted total	2.1
	Less amounts representing interest at 2.34%	0.3
	Accrued environmental liabilities at September 30, 2013	$	1.8

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]	'
Schedule of assets and liabilities measured at fair value on a recurring basis	'
	The following table sets forth the assets and liabilities measured at fair value on a recurring basis, by input level, as of September 30, 2013 and December 31, 2012:
		September 30, 2013
		Level 1		Level 2			Level 3		Total
		(in millions)
	Location and Description
	Other current assets (derivative agreements)	$	—	$	101.9		$	—	$	101.9
	Other long-term assets (derivative agreements)	—		8.2			—		8.2
	Total Assets	$	—	$	110.1		$	—	$	110.1
		December 31, 2012
		Level 1		Level 2			Level 3		Total
		(in millions)
	Location and Description
	Other long-term assets (derivative agreements)	$	—	$	0.9		$	—	$	0.9
	Total Assets	$	—	$	0.9		$	—	$	0.9
	Other current liabilities (derivative agreements)	—		(67.7		)	—		(67.7		)
	Other current liabilities (biofuel blending obligation)	—		(1.1		)	—		(1.1		)
	Total Liabilities	$	—	$	(68.8	)	$	—	$	(68.8	)

Derivative_Financial_Instrumen1

Derivative Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Components of gain (loss) on derivatives, net	'
	Gain (loss) on derivatives, net and current period settlements on derivative contracts were as follows:
		Three Months Ended September 30,					Nine Months Ended September 30,
		2013		2012			2013			2012
		(in millions)
	Current period settlements on derivative contracts	$	33.9	$	(53.2	)	$	(3.9	)	$	(80.4	)
	Gain (loss) on derivatives, net	$	72.5	$	(168.9	)	$	173		$	(277.4	)
Schedule of offsetting assets recorded as current assets and non-current assets in prepaid expenses and other current assets and other long-term assets in the Condensed Consolidated Balance Sheets	'
	The offsetting assets and liabilities for CVR Refining’s derivatives as of September 30, 2013 are recorded as current assets and non-current assets in prepaid expenses and other current assets and other long-term assets, respectively, in the Condensed Consolidated Balance Sheets as follows:
		As of September 30, 2013
	Description	Gross Current Assets		Gross			Net			Cash			Net
				Amounts			Current Assets			Collateral			Amount
				Offset			Presented			Not Offset
		(in millions)
	Commodity Swaps	$	104.1	$	(2.2	)	$	101.9		$	—		$	101.9
	Total	$	104.1	$	(2.2	)	$	101.9		$	—		$	101.9
		As of September 30, 2013
	Description	Gross Non-Current Assets		Gross			Net			Cash			Net
				Amounts			Non-Current Assets			Collateral			Amount
				Offset			Presented			Not Offset
		(in millions)
	Commodity Swaps	$	8.2	$	—		$	8.2		$	—		$	8.2
	Total	$	8.2	$	—		$	8.2		$	—		$	8.2
		As of December 31, 2012
	Description	Gross Non-Current Assets		Gross			Net			Cash			Net
				Amounts			Non-Current Assets			Collateral			Amount
				Offset			Presented			Not Offset
		(in millions)
	Commodity Swaps	$	0.9	$	—		$	0.9		$	—		$	0.9
	Total	$	0.9	$	—		$	0.9		$	—		$	0.9
Schedule of offsetting liabilities recorded as current liabilities in other current liabilities in the Condensed Consolidated Balance Sheet	'
		As of December 31, 2012
	Description	Gross		Gross			Net			Cash			Net
		Current Liabilities		Amounts			Current Liabilities			Collateral			Amount
				Offset			Presented			Not Offset
		(in millions)
	Commodity Swaps	$	74.2	$	(6.5	)	$	67.7		$	—		$	67.7
	Total	$	74.2	$	(6.5	)	$	67.7		$	—		$	67.7

Formation_of_the_Partnership_O1

Formation of the Partnership, Organization and Nature of Business (Details) (USD $)

2 Months Ended

3 Months Ended

4 Months Ended

8 Months Ended

9 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

0 Months Ended

4 Months Ended

0 Months Ended

9 Months Ended

0 Months Ended

4 Months Ended

9 Months Ended

In Millions, except Share data, unless otherwise specified

Mar. 31, 2013

Jun. 30, 2013

19-May-13

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Jan. 30, 2013

Jan. 30, 2013

Jan. 23, 2013

Dec. 31, 2012

Jun. 10, 2013

20-May-13

Jan. 23, 2013

Apr. 06, 2010

Jan. 23, 2013

19-May-13

Sep. 30, 2013

Jan. 23, 2013

Dec. 31, 2012

Jan. 23, 2013

20-May-13

Apr. 18, 2012

Sep. 30, 2013

Dec. 31, 2012

29-May-13

19-May-13

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Initial Public Offering

Initial Public Offering

Initial Public Offering

Initial Public Offering

Underwritten Offering

Underwritten Offering

10.875% senior secured notes due 2017

10.875% senior secured notes due 2017

10.875% senior secured notes due 2017

Affiliate of Icahn Enterprises

Affiliate of Icahn Enterprises

CRLLC

CRLLC

CRLLC

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Refining Holdings

CVR Refining Holdings

CVR Refining Holdings

CVR Refining Holdings

Initial Public Offering

Initial Public Offering

Underwritten Offering

Offer

Icahn Enterprises, LP

CVR Partners

Affiliate of Icahn Enterprises

Refining LLC

CVR Refining GP, LLC

payment

Minimum

Underwritten Offering

Percentage of membership interest in other entity transferred by limited partner

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

Percentage of membership interest in other entity transferred by limited partner

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

Limited partner interest (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

81.00%

71.00%

'

'

Ownership percentage held by controlling stockholder

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

82.00%

'

'

'

'

'

'

Number of partnership units sold in offering (in shares)

'

'

'

'

'

'

3,600,000

'

24,000,000

'

1,209,236

12,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Offering price per unit (in dollars per share)

'

'

'

'

'

'

$25

'

$25

'

$30.75

$30.75

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of partnership units sold in privately negotiated transaction (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,000,000

'

'

'

'

Net proceeds from offering

'

'

'

'

'

'

'

$653.60

'

'

'

$394

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of partnership units redeemed (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

13,209,236

'

'

'

'

'

'

'

'

Ownership interest (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

Proceeds from initial public offering used to repurchase CRLLC's 10.875% senior secured notes due 2017

'

'

'

'

'

'

'

'

'

'

'

'

253

'

253

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stated interest rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

10.88%

10.88%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from initial public offering used to fund the turnaround expenses

'

'

'

'

'

'

'

'

'

54

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from initial public offering used for distributions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

85.1

'

'

'

'

'

'

'

'

'

Proceeds from initial public offering used to prefund certain maintenance and environmental capital expenditures through 2014

'

'

'

'

'

'

'

'

160

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from initial public offering allocated to be utilized for general corporate purposes

'

'

'

'

'

'

'

'

101.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash on hand distributed

$233.20

[1]

$199.30

'

'

$432.50

'

'

'

'

'

'

'

'

'

'

'

'

$150

'

'

'

'

'

'

'

'

'

'

'

Percentage of limited partner interest held by the public

'

'

19.00%

29.00%

'

'

'

'

'

'

'

'

'

'

'

3.00%

4.00%

'

'

'

'

'

'

'

'

'

'

'

'

Price per share of common stock offered in tender offer (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$30

'

'

'

'

'

'

'

Number of Non Transferable Contingent Cash Payments Right for Each Share

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

Maximum period after the end of each quarter of cash distribution to common unitholders

'

'

'

'

'

'60 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of common units owned by managing partner

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

[1]

The distribution for the period ended March 31, 2013 was adjusted to exclude the period from January 1, 2013 through January 22, 2013 (the period preceding the closing of the Initial Public Offering).

ShareBased_Compensation_Detail

Share-Based Compensation (Details) (USD $)

9 Months Ended

9 Months Ended

0 Months Ended

1 Months Ended

3 Months Ended

9 Months Ended

1 Months Ended

3 Months Ended

9 Months Ended

Sep. 30, 2013

Sep. 30, 2013

Jan. 16, 2013

Sep. 30, 2013

Sep. 30, 2012

31-May-12

Dec. 31, 2012

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

CVR Refining LTIP

CVR Refining LTIP

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy LTIP

CVR Energy LTIP

CVR Energy LTIP

CVR Energy LTIP

CVR Energy LTIP

CVR Energy LTIP

CVR Energy LTIP

CVR Energy LTIP

CVR Energy LTIP

CVR Energy LTIP

CVR Energy LTIP

CVR Energy LTIP

Restricted Shares

Restricted Shares

Restricted Shares

Restricted stock units

Restricted stock units

Restricted stock units

Restricted stock units

Restricted stock units

Restricted stock units

Restricted stock units

Restricted stock units

Restricted stock units

payment

Executive officers

Mr. Lipinski

Mr. Lipinski

Share-Based Compensation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of allocation of share-based compensation expense

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Vesting period

'

'

'

'3 years

'

'

'

'3 years

'

'

'

'

'1 year

'

'

Offer price per share received as cash settlement on restricted stock awards vested (in dollars per share)

'

'

'

'

'

$30

'

'

'

'

'

'

'

'

'

Number of non-transferable contingent cash payments right for each share

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

Additional share-based compensation as a result of the modification

'

'

'

'

$6,300,000

'

'

'

'

'

'

'

'

'

'

Number of shares considered for determining cash payment for each award upon vesting

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

Award vesting percentage

'

'

'

'

'

'

33.00%

'

'

'

'

'

'

'

'

Granted (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

62,920

Compensation expenses

'

'

'

'

'

'

'

'

2,100,000

4,900,000

8,300,000

15,600,000

'

0

0

Unrecognized compensation cost

'

'

'

'

'

'

'

'

$6,200,000

'

$6,200,000

'

'

'

'

Weighted-average period for amortization of unrecognized compensation cost

'

'

'

'

'

'

'

'

'

'

'9 months 0 days

'

'

'

'

Maximum number of common units issuable under the plan (in shares)

'

'

11,070,000

'

'

'

'

'

'

'

'

'

'

'

'

Awards granted under the plan

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

Inventories_Details

Inventories (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Inventory Disclosure [Abstract]	'	'
Finished goods	$353.80	$269.50
Raw materials and precious metals	185.6	158.1
In-process inventories	78.5	42.7
Parts and supplies	29.4	29.2
Inventories	$647.30	$499.50

Property_Plant_and_Equipment_D

Property, Plant, and Equipment (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Property, Plant, and Equipment	'	'	'	'	'
Gross property, plant and equipment	$1,942.40	'	$1,942.40	'	$1,813.60
Accumulated depreciation	546.8	'	546.8	'	462
Total property, plant and equipment, net	1,395.60	'	1,395.60	'	1,351.60
Capitalized interest	0.7	1.8	1.7	3	'
Original carrying value of assets under capital lease obligations	24.8	'	24.8	'	24.8
Land and improvements	'	'	'	'	'
Property, Plant, and Equipment	'	'	'	'	'
Gross property, plant and equipment	24.8	'	24.8	'	24
Buildings	'	'	'	'	'
Property, Plant, and Equipment	'	'	'	'	'
Gross property, plant and equipment	38.2	'	38.2	'	36.7
Machinery and equipment	'	'	'	'	'
Property, Plant, and Equipment	'	'	'	'	'
Gross property, plant and equipment	1,739.60	'	1,739.60	'	1,685.60
Automotive equipment	'	'	'	'	'
Property, Plant, and Equipment	'	'	'	'	'
Gross property, plant and equipment	16	'	16	'	14.3
Furniture and fixtures	'	'	'	'	'
Property, Plant, and Equipment	'	'	'	'	'
Gross property, plant and equipment	6.7	'	6.7	'	6.2
Leasehold improvements	'	'	'	'	'
Property, Plant, and Equipment	'	'	'	'	'
Gross property, plant and equipment	0.8	'	0.8	'	0.8
Construction in progress	'	'	'	'	'
Property, Plant, and Equipment	'	'	'	'	'
Gross property, plant and equipment	$116.30	'	$116.30	'	$46

Cost_Classifications_Details

Cost Classifications (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Costs and Expenses [Abstract]	'	'	'	'
Depreciation and amortization not included in cost of product sold	$1.20	$1	$3.50	$2.50
Depreciation and amortization not included in direct operating expenses	27.5	26.4	81.4	77.4
Depreciation and amortization not included in selling, general and administrative expenses	$0.10	$0.10	$0.30	$0.50

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)

3 Months Ended

9 Months Ended

9 Months Ended

0 Months Ended

9 Months Ended

0 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

3 Months Ended

9 Months Ended

9 Months Ended

0 Months Ended

9 Months Ended

9 Months Ended

0 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Jan. 23, 2013

Sep. 30, 2013

Dec. 31, 2012

Apr. 06, 2010

Apr. 06, 2010

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Oct. 23, 2012

Sep. 30, 2013

Nov. 23, 2012

Oct. 23, 2012

Dec. 31, 2012

Apr. 06, 2010

Dec. 15, 2011

Dec. 15, 2011

Sep. 30, 2013

Dec. 20, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Jan. 23, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Jan. 23, 2013

Jan. 23, 2013

Refining LLC

10.875% senior secured notes due 2017

10.875% senior secured notes due 2017

10.875% senior secured notes due 2017

10.875% senior secured notes due 2017

10.875% senior secured notes due 2017

6.5% Second Lien Senior Secured Notes, due 2022

6.5% Second Lien Senior Secured Notes, due 2022

6.5% Second Lien Senior Secured Notes, due 2022

6.5% Second Lien Senior Secured Notes, due 2022

6.5% Second Lien Senior Secured Notes, due 2022

First Lien Notes

First Lien Notes

First Lien Notes

Original Notes

Additional First Lien Notes

Additional First Lien Notes

Amended and Restated ABL Credit Facility

Amended and Restated ABL Credit Facility

Amended and Restated ABL Credit Facility

Amended and Restated ABL Credit Facility

Amended and Restated ABL Credit Facility

Amended and Restated ABL Credit Facility

Amended and Restated ABL Credit Facility

Amended and Restated ABL Credit Facility

Amended and Restated ABL Credit Facility

Amended and Restated ABL Credit Facility

Amended and Restated ABL Credit Facility

Amended and Restated ABL Credit Facility

Intercompany credit facility

Intercompany credit facility

Intercompany credit facility

Intercompany credit facility

CRLLC

CRLLC and Coffeyville Finance Inc. (Issuers)

Refining LLC

Refining LLC

CRLLC

CRLLC

CRLLC

CRLLC and Coffeyville Finance Inc. (Issuers)

CRLLC and Coffeyville Finance Inc. (Issuers)

CRLLC and Coffeyville Finance Inc. (Issuers)

Credit Parties

Credit Parties

Credit Parties

Credit Parties

Credit Parties

Credit Parties

Credit Parties

Credit Parties

Credit Parties

Credit Parties

Credit Parties

Credit Parties

CRLLC

CRLLC

Intercompany credit facility

Quarterly Average Excess Availability Exceeding 50% Of Lesser Of Borrowing Base And Total Commitments

Quarterly Average Excess Availability Less Than Or Equal To 50% Of Lesser Of Borrowing Base And Total Commitments

Daily Average Amount Of Loans And Letters Of Credit Outstanding Less Than 50% Of Lesser Of Borrowing Base And Total Commitments

Daily Average Amount Of Loans And Letters Of Credit Outstanding Equal To Or Greater Than 50% Of Lesser Of Borrowing Base And Total Commitments

LIBOR

LIBOR

LIBOR

Prime

Prime

Prime

Minimum

Quarterly Average Excess Availability Exceeding 50% Of Lesser Of Borrowing Base And Total Commitments

Quarterly Average Excess Availability Less Than Or Equal To 50% Of Lesser Of Borrowing Base And Total Commitments

Quarterly Average Excess Availability Exceeding 50% Of Lesser Of Borrowing Base And Total Commitments

Quarterly Average Excess Availability Less Than Or Equal To 50% Of Lesser Of Borrowing Base And Total Commitments

Long-Term Debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt

$561,700,000

'

$561,700,000

'

$772,100,000

'

'

$0

$220,900,000

'

'

$500,000,000

$500,000,000

$500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest in subsidiary (as a percent)

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowings outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

11,500,000

0

11,500,000

'

'

Capital lease obligations

50,200,000

'

50,200,000

'

51,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unamortized discount

'

'

'

'

'

'

'

'

1,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stated interest rate (as a percent)

'

'

'

'

'

'

10.88%

'

'

10.88%

'

'

'

'

6.50%

'

'

'

'

9.00%

9.00%

9.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate principal amount

'

'

'

'

'

'

'

'

'

'

225,000,000

'

'

'

500,000,000

'

'

'

'

275,000,000

200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issue price as a percentage of principal amount

'

'

'

'

'

'

'

'

'

'

98.81%

'

'

'

'

'

'

'

'

99.51%

105.00%

105.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued interest payable

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from IPO to be utilized for repurchase of debt

'

'

'

'

'

'

253,000,000

'

'

'

'

'

'

'

'

'

'

348,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Face amount of debt repurchased

'

'

'

'

'

'

222,800,000

'

'

'

'

'

'

'

'

'

124,100,000

323,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unamortized premium

'

'

'

'

'

'

20,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest paid upon settlement

'

'

'

'

'

'

9,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss on extinguishment of debt

0

0

26,100,000

0

'

'

'

26,100,000

'

'

'

'

'

'

'

'

'

'

33,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Write-off of previously deferred financing charges

'

'

'

'

'

'

'

3,700,000

'

'

'

'

'

'

'

'

'

'

8,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unamortized discount written off

'

'

'

'

'

'

'

1,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total net proceeds from the offering

'

'

'

'

'

'

'

'

'

'

'

'

'

'

492,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt registration costs incurred

'

'

'

'

'

'

'

'

'

'

'

100,000

400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued interest settled on redemption

'

'

32,500,000

36,500,000

'

'

'

'

'

'

'

'

'

'

'

'

1,600,000

1,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Prepayment Premium

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,400,000

23,200,000

31,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Portion of unamortized premium written off

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred finance costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,700,000

'

'

'

'

'

'

'

2,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated fair value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

485,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

400,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

150,000,000

Letter of credit sublimit as a percentage of the total facility commitment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

90.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum borrowing capacity optional expansion

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Swingline loans sublimit as a percentage of the total facility commitment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Variable rate basis

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'LIBOR

'

'

'Prime Rate

'

'

'

'

'LIBOR

'

'LIBOR

Basis spread on variable rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.75%

2.00%

'

0.75%

1.00%

'

'

'

'

3.00%

Percentage threshold of borrowing base and total commitments for determination of interest rate on borrowings

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Unused line fee (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.40%

0.30%

'

'

'

'

'

'

'

'

'

'

'

Percentage threshold of borrowing base and total commitments for determination of unused capacity commitment fee

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

50.00%

'

'

'

'

'

'

'

'

'

'

'

Percentage of deduction of maximum amount available to be drawn under line of credit to compute fees on commercial letters of credit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of customary facing fees

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.13%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unamortized deferred cost at the time of modification that will continue to be amortized

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate availability

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

372,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

138,500,000

'

'

Outstanding letters of credit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

27,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Term of credit facility

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'6 years

Amount of default of other indebtness under customary events of default

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$25,000,000

'

LongTerm_Debt_Details_2

Long-Term Debt (Details 2)	9 Months Ended
	Sep. 30, 2013
	lease
Deferred Financing Costs and Original Issue Discount	'
Number of leases acquired	2
Wynnewood Acquisition | Capital Lease related to Excel Pipeline LLC	'
Deferred Financing Costs and Original Issue Discount	'
Remaining term of leases	'193 months
Wynnewood Acquisition | Capital Lease related to Magellan Pipeline Terminals, L.P.	'
Deferred Financing Costs and Original Issue Discount	'
Remaining term of leases	'192 months

Partners_Capital_and_Partnersh2

Partners' Capital and Partnership Distributions (Details)	9 Months Ended	4 Months Ended
	Sep. 30, 2013	19-May-13	Sep. 30, 2013
	partnership_interest	CVR Refining Holdings	CVR Refining Holdings
Equity [Abstract]	'	'	'
Number of types of partnership interests outstanding	2	'	'
Partners' Capital and Partnership Distributions	'	'	'
Common units issued (in shares)	147,600,000	'	'
Number of issued and outstanding common units owned	'	'	104,790,764
Percentage of outstanding units owned by CVR Refining Holdings	'	81.00%	71.00%
Maximum period after the end of each quarter of cash distribution to common unitholders	'60 days	'	'

Partners_Capital_and_Partnersh3

Partners' Capital and Partnership Distributions (Details 2) (USD $)	2 Months Ended		3 Months Ended	8 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2013		Jun. 30, 2013	Sep. 30, 2013
Equity [Abstract]	'		'	'
Amount paid CVR Refining Holdings, LLC and affiliates	$195.90	[1]	$149.60	$345.50
Amounts paid to non-affiliates	37.3	[1]	49.7	87
Total amount paid	$233.20	[1]	$199.30	$432.50
Cash distributions paid per common unit (in dollars per share)	$1.58	[1]	$1.35	$2.93
Common units outstanding (in shares)	147,600,000	[1]	147,600,000	147,600,000
[1]	The distribution for the period ended March 31, 2013 was adjusted to exclude the period from January 1, 2013 through January 22, 2013 (the period preceding the closing of the Initial Public Offering).

Net_Income_per_Common_Unit_Det

Net Income per Common Unit (Details) (USD $)	3 Months Ended		8 Months Ended	9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2013	Sep. 30, 2013		Jun. 30, 2013	Mar. 31, 2013
Net Income per Common Unit	'		'	'		'	'
Common units issued (in shares)	147,600,000		147,600,000	147,600,000		'	'
Common units outstanding (in shares)	147,600,000		147,600,000	147,600,000		147,600,000	147,600,000	[1]
Net income subsequent to initial public offering (January 23, 2013 through September 30, 2013)	$86		$622.80	$622.80		'	'
Net income per common unit, basic (in usd per unit)	$0.58	[2]	$4.22	$4.22	[2]	'	'
Net income per common unit, diluted (in usd per unit)	$0.58	[2]	$4.22	$4.22	[2]	'	'
Weighted-average common units outstanding, basic (in shares)	147,600,000		147,600,000	147,600,000		'	'
Weighted-average common units outstanding, diluted (in shares)	147,600,000		147,600,000	147,600,000		'	'
CVR Refining LTIP	'		'	'		'	'
Net Income per Common Unit	'		'	'		'	'
Common units issued (in shares)	0		0	0		'	'
Common units outstanding (in shares)	0		0	0		'	'
[1]	The distribution for the period ended March 31, 2013 was adjusted to exclude the period from January 1, 2013 through January 22, 2013 (the period preceding the closing of the Initial Public Offering).
[2]	Represents net income per common unit since closing the Partnership’s initial public offering on January 23, 2013. See Note 10 to the condensed consolidated and combined financial statements.

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	3 Months Ended			9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012	Sep. 30, 2013		Sep. 30, 2012
Operating Leases	'		'	'		'
Three months ending December 31, 2013	$0.70		'	$0.70		'
2014	2.3		'	2.3		'
2015	1.4		'	1.4		'
2016	1		'	1		'
2017	0.3		'	0.3		'
Thereafter	0.3		'	0.3		'
Operating leases	6		'	6		'
Unconditional Purchase Obligations	'		'	'		'
Three months ending December 31, 2013	82.7	[1]	'	82.7	[1]	'
2014	108.5	[1]	'	108.5	[1]	'
2015	96.7	[1]	'	96.7	[1]	'
2016	89.6	[1]	'	89.6	[1]	'
2017	88.4	[1]	'	88.4	[1]	'
Thereafter	940.7	[1]	'	940.7	[1]	'
Unconditional purchase obligations	1,406.60	[1]	'	1,406.60	[1]	'
Lease expenses	0.8		0.8	2.5		2.3
Petroleum transportation service agreement with TransCanada | CRRM	'		'	'		'
Unrecorded purchase agreements	'		'	'		'
Amount payable related to petroleum transportation service agreements	$965.50		'	$965.50		'
Period over which minimum quantity of crude oil is receivable	'		'	'18 years		'
Minimum quantity of crude oil to be received per day (in barrels)	25,000		'	25,000		'
Term of agreement	'		'	'20 years		'
[1]	This amount includes approximately $965.5 million payable ratably over eighteen years pursuant to petroleum transportation service agreements between CRRM and TransCanada Keystone Pipeline, LP (“TransCanada”). Under the agreements, CRRM receives transportation of at least 25,000 barrels per day of crude oil with a delivery point at Cushing, Oklahoma for a term of twenty years on TransCanada’s Keystone pipeline system. CRRM began receiving crude oil under the agreements in the first quarter of 2011.

Commitments_and_Contingencies_2

Commitments and Contingencies (Details 2) (USD $)

3 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

12 Months Ended

1 Months Ended

9 Months Ended

0 Months Ended

1 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Jun. 30, 2010

Oct. 31, 2009

31-May-08

Sep. 30, 2013

Oct. 25, 2010

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Mar. 31, 2012

Mar. 31, 2012

Sep. 30, 2013

Sep. 28, 2012

Jul. 02, 2013

21-May-13

Apr. 19, 2013

Mar. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Aug. 31, 2011

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Flood, Crude Oil Discharge and Insurance

Flood, Crude Oil Discharge and Insurance

Flood, Crude Oil Discharge and Insurance

Flood, Crude Oil Discharge and Insurance

Flood, Crude Oil Discharge and Insurance

EHS

EHS

EHS

EHS

EHS

EHS

EHS

MSAT II

Wynnewood refinery incident

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

WRC

WRC

WRC

New Vitol Agreement

plaintiff

claimant

plaintiff

landfill

landfill

Minimum

Maximum

employee

Flood, Crude Oil Discharge and Insurance

Flood, Crude Oil Discharge and Insurance

Flood, Crude Oil Discharge and Insurance

EHS

EHS

MSAT II

Tier 3

MSAT II

CRRM

issue

Maximum

Commitments and Contingencies

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Renewal term of agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'1 year

Number of days for prior notice of nonrenewal

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'180 days

Number of private claimants

'

'

'

'

'

'

16

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate amount of claims (excluding punitive damages)

'

'

'

'

$3,200,000

$3,200,000

$4,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of additional plaintiffs

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of claims not settled

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reimbursement of oversight cost

'

'

'

'

'

'

'

'

1,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Environmental civil penalty plus accrued interest for CWA violations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

600,000

'

'

'

'

'

'

'

'

Amount of reimbursement agreed for oversight cost

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,700,000

'

'

'

'

'

'

'

'

Environmental civil penalty related to RMP settlement agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

300,000

300,000

'

'

'

'

'

'

'

'

'

Insurance proceeds under primary environmental liability insurance policy

'

'

'

'

'

'

'

25,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Environmental, Health, and Safety ("EHS") Matters

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Environmental accruals

'

'

'

'

'

'

'

'

'

1,800,000

'

1,800,000

'

2,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Environmental accruals included in other current liabilities

'

'

'

'

'

'

'

'

'

400,000

'

400,000

'

700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated closure and post-closure costs

'

'

'

'

'

'

'

'

'

800,000

'

800,000

'

800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of landfills

'

'

'

'

'

'

'

'

'

'

'

2

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated future payments for environmental obligations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Three months ending December 31, 2013

'

'

'

'

'

'

'

'

'

200,000

'

200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2014

'

'

'

'

'

'

'

'

'

400,000

'

400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2015

'

'

'

'

'

'

'

'

'

200,000

'

200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2016

'

'

'

'

'

'

'

'

'

100,000

'

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2017

'

'

'

'

'

'

'

'

'

100,000

'

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Thereafter

'

'

'

'

'

'

'

'

'

1,100,000

'

1,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Undiscounted total

'

'

'

'

'

'

'

'

'

2,100,000

'

2,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Less amounts representing interest at 2.34%

'

'

'

'

'

'

'

'

'

300,000

'

300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued environmental liabilities at September 30, 2013

'

'

'

'

'

'

'

'

'

1,800,000

'

1,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate (as a percent)

'

'

'

'

'

'

'

'

'

2.34%

'

2.34%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acceleration of project completion

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'3 months

'

'

'

'

'

'

'

'

'

'

'

'

Estimated amount expected to be spent for environmental remediation compliance, including capital expenditures

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

63,000,000

20,000,000

'

'

105,000,000

'

Amount spent to date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

19,100,000

'

'

'

35,400,000

'

Final percentage of renewable fuel

'

'

'

'

'

'

'

'

'

'

'

9.74%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost of Renewable Identification Numbers

'

'

'

'

'

'

'

'

'

57,400,000

7,100,000

155,000,000

16,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Biofuel blending obligation recorded in accrued expenses and other current liabilities

'

'

'

'

'

'

'

'

'

47,500,000

'

47,500,000

'

1,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Marquee issues under the Clean Air Act

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

'

'

'

'

'

'

Percentage of refineries under consent decrees

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

90.00%

'

'

'

'

'

'

'

Environmental civil penalty

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

700,000

'

'

'

'

'

'

'

Estimated costs associated with Second Consent Decree

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40,000,000

'

'

'

'

'

'

Estimated cost of completion of project

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,200,000

'

'

'

'

'

'

Period over which incremental capital expenditure not material and limited primarily to retrofit and replacement of heaters and boilers

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'5 years

'7 years

'

'

'

'

'

'

'

'

'

'

'

'

'

Payment of civil penalties

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

950,000

'

'

'

Expected remaining costs under consent order

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,000,000

'

'

Expenses related to environmental, health and safety ("EHS") matters

$35,500,000

$7,700,000

$73,500,000

$18,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of employees fatally injured

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Fair Value Measurements	'	'
Transfers of assets between levels of fair value hierarchy	$0	'
Transfers of liabilities between levels of fair value hierarchy	0	'
Recurring | Level 1	'	'
Fair Value Measurements	'	'
Other current assets (derivative agreements)	0	'
Other long-term assets (derivative agreements)	0	0
Total Assets	0	0
Other current liabilities (derivative agreements)	'	0
Other current liabilities (biofuels blending obligation)	'	0
Total Liabilities	'	0
Recurring | Level 2	'	'
Fair Value Measurements	'	'
Other current assets (derivative agreements)	101,900,000	'
Other long-term assets (derivative agreements)	8,200,000	900,000
Total Assets	110,100,000	900,000
Other current liabilities (derivative agreements)	'	-67,700,000
Other current liabilities (biofuels blending obligation)	'	-1,100,000
Total Liabilities	'	-68,800,000
Recurring | Level 3	'	'
Fair Value Measurements	'	'
Other current assets (derivative agreements)	0	'
Other long-term assets (derivative agreements)	0	0
Total Assets	0	0
Other current liabilities (derivative agreements)	'	0
Other current liabilities (biofuels blending obligation)	'	0
Total Liabilities	'	0
Recurring | Total	'	'
Fair Value Measurements	'	'
Other current assets (derivative agreements)	101,900,000	'
Other long-term assets (derivative agreements)	8,200,000	900,000
Total Assets	110,100,000	900,000
Other current liabilities (derivative agreements)	'	-67,700,000
Other current liabilities (biofuels blending obligation)	'	-1,100,000
Total Liabilities	'	($68,800,000)

Derivative_Financial_Instrumen2

Derivative Financial Instruments (Details) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Dec. 31, 2012

Commodity derivatives

Commodity derivatives

Commodity derivatives

Commodity derivatives

Commodity swap

Commodity swap

Commodity swap

Commodity swap

Commodity swap

Commodity swap

Not designated as hedges

Not designated as hedges

bbl

bbl

Derivative Financial Instruments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current period settlements on derivative contracts

$33.90

($53.20)

($3.90)

($80.40)

'

'

'

'

'

'

'

'

'

'

Total gain (loss) on derivatives, net

72.5

-168.9

173

-277.4

0.1

-7.1

-2.3

-11

72.4

-161.8

175.3

-266.4

'

'

Number of barrels

'

'

'

'

'

'

'

'

'

'

'

'

20,600,000

23,300,000

Net unrealized gain

'

'

'

'

'

'

'

'

'

'

'

'

110.1

'

Portion of net unrealized gain in current assets

'

'

'

'

'

'

'

'

'

'

'

'

101.9

'

Portion of net unrealized gain in non-current assets

'

'

'

'

'

'

'

'

'

'

'

'

$8.20

'

Derivative_Financial_Instrumen3

Derivative Financial Instruments (Details 2) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Current Assets	'	'
Offsetting assets	'	'
Gross Assets	$104.10	'
Gross Amounts Offset	-2.2	'
Net Assets Presented	101.9	'
Cash Collateral Not Offset	0	'
Net Amount	101.9	'
Non-Current Assets	'	'
Offsetting assets	'	'
Gross Assets	8.2	0.9
Gross Amounts Offset	0	0
Net Assets Presented	8.2	0.9
Cash Collateral Not Offset	0	0
Net Amount	8.2	0.9
Current Liabilities	'	'
Offsetting liabilities	'	'
Gross Liabilities	'	74.2
Gross Amounts Offset	'	-6.5
Net Liabilities Presented	'	67.7
Cash Collateral Not Offset	'	0
Net Amount	'	67.7
Commodity Swaps | Current Assets	'	'
Offsetting assets	'	'
Gross Assets	104.1	'
Gross Amounts Offset	-2.2	'
Net Assets Presented	101.9	'
Cash Collateral Not Offset	0	'
Net Amount	101.9	'
Commodity Swaps | Non-Current Assets	'	'
Offsetting assets	'	'
Gross Assets	8.2	0.9
Gross Amounts Offset	0	0
Net Assets Presented	8.2	0.9
Cash Collateral Not Offset	0	0
Net Amount	8.2	0.9
Commodity Swaps | Current Liabilities	'	'
Offsetting liabilities	'	'
Gross Liabilities	'	74.2
Gross Amounts Offset	'	-6.5
Net Liabilities Presented	'	67.7
Cash Collateral Not Offset	'	0
Net Amount	'	$67.70

Allocation_of_Costs_Details

Allocation of Costs (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Allocation of Costs	'	'	'	'
Direct operating expenses (exclusive of depreciation and amortization)	$104.70	$88.80	$274.50	$253.10
Selling, general and administrative expenses (exclusive of depreciation and amortization)	18.9	21.2	57.8	67.5
CVR Energy, Inc | CRLLC	'	'	'	'
Allocation of Costs	'	'	'	'
Direct operating expenses (exclusive of depreciation and amortization)	'	3	'	8.8
Selling, general and administrative expenses (exclusive of depreciation and amortization)	'	$14.40	'	$48.90

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

1 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

9 Months Ended

0 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

3 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Apr. 30, 2011

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

4-May-12

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2012

Jan. 23, 2013

Sep. 30, 2013

Intercompany credit facility

Intercompany credit facility

Hydrogen

Hydrogen

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Lease Agreement

Lease Agreement

Lease Agreement

Lease Agreement

Environmental Agreement

Limited Partnership Agreement

Limited Partnership Agreement

CRRM

CRRM

CRRM

CRRM

CRLLC

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CRNF

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CRLLC

Navistar International Corporation

High-pressure steam

High-pressure steam

High-pressure steam

High-pressure steam

Tail gas

Tail gas

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Intercompany credit facility

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

Coffeyville Resources Terminal, LLC

Coffeyville Resources Terminal, LLC

Coffeyville Resources Terminal, LLC

Coffeyville Resources Terminal, LLC

Coffeyville Resources Terminal, LLC

CVR GP, LLC

CVR GP, LLC

CVR GP, LLC

CVR GP, LLC

CRLLC

CRLLC

Intercompany credit facility

truck

Tail gas

Tail gas

Tail gas

Tail gas

Hydrogen

Hydrogen

Hydrogen

Hydrogen

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Feedstock and Shared Services Agreement

Coke Supply Agreement

Coke Supply Agreement

Coke Supply Agreement

Coke Supply Agreement

Coke Supply Agreement

Coke Supply Agreement

Coke Supply Agreement

Lease Agreement

Lease Agreement

Lease Agreement

Terminal Operating and Lease Agreement

Terminal Operating and Lease Agreement

Terminal Operating and Lease Agreement

Terminal Operating and Lease Agreement

Terminal Operating and Lease Agreement

Services Agreement

Services Agreement

Services Agreement

Services Agreement

Minimum

Nitrogen

Nitrogen

Nitrogen

Nitrogen

Tail gas

Tank capacity

Tank capacity

Tank capacity

Tank capacity

T

Minimum

Maximum

Minimum

Maximum

Minimum

Maximum

T

renewal

Related party transactions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenue from related party

$1,910,500,000

$2,337,400,000

$6,322,600,000

$6,465,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$300,000

$100,000

$600,000

$200,000

'

'

'

'

'

'

'

'

'

'

'

$1,700,000

$2,400,000

$7,000,000

$7,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost of product sold (exclusive of depreciation and amortization)

1,734,700,000

1,694,100,000

5,317,000,000

5,191,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

800,000

300,000

4,700,000

6,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Related party liability

13,400,000

'

13,400,000

'

400,000

'

'

800,000

200,000

100,000

200,000

'

'

'

'

200,000

200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12,600,000

12,600,000

'

'

'

'

'

'

Net reimbursed direct operating expenses

'

'

'

'

'

'

'

'

'

'

'

-8,000

-2,000

10,000

42,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount paid for direct operating expenses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

100,000

100,000

200,000

'

'

'

'

'

'

'

100,000

400,000

400,000

1,300,000

'

100,000

0

300,000

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Period for payment of cost of installation of pipe

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'3 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of payment agreed to be paid for cost of capital in fourth year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Asset included in other current assets

1,300,000

'

1,300,000

'

900,000

'

'

'

'

800,000

400,000

'

'

'

'

400,000

500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Asset included in other non-current assets

100,000

'

100,000

'

400,000

'

'

'

'

'

'

'

'

'

'

100,000

400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

300,000

'

300,000

'

600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liability included in other non-current liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,200,000

1,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Initial term of agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'20 years

'

'

'

'

'

'

'

'

'

'

'

'20 years

'

'

'

'

'

'

'

'

'

'

'

'

'20 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Renewal period of agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'

'

'

'

'

Notice period for termination of agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'3 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'3 years

'

'180 days

'

'

'

'

'

'

'

'

'

'180 days

'1 year

'

'

'

'

Percentage of annual production of pet coke to be delivered

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Annual production of pet coke (in tons)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Monthly production volume of product which allows for the purchasing party the option to purchase any excess at rates stated in the agreement (in tons)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

41,667

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Pet coke price used to calculate the UAN-based price under the related party agreement (in dollars per ton)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25

'

'

5

40

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

UAN-based netback price, exclusive of transportation cost, under the related party agreement (in dollars per ton)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

205

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Pet coke price adjustment for every $1.00 change in the UAN netback price, exclusive of transportation cost, used to calculate the UAN-based price under the related party agreement (in dollars per ton)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

UAN-based netback price change, exclusive of transportation cost, under the related party agreement (in dollars per ton)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Notice period for termination of agreement during any renewal term

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'180 days

'

'

'

'

'

'

'

'

'

'

'

'

Annual rent to be paid

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

Fees to be paid for UAN placed into the terminal (in dollars per ton)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

'

'

'

'

'

'

'

'

'

'

'

'

Fees to be paid for UAN placed out of the terminal (in dollars per ton)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

'

'

'

'

'

'

'

'

'

'

'

'

Number of times the agreement can be renewed

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

'

'

'

'

'

'

'

'

'

'

'

'

'

Additional renewal period of agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'1 year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Notice period for renewal of agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'60 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating leases, lease revenue

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

27,000

26,000

100,000

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

28,000

12,000

83,000

12,000

'

'

'

'

'

'

'

'

Notice period for exclusion of service from agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'180 days

'

'

'

'

'

'

Expenses from transaction with related party

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

22,000,000

64,500,000

'

'

'

'

'

'

Selling, general and administrative expenses (exclusive of depreciation and amortization)

18,900,000

21,200,000

57,800,000

67,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15,400,000

45,400,000

'

'

14,400,000

48,900,000

'

'

Direct operating expenses (exclusive of depreciation and amortization)

104,700,000

88,800,000

274,500,000

253,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,600,000

19,100,000

'

'

3,000,000

8,800,000

'

'

Net reimbursed direct operating expenses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000

200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of credit facility

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

150,000,000

'

Term of credit facility

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'6 years

'

Variable rate basis

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'LIBOR

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'LIBOR

'

Basis spread on variable rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.00%

'

Borrowings outstanding

'

'

'

'

'

11,500,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

11,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of trucks purchased

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7

Purchases from related party

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$800,000

Percentage of ownership by related party

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

17.00%

Subsequent_Events_Details

Subsequent Events (Details) (Distribution, USD $)	0 Months Ended
In Millions, except Per Share data, unless otherwise specified	Oct. 31, 2013
Distribution	'
Subsequent Events	'
Cash distribution declared (in dollars per unit)	$0.30
Aggregate cash distribution declared	$44.30