CVR Refining 10-K 26 Feb 14 2013 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Feb. 18, 2014	Jun. 28, 2013
Document and Entity Information	'	'	'
Entity Registrant Name	'CVR Refining, LP	'	'
Entity Central Index Key	'0001558785	'	'
Document Type	'10-K	'	'
Document Period End Date	31-Dec-13	'	'
Amendment Flag	'false	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Well-known Seasoned Issuer	'No	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Filer Category	'Non-accelerated Filer	'	'
Entity Public Float	'	'	$1,095,393,494
Entity Common Stock, Shares Outstanding	'	147,600,000	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$279.80	$153.10
Accounts receivable, net of allowance for doubtful accounts of $0.9 and $1.9, including $0.6 due from affiliates at December 31, 2013 and 2012, respectively	234.9	204.5
Inventories	493.7	499.5
Prepaid expenses and other current assets, including $1.5 and $0.9 due from affiliates at December 31, 2013 and 2012, respectively	74.2	27
Insurance receivable	0	1.3
Total current assets	1,082.60	885.4
Property, plant, and equipment, net of accumulated depreciation	1,430.20	1,351.60
Deferred financing costs, net	10	14.4
Other long-term assets, including $0.1 and $0.4 due from affiliates at December 31, 2013 and 2012, respectively	10.5	7.1
Total assets	2,533.30	2,258.50
Current liabilities:	'	'
Note payable and capital lease obligations	1.3	1.1
Accounts payable, including $17.7 and $0.4 due to affiliates at December 31, 2013 and 2012, respectively	341	364.7
Personnel accruals	13	14
Accrued taxes other than income taxes	30	29.5
Accrued expenses and other current liabilities, including $0.2 due to affiliates at December 31, 2013 and 2012, respectively	40.4	93.4
Total current liabilities	425.7	502.7
Long-term liabilities:	'	'
Long-term debt and capital lease obligations, net of current portion, including $31.5 due to affiliates at December 31, 2013	581.4	772.1
Accrued environmental liabilities, net of current portion	1.2	1.6
Other long-term liabilities, including $1.1 and $1.3 due to affiliates at December 31, 2013 and 2012, respectively	2.9	1.3
Total long-term liabilities	585.5	775
Commitments and contingencies	'	'
Partners' Capital	'	'
Common unitholders, 147,600,000 units issued and outstanding at December 31, 2013	1,522.10	0
General partner’s interest	0	0
Limited partner interest	0	980.8
Partners' capital	1,522.10	980.8
Total liabilities and partners' capital	$2,533.30	$2,258.50

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, except Share data, unless otherwise specified
Statement of Financial Position [Abstract]	'	'
Accounts receivable, allowance for doubtful accounts	$0.90	$1.90
Accounts receivable, due from affiliates	0.6	0.6
Prepaid expenses and other current assets, due from affiliates	1.5	0.9
Other long-term assets, due from affiliates	0.1	0.4
Accounts payable, due to affiliates	17.7	0.4
Accrued expenses and other current liabilities, due to affiliates	0.2	0.2
Long term debt and capital lease obligations, net of current portion, due to affiliates	31.5	0
Other long-term liabilities, due to affiliates	$1.10	$1.30
Common unitholders, units issued (in shares)	147,600,000	'
Common unitholders, units outstanding (in shares)	147,600,000	'

CONSOLIDATED_AND_COMBINED_STAT

CONSOLIDATED AND COMBINED STATEMENTS OF OPERATION (USD $)	3 Months Ended								12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
Income Statement [Abstract]	'	'	'	'	'	'	'	'	'		'	'
Net sales	$2,360.90	$1,910.50	$2,138.10	$2,274	$1,816.20	$2,337.40	$2,229.60	$1,898.50	$8,683.50		$8,281.70	$4,752.80
Operating costs and expenses:	'	'	'	'	'	'	'	'	'		'	'
Cost of product sold (exclusive of depreciation and amortization)	2,209.70	1,734.70	1,776.60	1,805.80	1,476.50	1,694.10	1,866.20	1,630.70	7,526.70		6,667.50	3,927.60
Direct operating expenses (exclusive of depreciation and amortization)	87.2	104.7	83.8	86	173.4	88.8	71.6	92.7	361.7		426.5	247.7
Selling, general and administrative expenses (exclusive of depreciation and amortization)	20	18.9	20.2	18.6	18.6	21.2	26.1	20.2	77.8		86.2	51
Depreciation and amortization	29.1	28.8	28.4	28	27.3	27.5	26.6	26.3	114.3		107.6	69.8
Total operating costs and expenses	2,346	1,887.10	1,909	1,938.40	1,695.80	1,831.60	1,990.50	1,769.90	8,080.50		7,287.80	4,296.10
Operating income	14.9	23.4	229.1	335.6	120.4	505.8	239.1	128.6	603		993.9	456.7
Other income (expense):	'	'	'	'	'	'	'	'	'		'	'
Interest expense and other financing costs	-9.3	-10	-10.6	-14.2	-20.2	-18.2	-19	-18.8	-44.1		-76.2	-53
Interest income	0.1	0.1	0.1	0.1	0	0	0	0	0.4		0	0
Gain (loss) on derivatives, net	-115.9	72.5	120.5	-20	-8.2	-168.9	38.8	-147.2	57.1		-285.6	78.1
Loss on extinguishment of debt	0	0	0	-26.1	-37.5	0	0	0	-26.1		-37.5	-2.1
Other income, net	0	0	0.1	0	0.1	-0.1	0.6	0	0.1		0.7	0.6
Total other income (expense)	-125.1	62.6	110.1	-60.2	-65.8	-187.2	20.4	-166	-12.6		-398.6	23.6
Income before income tax expense	-110.2	86	339.2	275.4	54.6	318.6	259.5	-37.4	590.4		595.3	480.3
Income taxes	0	0	0	0	0	0	0	0	0		0	0
Net income	-110.2	86	339.2	275.4	54.6	318.6	259.5	-37.4	590.4		595.3	480.3
Net income subsequent to initial public offering (January 23, 2013 through December 31, 2013)	($110.20)	$86	$339.20	$197.50	'	'	'	'	$512.60		'	'
Net income per common unit - basic (in dollars per share)	($0.75)	$0.58	$2.30	$1.34	'	'	'	'	$3.47	[1]	'	'
Net income per common unit - diluted (in dollars per share)	($0.75)	$0.58	$2.30	$1.34	'	'	'	'	$3.47	[1]	'	'
Weighted-average common units outstanding, basic (in shares)	147.6	147.6	147.6	147.6	'	'	'	'	147.6		'	'
Weighted-average common units outstanding, diluted (in shares)	147.6	147.6	147.6	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 11 to the consolidated and combined financial statements.

CONSOLIDATED_AND_COMBINED_STAT1

CONSOLIDATED AND COMBINED STATEMENTS OF CHANGES IN PARTNERS' CAPITAL/DIVISIONAL EQUITY (USD $)	Total	January issuance of common units	May issuance of additional common units	Divisional Equity	Limited Partner Interest	Common Unitholders	Common Unitholders	Common Unitholders
In Millions, except Share data, unless otherwise specified							January issuance of common units	May issuance of additional common units
Balance at Dec. 31, 2010	$418.80	'	'	$418.80	'	'	'	'
Increase (Decrease) in Stockholders' Equity	'	'	'	'	'	'	'	'
Share-based compensation	8.9	'	'	8.9	'	'	'	'
Contributions from parent, net	110.6	'	'	110.6	'	'	'	'
Net income	480.3	'	'	480.3	'	'	'	'
Balance at Dec. 31, 2011	1,018.60	'	'	1,018.60	'	'	'	'
Increase (Decrease) in Stockholders' Equity	'	'	'	'	'	'	'	'
Share-based compensation	18.5	'	'	18.5	'	'	'	'
Distributions to affiliates, net	-651.6	'	'	-651.6	'	'	'	'
Net income	595.3	'	'	595.3	'	'	'	'
CRLLC contribution to CVR Refining, LP for limited partner interest	'	'	'	-980.8	980.8	'	'	'
Balance at Dec. 31, 2012	980.8	'	'	'	980.8	'	'	'
Increase (Decrease) in Stockholders' Equity	'	'	'	'	'	'	'	'
Net Income Prior to Initial Public Offering	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	'	'	'
Distributions to affiliates, net	-85.1	'	'	'	'	-85.1	'	'
Net income	590.4	'	'	'	'	'	'	'
Conversion of limited partner interest to common units and general partner interest (in units)	'	'	'	'	'	147,600,000	'	'
Conversion of limited partner interest to common units and general partner interest	'	'	'	'	-909.4	909.4	'	'
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
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	8.7	'	'	'	'	8.7	'	'
Cash distributions to common unitholders - Affiliates	-378.7	'	'	'	'	-378.7	'	'
Cash distributions to common unitholders - Non-affiliates	-98	'	'	'	'	-98	'	'
Net income attributable to the period from January 23, 2013 through December 31, 2013	512.6	'	'	'	'	512.6	'	'
Balance at Dec. 31, 2013	$1,522.10	'	'	'	'	$1,522.10	'	'
Balance (in units) at Dec. 31, 2013	'	'	'	'	'	147,600,000	'	'

CONSOLIDATED_AND_COMBINED_STAT2

CONSOLIDATED AND COMBINED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash flows from operating activities:	'	'	'
Net income	$590.40	$595.30	$480.30
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'
Depreciation and amortization	114.3	107.6	69.8
Allowance for doubtful accounts	-1.1	0.7	0.5
Amortization of deferred financing costs	1.9	6.4	3.9
Amortization of original issue discount	0	0.5	0.5
Amortization of original issue premium	0	-2.8	-0.1
Loss on disposition of assets	0.1	1.2	2.7
Loss on extinguishment of debt	26.1	37.5	2.1
Share-based compensation	11.6	18.5	8.9
(Gain) loss on derivatives, net	-57.1	285.6	-78.1
Current period settlements on derivative contracts	6.4	-137.6	-7.2
Changes in assets and liabilities:	'	'	'
Accounts receivable	-29.3	-30.4	58.9
Inventories	5.8	113.9	-172
Prepaid expenses and other current assets	-49.1	14.7	-14.1
Insurance receivable	0	0	-2.4
Insurance Receivable	1.3	0.7	0
Other long-term assets	0.2	2.2	-1.3
Accounts payable	-18.9	-101.3	7.1
Accrued expenses and other current liabilities	-1	4.4	-6.9
Accrued environmental liabilities	-0.4	0.1	-1.1
Other long-term liabilities	-0.2	0.1	1.2
Net cash provided by operating activities	601	917.3	352.7
Cash flows from investing activities:	'	'	'
Capital expenditures	-204.5	-120.2	-68.8
Proceeds from sale of assets	0.1	0.4	0
Acquisition of Gary-Williams	0	0	-587.1
Net cash used in investing activities	-204.4	-119.8	-655.9
Cash flows from financing activities:	'	'	'
Proceeds, gross of original issue premium on issuance of senior notes	0	0	206
Proceeds, gross on issuance of CVR Refining's senior notes	0	500	0
Principal payments on senior secured notes	-243.4	-478.7	-2.7
Payment of capital lease obligations	-1.1	-0.9	0
Payment of deferred financing costs	-0.4	-12.8	-10.3
Proceeds from Related Party Debt	31.5	0	0
Payments to Redeem Common Limited Partners Units	-394	0	0
Deferred costs associated with the initial public offering	0	-3.1	0
Net contributions from (distributions to) parent	0	-651.6	110.6
Payments of Distributions to Affiliates	-235.1	0	0
Net cash used in financing activities	-269.9	-647.1	303.6
Net increase in cash and cash equivalents	126.7	150.4	0.4
Cash and cash equivalents, beginning of period	153.1	2.7	2.3
Cash and cash equivalents, end of period	279.8	153.1	2.7
Supplemental disclosures	'	'	'
Cash paid for interest net of capitalized interest of $3.2, $3.0 and $1.1 for the years ended December 31, 2013, 2012 and 2011, respectively	49.4	75.2	43.8
Non-cash investing and financing activities:	'	'	'
Construction in process additions included in accounts payable	30.4	37.4	19.9
Change in accounts payable related to construction in process additions	-7	17.5	15.3
Reduction of proceeds for underwriting discount and financing costs	0	7.5	4
January issuance of common units	'	'	'
Cash flows from financing activities:	'	'	'
Proceeds from issuance of common units, net of offering costs	655.7	0	0
May issuance of additional common units	'	'	'
Cash flows from financing activities:	'	'	'
Proceeds from issuance of common units, net of offering costs	393.6	0	0
Affiliates	'	'	'
Cash flows from financing activities:	'	'	'
Distribution to common unitholders	-378.7	0	0
Non-affiliates	'	'	'
Cash flows from financing activities:	'	'	'
Distribution to common unitholders	($98)	$0	$0

CONSOLIDATED_AND_COMBINED_STAT3

CONSOLIDATED AND COMBINED STATEMENTS OF CASH FLOWS (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Statement of Cash Flows [Abstract]	'	'	'
Capitalized interest	$3.20	$3	$1.10

Formation_of_the_Partnership_O

Formation of the Partnership, Organization and Nature of Business	12 Months Ended
	Dec. 31, 2013
Formation of the Partnership, Organization and Nature of Business	'
Formation of the Partnership, Organization and Nature of Business	'
	(1) 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 December 31, 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 December 31, 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 an approximately 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 was not considered a business combination accounted for under the purchase method as it was 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 on December 31, 2012 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 the Initial Public Offering. The Partnership sold 24,000,000 common units at a price of $25.00 per common unit. Of the common units issued, 4,000,000 units were purchased by an affiliate of Icahn Enterprises. Additionally, on January 30, 2013, the underwriters closed their option to purchase an additional 3,600,000 common units at a price of $25.00 per common unit. The common units, which are listed on the NYSE, began trading on January 17, 2013 under the symbol "CVRR." In connection with the Initial Public Offering, the Partnership paid approximately $32.5 million in underwriting fees and incurred approximately $3.9 million of other offering costs.
	The net proceeds to CVR Refining of the Initial Public Offering were 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 have 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 number includes the 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 December 31, 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. 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 Partnership's general partner is not elected by the Partnership's unitholders and will not be subject to re-election on a regular basis in the future. 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.
	In connection with the Initial Public Offering, the Partnership entered into a services agreement, pursuant to which the Partnership and its general partner will 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 for a price of $30.00 per share in cash, without interest, less any applicable withholding taxes, plus one non-transferable contingent payment right for each share of CVR Energy common stock (the "CCP"), which represented 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 prior to 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 December 31, 2013, IEP owned approximately 82% of the shares of CVR Energy.

Basis_of_Presentation

Basis of Presentation	12 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Basis of Presentation	'
	(2) Basis of Presentation
	The accompanying consolidated and combined financial statements have been prepared in accordance with Regulation S-X, Article 3, "General instructions as to financial statements" and Staff Accounting Bulletin, or SAB Topic 1-B, "Allocations of Expenses and Related disclosures in Financial Statements of Subsidiaries, Divisions or Lesser Business Components of Another Entity."
	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). These allocations are not necessarily indicative of the cost that the Partnership would have incurred had it operated as an independent stand-alone entity during the years ended December 31, 2012 and 2011. All intercompany accounts and transactions have been eliminated. The allocations and related estimates and assumptions are described more fully in Note 3 ("Summary of Significant Accounting Policies") and Note 17 ("Related Party Transactions").
	CRLLC also used a centralized approach to cash management and the financing of its operations until the contribution of its petroleum refining and related logistics business to CVR Refining on December 31, 2012. As a result, amounts owed to or from CRLLC prior to December 31, 2012 are reflected as a component of divisional equity on the accompanying Consolidated and Combined Statements of Changes in Partners' Capital/Divisional Equity.
	Beginning in 2013, the 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 17 ("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.
	The Partnership has omitted net income per unit for the years ended December 31, 2012 and 2011, 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 year ended December 31, 2013 is calculated since the closing of the Initial Public Offering on January 23, 2013.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Summary of Significant Accounting Policies	'
	(3) Summary of Significant Accounting Policies
	Cash and Cash Equivalents
	CRLLC historically provided cash as needed to support the operations of the refining and related logistics assets and retained excess cash earned by the Partnership. The Partnership considers all highly liquid money market accounts and debt instruments with original maturities of three months or less to be cash equivalents. Cash received or paid by CRLLC on behalf of CVR Refining prior to December 31, 2012 is reflected as net contributions from or net distributions to parent on the accompanying Consolidated and Combined Statements of Changes in Partners' Capital/Divisional Equity. Effective December 31, 2012, the Partnership began operating with an independent capital structure.
	Under the Partnership's cash management system, checks issued but not presented to banks frequently result in book overdraft balances for accounting purposes and are classified within accounts payable in the Consolidated Balance Sheets. The change in book overdrafts are reported in the Consolidated and Combined Statements of Cash Flows as a component of operating cash flows for accounts payable as they do not represent bank overdrafts. The amount of these checks included in accounts payable as of December 31, 2013 and 2012 was $11.7 million and $14.9 million, respectively.
	Accounts Receivable, net
	CVR Refining grants credit to its customers. Credit is extended based on an evaluation of a customer's financial condition; generally, collateral is not required. Accounts receivable are due on negotiated terms and are stated at amounts due from customers, net of an allowance for doubtful accounts. Accounts outstanding longer than their contractual payment terms are considered past due. CVR Refining determines its allowance for doubtful accounts by considering a number of factors, including the length of time trade accounts are past due, the customer's ability to pay its obligations to CVR Refining, and the condition of the general economy and the industry as a whole. CVR Refining writes off accounts receivable when they become uncollectible, and payments subsequently received on such receivables are credited to the allowance for doubtful accounts. Amounts collected on accounts receivable are included in net cash provided by operating activities in the Consolidated and Combined Statements of Cash Flows. At December 31, 2013 and 2012, one customer individually represented greater than 10% of the total accounts receivable balance. The largest concentration of credit for any one customer at December 31, 2013 and 2012 was approximately 13% and 10%, respectively, of the accounts receivable balance.
	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 byproducts 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.
	Prepaid Expenses and Other Current Assets
	Prepaid expenses and other current assets consist of prepayments for crude oil deliveries to our refineries for which title had not transferred, non-trade accounts receivable, current portions of prepaid insurance, deferred financing costs, derivative agreements and other general current assets.
	Property, Plant, and Equipment
	Additions to property, plant and equipment, including capitalized interest and certain costs allocable to construction and property purchases, are recorded at cost. Capitalized interest is added to any capital project over $1.0 million in cost which is expected to take more than six months to complete. Depreciation is computed using principally the straight-line method over the estimated useful lives of the various classes of depreciable assets. The lives used in computing depreciation for such assets are as follows:
	Asset	Range of Useful
		Lives, in Years
	Improvements to land	15	to	30
	Buildings	20	to	30
	Machinery and equipment	5	to	30
	Automotive equipment	5	to	15
	Furniture and fixtures	3	to	10
	Leasehold improvements are depreciated or amortized on the straight-line method over the shorter of the contractual lease term or the estimated useful life of the asset. Expenditures for routine maintenance and repair costs are expensed when incurred. Such expenses are reported in direct operating expenses (exclusive of depreciation and amortization) in the Consolidated and Combined Statements of Operations.
	Deferred Financing Costs, Underwriting and Original Issue Discount
	Deferred financing costs associated with debt issuances are amortized to interest expense and other financing costs using the effective-interest method over the life of the debt. Additionally, the underwriting and original issue discount and premium related to debt issuances have been amortized to interest expense and other financing costs using the effective-interest method over the life of the debt. Deferred financing costs related to the Amended and Restated ABL Credit Facility are amortized to interest expense and other financing costs using the straight-line method through the termination date of the facility.
	Planned Major Maintenance Costs
	The direct-expense method of accounting is used for planned major maintenance activities. Maintenance costs are recognized as expense when maintenance services are performed. Planned major maintenance activities for the refineries varies by unit, but generally is every four to five years.
	The Coffeyville refinery completed the second phase of a two-phase turnaround project during the first quarter of 2012. The first phase was completed during the fourth quarter of 2011. Costs of approximately $21.2 million and $66.4 million associated with the Coffeyville refinery's 2011/2012 turnaround were included in direct operating expenses (exclusive of depreciation and amortization) for the years ended December 31, 2012 and 2011, respectively. The Wynnewood refinery completed a turnaround in the fourth quarter of 2012. Costs of approximately $102.5 million were included in direct operating expenses (exclusive of depreciation and amortization) for the year ended December 31, 2012.
	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 $4.8 million, $3.6 million and $2.4 million for the years ended December 31, 2013, 2012 and 2011, 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 share-based compensation for CVR Energy and Coffeyville Acquisition III LLC ("CALLC III"), as discussed in Note 5 ("Share-Based Compensation"). Direct operating expenses exclude depreciation and amortization of approximately $109.1 million, $103.5 million and $67.2 million for the years ended December 31, 2013, 2012 and 2011, 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 share-based compensation expense from CVR Energy and CALLC III as discussed in Note 5 ("Share-Based Compensation"). Selling, general and administrative expenses exclude depreciation and amortization of approximately $0.4 million, $0.5 million and $0.2 million for the years ended December 31, 2013, 2012 and 2011, respectively.
	Income Taxes
	CVR Refining is treated as a partnership for U.S. federal income tax purposes. The income tax liability of the common unitholders is not reflected in the consolidated and combined financial statements of the Partnership. 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.
	Segment Reporting
	The Partnership accounts for segment reporting in accordance with the Financial Accounting Standards Board ("FASB") Accounting Standards Codification ("ASC") Topic ASC 280, Segment Reporting, which established standards for entities to report information about the operating segments and geographic areas in which they operate. CVR Refining only operates one segment and all of its operations are located in the United States.
	Impairment of Long-Lived Assets
	CVR Refining accounts for long-lived assets in accordance with accounting standards issued by the FASB regarding the treatment of the impairment or disposal of long-lived assets. As required by this standard, CVR Refining reviews long-lived assets (excluding intangible assets with indefinite lives) for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to estimated undiscounted future net cash flows expected to be generated by the asset. If the carrying amount of an asset exceeds its estimated undiscounted future net cash flows, an impairment charge is recognized for the amount by which the carrying amount of the assets exceeds their fair value. Assets to be disposed of are reported at the lower of their carrying value or fair value less cost to sell.
	Divisional Equity
	Partners' capital is referred to as divisional equity during the periods covered by the consolidated and combined financial statements prior to the contribution of the Refining Subsidiaries to the Partnership. Upon CRLLC's contribution of the Refining Subsidiaries to the Partnership on December 31, 2012, divisional equity became partners' capital.
	Revenue Recognition
	Revenues for products sold are recorded upon delivery of the products to customers, which is the point at which title is transferred, the customer has assumed the risk of loss, and payment has been received or collection is reasonably assured. Excise and other taxes collected from customers and remitted to governmental authorities are not included in reported revenues.
	Nonmonetary product exchanges and certain buy/sell crude oil transactions which are entered into in the normal course of business are included on a net cost basis in operating expenses on the Consolidated and Combined Statements of Operations.
	The Partnership also engages in trading activities, whereby the Partnership enters into agreements to purchase and sell refined products with third parties. The Partnership acts as a principal in these transactions, taking title to the products in purchases from counterparties, and accepting the risks and rewards of ownership. The Partnership records revenue for the gross amount of the sales transactions, and records costs of purchases as an operating expense in the accompanying consolidated and combined financial statements.
	Shipping Costs
	Pass-through finished goods delivery costs reimbursed by customers are reported in net sales, while an offsetting expense is included in cost of product sold (exclusive of depreciation and amortization).
	Derivative Instruments and Fair Value of Financial Instruments
	The Partnership uses futures contracts, options, and forward contracts primarily to reduce exposure to changes in crude oil prices, finished goods product prices and interest rates to provide economic hedges of inventory positions and anticipated interest payments on long-term debt. Although management considers these derivatives economic hedges, these derivative instruments do not qualify as hedges for hedge accounting purposes under ASC Topic 815, Derivatives and Hedging ("ASC 815"), and accordingly are recorded at fair value in the balance sheet. Changes in the fair value of these derivative instruments are recorded into earnings as a component of other income (expense) in the period of change. The estimated fair values of forward and swap contracts are based on quoted market prices and assumptions for the estimated forward yield curves of related commodities in periods when quoted market prices are unavailable. See Note 16 ("Derivative Financial Instruments") for further discussion.
	Other financial instruments consisting of cash and cash equivalents, accounts receivable, and accounts payable are carried at cost, which approximates fair value, as a result of the short-term nature of the instruments. See Note 9 ("Long-Term Debt") for further discussion of the fair value of the debt instruments.
	Share-Based Compensation
	The Partnership has been allocated share-based compensation expense from CVR Energy, CRLLC and CALLC III. CVR Energy accounts for share-based compensation in accordance with ASC Topic 718, Compensation — Stock Compensation ("ASC 718"). ASC 718 requires that compensation costs relating to share-based payment transactions be recognized in a company's financial statements. ASC 718 applies to transactions in which an entity exchanges its equity instruments for goods or services and also may apply to liabilities an entity incurs for goods or services that are based on the fair value of those equity instruments.
	Environmental Matters
	Liabilities related to future remediation costs of past environmental contamination of properties are recognized when the related costs are considered probable and can be reasonably estimated. Estimates of these costs are based upon currently available facts, internal and third party assessments of contamination, available remediation technology, site-specific costs, and currently enacted laws and regulations. In reporting environmental liabilities, no offset is made for potential recoveries. Loss contingency accruals, including those for environmental remediation, are subject to revision as further information develops or circumstances change and such accruals can take into account the legal liability of other parties. Environmental expenditures are capitalized at the time of the expenditure when such costs provide future economic benefits.
	Use of Estimates
	The consolidated and combined financial statements have been prepared in conformity with U.S. generally accepted accounting principles ("GAAP"), using management's best estimates and judgments where appropriate. These estimates and judgments affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ materially from these estimates and judgments.
	Related Party Transactions
	CVR Energy and its subsidiaries provide a variety of services to CVR Refining, including cash management and financing services, employee benefits provided through CVR Energy's benefit plans, administrative services provided by CVR Energy's employees and management, insurance and office space leased in CVR Energy's headquarters building and other locations. As such, the accompanying consolidated and combined financial statements include costs that have been incurred by CVR Energy and CRLLC on behalf of CVR Refining. These amounts incurred by CVR Energy are then billed or allocated to CVR Refining and are properly classified on the Consolidated and Combined Statements of Operations as either direct operating expenses (exclusive of depreciation and amortization) or as selling, general and administrative expenses (exclusive of depreciation and amortization). For the year ended December 31, 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. Such expenses include, but are not limited to, salaries, benefits, share-based compensation expense, insurance, accounting, tax, legal and technology services. Costs which are specifically incurred on behalf of CVR Refining, are billed directly to CVR Refining. See Note 17 ("Related Party Transactions") for a detailed discussion of the billing procedures and the basis for calculating the charges.
	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 accompanying financial statements have been prepared in accordance with SAB Topic 1-B, as more fully explained in Note 2 ("Basis of Presentation"). 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 have allocated general and administrative expenses to CVR Refining based on allocation methodologies that management considers reasonable and result in an allocation of the 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.
	CVR Refining's Consolidated and Combined Statements of Operations for the years ended December 31, 2012 and 2011 reflect all of the expenses that CRLLC and CVR Energy incurred on CVR Refining's behalf. For the year ended December 31, 2013, amounts incurred by CVR Energy and its affiliates on our behalf have been governed and billed in accordance with the services agreement as discussed above. 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, mark-to-market changes in interest rate swap, 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 5 ("Share-Based Compensation").
The table below reflects cost allocations, either allocated or billed, for the years ended December 31, 2012 and 2011 reflected in the Consolidated and Combined Statements of Operations.
	Year Ended December 31,
	2012			2011
	(in millions)
Direct operating expenses (exclusive of depreciation and amortization)	$	13.3		$	9.1
Selling, general and administrative expenses (exclusive of depreciation and amortization)	65.5			39.7
	$	78.8		$	48.8
Subsequent Events
The Partnership evaluated subsequent events, if any, that would require an adjustment to the Partnership's consolidated and combined financial statements or require disclosure in the notes to the consolidated and combined financial statements through the date of issuance of the consolidated and combined financial statements. See Note 20 ("Subsequent Events") for further discussion.
New Accounting Pronouncements
In December 2011, the FASB issued Accounting Standard Update ("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 consolidated financial statement footnote disclosures.

Wynnewood_Acquisition

Wynnewood Acquisition	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Wynnewood Acquisition	'
	(4) Wynnewood Acquisition
	On December 15, 2011, CVR Refining, through CRLLC, completed the acquisition of all the issued and outstanding shares of the Gary-Williams Energy Corporation (subsequently converted to WEC), including its two wholly-owned subsidiaries (the "Wynnewood Acquisition"), for a purchase price of $593.4 million from The Gary-Williams Company, Inc. (the "Seller"). This consisted of $525.0 million, in cash, plus approximately $66.6 million for working capital and approximately $1.8 million for a capital expenditure adjustment. The Wynnewood Acquisition was partially funded by proceeds received from the issuance of additional First Lien Notes. See Note 9 ("Long-Term Debt") for further discussion of the issuance. The Wynnewood Acquisition was accounted for under the purchase method of accounting and, as such, CVR Refining's results of operations on the Consolidated and Combined Statements of Operations for the year ended December 31, 2011 include WEC's revenues and operating loss of approximately $115.7 million and $2.3 million, respectively, for the period from December 16, 2011 through December 31, 2011.
	WEC owned a 70,000 bpcd rated capacity refinery in Wynnewood, Oklahoma that includes approximately 2.0 million barrels of company-owned storage tanks. Located in the PADD II Group 3 distribution area, the Wynnewood refinery is a dual crude oil unit facility that processes a variety of crudes and produces high-value fuel products (including gasoline, ultra-low sulfur diesel, jet fuel and solvent) as well as liquefied petroleum gas and a variety of asphalts.
	Purchase Price Allocation
	Under the purchase method of accounting, the total purchase price was allocated to WEC's net tangible assets based on their fair values as of December 15, 2011. An independent appraisal of the net assets was completed. The purchase price included a preliminary net working capital amount, which was finalized in the first quarter of 2012. At December 31, 2011, this difference was estimated at approximately $15.8 million and was recorded in prepaid expenses and other current assets in the Consolidated Balance Sheets.
	In accordance with the Stock Purchase and Sale Agreement (the "Purchase Agreement"), CVR Refining provided a Post-Closing Statement to the Seller on February 13, 2012 which reflected the difference between the cash paid at closing for the estimated working capital as compared to the actual net working capital acquired. In March 2012, the preliminary purchase price was increased by $1.1 million following settlement of the estimated cash paid for working capital in excess of actual working capital.
	The following table displays the total final purchase price allocated to WEC's net tangible assets based on their fair values as of December 15, 2011 (in millions):
	Cash and cash equivalents	$	6.3
	Accounts receivable	159
	Inventories	213.5
	Prepaid expenses and other current assets	6
	Property, plant and equipment	577
	Accounts payable and accrued liabilities	(316.1		)
	Long-term debt	(52.3		)
	Total fair values of net assets acquired	593.4
	Less: cash acquired	6.3
	Total consideration transferred, net of cash acquired	$	587.1
	Acquisition Costs
	For the years ended December 31, 2012 and 2011, the Partnership recognized approximately $11.0 million and $5.2 million, respectively in transaction fees and integration expenses that are included in selling, general and administrative expense in the Consolidated and Combined Statements of Operations. In 2012, these costs primarily relate to accounting and other professional consulting fees incurred associated with post-closing transaction matters and continued integration of various processes, policies, technologies and systems of GWEC. In 2011, these costs primarily relate to legal, accounting, initial purchaser discounts and commissions, and other professional fees incurred since the announcement of the Wynnewood Acquisition in November 2011. In addition, CVR Refining, through CRLLC, entered into a commitment letter for a senior secured one-year bridge loan to ensure that financing would be available for the Wynnewood Acquisition in the event that the additional offering of First Lien Notes was not closed by the date of the Wynnewood Acquisition. The bridge loan commitment letter subsequently expired by its terms. A commitment fee and other third-party costs totaling $3.9 million are included in selling, general and administrative expenses associated with the bridge loan commitment. The Company did not incur such expenses for the year ended December 31, 2013 as the Wynnewood refinery’s operations were fully integrated.

ShareBased_Compensation

Share-Based Compensation	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Share-Based Compensation	'
	(5) 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 the allocated share-based compensation for certain plans as discussed below. Allocated expense amounts related to plans for which CVR Refining is not responsible for payment are reflected as an increase or decrease to partners' capital/divisional equity.
	CALLC Override Units
	Prior to CVR Energy's initial public offering, CVR Energy's subsidiaries were held and operated by Coffeyville Acquisition LLC ("CALLC"). CALLC issued non-voting override units to certain management members who held common units of CALLC. There were no required capital contributions for the override operating units. In connection with CVR Energy's initial public offering in October 2007, CALLC was split into two entities: CALLC and Coffeyville Acquisition II LLC ("CALLC II"). In connection with this split, management's equity interest in CALLC, including both their common units and non-voting override units, was split so that half of management's equity interest was in CALLC and half was in CALLC II. In addition, in connection with the transfer of the managing general partner of CVR Partners to CALLC III in October 2007, CALLC III issued non-voting override units to certain management members of CALLC III.
	In February 2011, CALLC and CALLC II sold 11,759,023 shares and 15,113,254 shares, respectively, of CVR Energy's common stock, pursuant to an underwritten registered public offering. In May 2011, CALLC sold 7,988,179 shares of CVR Energy's common stock, pursuant to an underwritten registered public offering.
	As a result, CALLC and CALLC II ceased to be stockholders of CVR Energy. Subsequent to CALLC II's divestiture of its ownership interest in CVR Energy in February 2011 and CALLC's divestiture of its ownership interest in CVR Energy in May 2011, no additional share-based compensation expense was incurred with respect to override units and phantom units. The final fair values of the override units of CALLC and CALLC II were derived based upon the values resulting from the proceeds received associated with each entity's respective divestiture of its ownership in CVR Energy. These values were utilized to determine the related compensation expense for the unvested units.
	The final fair value of the CALLC III override units was derived based upon the aggregate principal amount of the proceeds received by CVR Partners' general partner upon the purchase of CVR Partners' incentive distribution rights ("IDRs") by CVR Partners. These proceeds were subsequently distributed to the owners of CALLC III which includes the override unitholders. This value was utilized to determine the related compensation expense for the unvested units. No additional share-based compensation was incurred with respect to override units of CALLC III subsequent to June 30, 2011 due to the complete distribution of the value prior to July 1, 2011.
	The following table provides key information for the share-based compensation plans related to the override units of CALLC, CALLC II, and CALLC III.
								*Compensation
								Expense for the
								Year Ended
								December 31,
	Award Type	Benchmark Value (per Unit)			Original Awards Issued	Grant Date		2011
								(in millions)
	Override Value Units	$	11.31		1,839,265	Jun-05		$	1.4
	Override Units	$	10		642,219	Feb-08		(0.1		)
						Total		$	1.3
	*	As CVR Energy's common stock price increased or decreased, compensation expense associated with the unvested CALLC and CALLC II override units increased or was reversed in correlation with the calculation of the fair value under the probability-weighted expected return method.
	Due to the divestiture of all ownership in CVR Energy by CALLC and CALLC II and due to the purchase of the IDRs from CVR Partners' general partner and the distribution to CALLC III, there was no associated unrecognized compensation expense as of December 31, 2013, 2012 and 2011. CVR Refining was not responsible for payment of override unit allocated awards, and accordingly, the expense recorded for the year ended December 31, 2011 has been reflected as an increase to divisional equity.
	Phantom Unit Plans
	CVR Energy, through CRLLC, had two Phantom Unit Appreciation Plans (the "Phantom Unit Plans") whereby directors, employees and service providers were eligible to be awarded phantom points at the discretion of CVR Energy's board of directors or the compensation committee. Holders of service phantom points received distributions when CALLC and CALLC II holders of override operating units received distributions. Holders of performance phantom points received distributions when CALLC and CALLC II holders of override value units received distributions.
	There was no compensation expense for the year ended December 31, 2013 and 2012 related to the Phantom Unit Plans. Compensation expense allocated for the year ended December 31, 2011 related to the Phantom Unit Plans was approximately $4.3 million. The Phantom Unit Plans were terminated in December 2012. Due to the divestiture of all ownership of CVR Energy by CALLC and CALLC II, there was no unrecognized compensation expense associated with the Phantom Unit Plans at December 31, 2013, 2012 and 2011. CVR Refining was not responsible for payment of phantom unit allocated awards, and accordingly, the expense recorded for the year ended December 31, 2011 has been reflected as an increase to divisional equity.
	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 shares, restricted share units, dividend equivalent rights, share awards and performance awards (including performance share units, performance units and performance based restricted stock). As of December 31, 2013, only restricted shares of CVR Energy common stock, restricted stock units, performance units and stock options had been granted under the CVR Energy LTIP. 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, advisors 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 discussed in Note 1 ("Formation of the Partnership, Organization and Nature of Business") 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 of CVR Energy's common stock 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 year ended December 31, 2012. For awards vesting subsequent to 2012, the awards will be remeasured at each subsequent reporting date until they vest.
	In December 2012 and during 2013, awards of restricted stock units and dividend equivalent rights were granted to certain employees of CVR Energy and its subsidiaries (including CVR Refining). The awards are expected to vest over three years with one-third of the award vesting each year with the exception of awards granted to certain executive officers scheduled to vest over one year. Awards granted in December 2012 to Mr. Lipinski, CVR Energy's Chief Executive Officer and President, were canceled in connection with the issuance of certain performance unit awards as discussed further below. Each restricted stock unit and dividend equivalent right represents the right to receive, upon vesting, a cash payment equal to (a) the fair market value of one share of the CVR Energy's common stock, plus (b) the cash value of all dividends declared and paid per share of the 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.
	Assuming the allocation of costs from CVR Energy remains consistent with the allocation percentages in place at December 31, 2013, there was approximately $4.0 million of total unrecognized compensation cost related to restricted shares and associated dividends to be recognized over a weighted-average period of approximately 1.2 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 December 31, 2013, compensation expense has been allocated to the Partnership.
	Compensation expense recorded for the years ended December 31, 2013, 2012 and 2011, related to the restricted shares, was approximately $9.5 million, $18.5 million and $3.3 million, respectively. CVR Refining is not responsible for payment of CVR Energy restricted stock unit awards, and accordingly, the expenses recorded for the years ended December 31, 2013, 2012 and 2011 have been reflected as an increase to partners' capital/divisional equity.
	Performance Unit Awards
	In December 2013, CVR Energy entered into Performance Unit Award Agreements with Mr. Lipinski. Certain of the Performance Unit Awards were entered into in connection with the cancellation of Mr. Lipinski's December 2012 restricted stock unit award, as discussed above. In accordance with accounting guidance related to the modification of share-based and other compensatory award arrangements, CVR Energy concluded that the cancellation and concurrent issuance of the performance awards created a substantive service period from the original grant date of the December 2012 restricted stock unit award through the end of the performance period for the related performance awards. Compensation cost for these awards is being recognized over the substantive service period. Compensation expense recorded for the year ended December 31, 2013 related to the performance unit awards was $2.1 million. The Partnership will be responsible for reimbursing CVR Energy for its allocated portion of the performance unit awards.
	Incentive Unit Awards
	In December 2013, CVR Energy granted awards of incentive units and distribution equivalent rights to certain employees of CRLLC and CVR Energy. The awards are expected to vest over three years with one-third of the award vesting each year. Each incentive unit and distribution equivalent right represents the right to receive, upon vesting, a cash payment equal to (a) the average fair market value of one unit of the Partnership's common units for the first ten trading days in the month of vesting, plus (b) the per unit cash value of all distributions declared and paid by the Partnership from the grant date to and including the vesting date. The awards, which are liability-classified, will be remeasured at each subsequent reporting date until they vest.
	Assuming the allocation of costs from CVR Energy remains consistent with the allocation percentages in place at December 31, 2013, there was approximately $3.5 million of total unrecognized compensation cost related to the incentive units to be recognized over a weighted-average period of approximately 2.0 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 incentive units and respective allocation percentage for individuals for whom, as of December 31, 2013, compensation expense has been allocated to the Partnership. Compensation expense recorded for the year ended December 31, 2013 related to the incentive unit awards was not material. The Partnership will be responsible for reimbursing CVR Energy for its allocated portion of the incentive unit awards.
	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 (1) employees of the Partnership and its subsidiaries, (2) employees of the general partner, (3) members of the board of directors of the general partner and (4) certain employees, consultants and directors of CRLLC and CVR Energy who perform services solely for the benefit of the Partnership. 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.
	In December 2013, awards of phantom units and distribution equivalent rights were granted to employees of the Partnership and its subsidiaries, its general partner and certain employees of CRLLC and CVR Energy who perform services solely for the benefit of the Partnership. The awards are expected to vest over three years with one-third of the award vesting each year. Each phantom unit and distribution equivalent right represents the right to receive, upon vesting, a cash payment equal to (a) the average fair market value of one unit of the Partnership's common units for the first ten trading days in the month of vesting, plus (b) the per unit cash value of all distributions declared and paid by the Partnership from the grant date to and including the vesting date. The awards, which are liability-classified, will be remeasured at each subsequent reporting date until they vest.
	A summary of phantom unit activity and changes under the CVR Refining LTIP during the year ended December 31, 2013 is presented below:
		Phantom Units		Weighted-		Aggregate
				Average		Intrinsic
				Grant-Date		Value
				Fair Value
						(in millions)
	Non-vested at January 16, 2013	—		$	—	$	—
	Granted	187,177		21.55
	Vested	—		—
	Forfeited	—		—
	Non-vested at December 31, 2013	187,177		$	21.55	$	4.2
	As of December 31, 2013, there was approximately $4.2 million of total unrecognized compensation cost related to the awards under the CVR Refining LTIP to be recognized over a weighted-average period of 2.0 years. Compensation expense recorded for the year ended December 31, 2013 related to the awards under the CVR Refining LTIP was not material. As the phantom unit awards discussed above are cash-settled awards, they did not reduce the number of common units available for issuance under the plan. As of December 31, 2013, there were 11,070,000 common units available for issuance under the CVR Refining LTIP.

Inventories

Inventories	12 Months Ended
	Dec. 31, 2013
Inventory Disclosure [Abstract]	'
Inventories	'
	(6) Inventories
	Inventories consisted of the following:
		December 31,
		2013		2012
		(in millions)
	Finished goods	$	259	$	269.5
	Raw materials and precious metals	169.1		158.1
	In-process inventories	36.8		42.7
	Parts and supplies	28.8		29.2
		$	493.7	$	499.5

Property_Plant_and_Equipment

Property, Plant, and Equipment	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant, and Equipment	'
	(7) Property, Plant, and Equipment
	A summary of costs for property, plant, and equipment is as follows:
		December 31,
		2013		2012
		(in millions)
	Land and improvements	$	26.6	$	24
	Buildings	37.7		36.7
	Machinery and equipment	1,757.70		1,685.60
	Automotive equipment	18.4		14.3
	Furniture and fixtures	7.3		6.2
	Leasehold improvements	0.8		0.8
	Construction in progress	157.3		46
		2,005.80		1,813.60
	Accumulated depreciation	575.6		462
	Total property, plant and equipment, net	$	1,430.20	$	1,351.60
	Capitalized interest recognized as a reduction in interest expense for the years ended December 31, 2013, 2012 and 2011 totaled approximately $3.2 million, $3.0 million and $1.1 million, respectively. Land, building and equipment that are under a capital lease obligation had an original carrying value of approximately $24.8 million at both December 31, 2013 and 2012. Amortization of assets held under capital leases is included in depreciation expense.

Insurance_Claims

Insurance Claims	12 Months Ended
	Dec. 31, 2013
Insurance [Abstract]	'
Insurance Claims	'
	(8) Insurance Claims
	On December 28, 2010 the Coffeyville crude oil refinery experienced an equipment malfunction and small fire in connection with its fluid catalytic cracking unit ("FCCU"), which led to reduced crude oil throughput. The refinery returned to full operation on January 26, 2011. This interruption adversely impacted the production of refined products for the petroleum business in the first quarter of 2011. Total gross repair and other costs recorded related to the incident as of December 31, 2011 were approximately $8.0 million. No costs were recorded in 2013 or 2012.
	CVR Refining maintains property damage insurance policies through CVR Energy which have an associated deductible of $2.5 million. During 2011, the Company received $4.0 million in insurance proceeds and recorded an insurance receivable related to the incident of approximately $1.3 million, which is included in current assets in the Consolidated Balance Sheet as of December 31, 2012. The recording of the insurance proceeds and receivable resulted in a reduction of direct operating expenses (exclusive of depreciation and amortization). In February 2013, all insurance claims associated with the FCCU incident were fully settled and closed. Substantially all repair costs incurred in excess of the associated $2.5 million deductible were recovered by insurance.

LongTerm_Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Long-Term Debt	'
	(9) Long-Term Debt
	Long-term debt was as follows:
		December 31,
		2013		2012
		(in millions)
	10.875% Second Lien Senior Secured Notes, due 2017, net of unamortized discount of $1.8 million as of December 31, 2012	$	—	$	220.9
	6.5% Second Lien Senior Secured Notes, due 2022	500		500
	Intercompany credit facility	31.5		—
	Capital lease obligations	49.9		51.2
	Long-term debt	$	581.4	$	772.1
	Senior Secured Notes
	On April 6, 2010, CRLLC and its then wholly-owned subsidiary, Coffeyville Finance, completed a private offering of $275.0 million aggregate principal amount of 9.0% First Lien Senior Secured Notes due 2015 (the "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 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. The associated original issue discount of the Old Notes was amortized to interest expense and other financing costs over the respective terms of the Old Notes.
	On December 30, 2010, CRLLC made a voluntary unscheduled principal payment of approximately $27.5 million on the First Lien Notes that resulted in a premium payment of 3.0% and a partial write-off of previously deferred financing costs and unamortized original issue discount totaling approximately $1.6 million, which was recognized as a loss on extinguishment of debt in the Consolidated and Combined Statements of Operations in 2010. On May 16, 2011, CRLLC repurchased $2.7 million of the Old Notes at a purchase price of 103.0% of the outstanding principal amount. In connection with the repurchase, CRLLC wrote off a portion of previously deferred financing costs and unamortized original issue discount of approximately $89,000 which is recorded as a loss on extinguishment of debt for the year ended December 31, 2011. CRLLC also recorded additional losses on extinguishment of debt of $81,000 in connection with premiums paid for the repurchase. As the Old Notes were incurred for the benefit of the operations of CVR Refining, all the debt and associated costs were allocated to CVR Refining.
	On December 15, 2011, CRLLC and Coffeyville Finance issued 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 First Lien Notes issued in 2010, 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 associated original issue premium of $10.0 million for the Additional First Lien Notes has been amortized to interest expense and other financing costs over the term of the Additional First Lien Notes. The Additional First Lien Notes were offered in connection with CRLLC's acquisition of WEC. Proceeds of the Additional First Lien Notes were used to partially fund the Wynnewood Acquisition. On November 2, 2011, CRLLC entered into a commitment letter with certain lenders regarding a senior secured one year bridge loan (the "bridge loan"). CRLLC entered into the commitment letter in order to ensure that financing would be available for the Wynnewood Acquisition in the event that the offering of the Additional First Lien Notes was not closed by the date of closing of the Wynnewood Acquisition. Due to the closing of the issuance of the Additional First Lien Notes, the bridge loan commitment letter expired by its terms. At the closing of the issuance of the Additional First Lien Notes and the Wynnewood Acquisition, a commitment fee was paid to the lenders who provided the commitment. Other third-party costs were incurred. All costs associated with the undrawn bridge loan were fully expensed. In conjunction with the issuance of the Additional First Lien Notes, CRLLC expanded the then existing ABL credit facility (see "ABL Credit Facility" below for further discussion of the expansion and associated accounting treatment) and incurred a commitment fee and other third-party costs associated with the expansion.
	CRLLC received total net proceeds from the offering of approximately $202.8 million, net of an underwriting discount of $4.0 million, bridge loan commitment and other associated fees of $3.3 million, an ABL commitment fee of $2.6 million, an Additional First Lien Notes structuring fee of $0.2 million, and certain third party fees of $0.8 million. The related original issue premium and other debt issuance costs related to the Additional First Lien Notes were amortized over the remaining term of the First Lien Notes. Fees and third-party costs totaling $3.9 million related to the bridge loan commitment were expensed for the year ended December 31, 2011 and are included in selling, general and administrative expenses (exclusive of depreciation and amortization) on the Consolidated and Combined Statements of Operations. Fees and third-party costs associated with the ABL credit facility expansion were amortized over the remaining term of the facility.
	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 offer for and 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 year ended December 31, 2013 which includes the write-off of previously deferred financing fees of $3.7 million and unamortized original issue discount of $1.8 million.
	The change of control discussed in Note 1 ("Formation of the Partnership, Organization and Nature of Business") required CVR Energy to make an offer to repurchase all of the Issuers' outstanding Old Notes. On June 4, 2012, the issuers offered to purchase all or any part of the Old Notes, at a cash purchase price of 101% of the aggregate principal amount of the Old Notes, plus accrued and unpaid interest, if any. The offer expired on July 5, 2012 with none of the outstanding Old Notes tendered.
	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 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. Accordingly, the 2022 Notes are no longer secured. 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 fund a completed and settled redemption of 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 these transactions, a loss on extinguishment of debt of $33.4 million was recorded in the Consolidated and Combined Statements of Operations in the fourth quarter of 2012, which includes 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 $0.4 million of debt registration costs related to the registration and exchange offer during the year ended December 31, 2013, 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 December 31, 2013, the Partnership was in compliance with the covenants contained in the 2022 Notes.
	Included in other current liabilities on the Consolidated Balance Sheets is accrued interest payable totaling approximately $5.4 million and $12.2 million for the years ended December 31, 2013 and 2012, respectively, related to the Old Notes and 2022 Notes. At December 31, 2013, the estimated fair value of the 2022 Notes was approximately $491.3 million. This estimate of fair value is Level 2 as it was determined by quotations obtained from a broker-dealer who makes a market in these and similar securities.
	Asset Backed (ABL) Credit Facility
	On February 22, 2011, CRLLC entered into a $250.0 million asset-backed revolving credit agreement (the "ABL credit facility") with a group of lenders including Deutsche Bank Trust Company Americas as collateral and administrative agent. This ABL credit facility, which was scheduled to mature in August 2015, replaced the $150.0 million first priority credit facility which was terminated. The ABL credit facility was used to finance ongoing working capital, capital expenditures, letters of credit issuance and general needs of CVR Refining and includes, among other things, a letter of credit sublimit equal to 90% of the total facility commitment and a feature which permits an increase in borrowings of up to $250.0 million (in the aggregate), subject to additional lender commitments. On December 15, 2011, CRLLC entered into an incremental commitment agreement to increase the borrowings under the ABL credit facility to $400.0 million in the aggregate in connection with the Additional First Lien Notes issuance as discussed above. Terms of the ABL credit facility did not change as a result of the additional availability. On December 20, 2012, the ABL credit facility was amended and restated as discussed below.
	In connection with the ABL credit facility, CRLLC incurred lender and other third-party costs of approximately $9.1 million for the year ended December 31, 2011. As the ABL credit facility was incurred for the benefit of the operations of CVR Refining, all the debt and associated costs have been allocated to CVR Refining. These costs were deferred and amortized to interest expense and other financing costs using a straight-line method over the term of the facility. In connection with termination of the first priority credit facility, a portion of the unamortized deferred financing costs associated with this facility, totaling approximately $1.9 million, were written off in the first quarter of 2011. In accordance with guidance provided by the FASB regarding the modification of revolving debt arrangements, the remaining approximately $0.8 million of unamortized deferred financing costs associated with the first priority credit facility were amortized over the term of the ABL credit facility.
	In connection with the closing of CVR Partners' initial public offering in April 2011, CVR Partners and CRNF were released as guarantors of the ABL credit facility.
	In connection with the change in control described in Note 1 ("Formation of the Partnership, Organization and Nature of Business") above, CRLLC, Deutsche Bank Trust Company Americas, as Administrative Agent and Collateral Agent, the lenders and the other parties thereto, entered into a First Amendment to Credit Agreement effective as of May 7, 2012 (the "ABL First Amendment"), pursuant to which the parties agreed to exclude IEP's acquisition of common stock from the definition of change of control as provided in the ABL credit facility.
	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 replaced the ABL credit facility described above and 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, as further discussed in Note 1 ("Formation of the Partnership, Organization and Nature of Business").
	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 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 swing line 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 is also 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 under the facility. The Credit Parties were in compliance with the covenants of the Amended and Restated ABL Credit Facility as of December 31, 2013.
	In connection with the Amended and Restated ABL Credit Facility, CRLLC and its subsidiaries incurred lender and other third-party costs of approximately $2.1 million for the year ended December 31, 2012. These costs are being deferred and amortized to interest expense and other financing costs using a straight-line method over the term of the amended facility. In connection with amendment of the ABL credit facility, a portion of the unamortized deferred financing costs associated with the ABL Credit Facility, totaling approximately $4.1 million, were written off in the fourth quarter of 2012. This expense is reflected on the Consolidated and Combined Statements of Operations as a loss on extinguishment of debt for the year ended December 31, 2012. In accordance with guidance provided by the FASB regarding the modification of revolving debt arrangements, the remaining approximately $2.8 million of unamortized deferred financing costs associated with the ABL credit facility will continue to be amortized over the term of the Amended and Restated ABL credit facility.
	As of December 31, 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 December 31, 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 December 31, 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 December 31, 2013, the Partnership had borrowings of $31.5 million outstanding and $118.5 million available under the intercompany credit facility. Accrued interest payable included in other current liabilities on the Consolidated Balance Sheets as of December 31, 2013 is not material.
	Deferred Financing Costs
	For the years ended December 31, 2013, 2012 and 2011, amortization of deferred financing costs reported as interest expense and other financing costs totaled approximately $2.0 million, $4.1 million and $4.2 million, respectively.
	Estimated amortization of deferred financing costs is as follows:
	Year Ending December 31,	Deferred
		Financing
		(in millions)
	2014	$	1.9
	2015	1.9
	2016	1.9
	2017	1.8
	2018	0.9
	Thereafter	3.5
		$	11.9
	Capital Lease Obligations
	As a result of the Wynnewood Acquisition, CVR Refining acquired certain lease assets and assumed related capital lease obligations related to the 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 190 months remaining through September 2029. The financing agreement relates to the Magellan Pipeline terminals, bulk terminal and loading facility. The lease has 189 months remaining and will expire in September 2029. As of December 31, 2013, the outstanding obligation associated with these arrangements totaled approximately $51.2 million, of which $49.9 million is included in long-term liabilities and $1.3 million is included in current liabilities in the Consolidated Balance Sheets.
	Future payments required under capital lease at December 31, 2013 are as follows:
	Year Ending December 31,	Capital Lease
		(in millions)
	2014	$	6.3
	2015	6.4
	2016	6.4
	2017	6.4
	2018	6.5
2019 and thereafter	70.3
Total future payments	102.3
Less: amount representing interest	51.1
Present value of future minimum payments	51.2
Less: current portion	1.3
Long-term portion	$	49.9

Partners_Capital_and_Partnersh

Partners' Capital and Partnership Distributions	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
Partners' Capital and Partnership Distributions	'
	(10) Partners’ Capital and Partnership Distributions
	The Partnership had two types of partnership interests outstanding at December 31, 2013:
	•	common units; and
	•	a general partner interest, which is not entitled to any distributions, and which is held by the general partner.
	At December 31, 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		30-Sep-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	$	33.2	$	378.7
	Amounts paid to non-affiliates	37.3		49.7		11.1		98
	Total amount paid	$	233.2	$	199.3	$	44.3	$	476.7
	Per common unit	$	1.58	$	1.35	$	0.3	$	3.23
	Common units outstanding	147.6		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	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Net Income per Common Unit	'
	(11) Net Income per Common Unit
	The net income per common unit on the 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 December 31, 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. There were no dilutive awards outstanding during the year ended December 31, 2013, as all unvested awards under the CVR Refining LTIP were liability-classified awards.
	The following table illustrates the Partnership's calculation of net income per common unit:
		January 23, 2013 to
		31-Dec-13
		(in millions, except per unit data)
	Net income (from the closing of the offering on January 23, 2013 to December 31, 2013)	$	512.6
	Net income per common unit, basic	$	3.47
	Net income per common unit, diluted	$	3.47
	Weighted-average common units outstanding, basic	147.6
	Weighted-average common units outstanding, diluted	147.6

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	(12) 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 consolidated and combined financial statements of the Partnership.
	Under ASC Topic 740, Income Taxes ("ASC 740"), taxes based on income like the Texas franchise tax are accounted for using the liability method under which deferred income taxes are recognized for the future tax effects of temporary differences between the financial statement carrying amounts and the tax basis of existing assets and liabilities using the enacted statutory tax rates in effect at the end of the period. A valuation allowance for deferred tax assets is recorded when it is more likely than not that the benefit from the deferred tax asset will not be realized. As of December 31, 2013 and 2012, the Partnership has no material tax balances associated with the Texas franchise tax.

Benefit_Plans

Benefit Plans	12 Months Ended
	Dec. 31, 2013
Compensation and Retirement Disclosure [Abstract]	'
Benefit Plans	'
	(13) Benefit Plans
	As of December 31, 2013, CVR Energy sponsored two defined-contribution 401(k) plans (the "Plans") in which all employees of CVR Refining may participate. Participants in the Plans may elect to contribute up to 50% of their annual salaries and up to 100% of their annual income sharing. The Partnership matches up to 100% of the first 6% of the participant's contribution for the union and nonunion plans. Both Plans are administered by CVR Energy and contributions for the union plans were determined in accordance with provisions of negotiated labor contracts. Participants in both Plans are immediately vested in their individual contributions. Both Plans have a three-year vesting schedule for matching funds and contain a provision to count service with any predecessor organization. The Partnership's contributions under the Plans for employees of CVR Refining were approximately $4.2 million, $3.3 million and $1.4 million for the years ended December 31, 2013, 2012 and 2011, respectively.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	(14) Commitments and Contingencies
	The minimum required payments for CVR Refining's operating lease agreements and unconditional purchase obligations are as follows:
	Year Ending December 31,	Operating		Unconditional
		Leases		Purchase
				Obligations(1)
		(in millions)
	2014	$	2.5	$	110.8
	2015	1.5		104.9
	2016	1		97.8
	2017	0.3		96.5
	2018	0.1		96.6
	Thereafter	0.3		874.5
		$	5.7	$	1,381.10
	-1	This amount includes approximately $973.0 million payable ratably over seventeen 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, including real properties under long-term operating leases expiring at various dates. For the years ended December 31, 2013, 2012 and 2011, lease expense totaled approximately $3.2 million, $2.9 million and $1.4 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, CVR Refining has long-term commitments to purchase storage capacity and pipeline transportation services. For the years ended December 31, 2013, 2012 and 2011, total expense of $117.1 million, $107.5 million and $83.1 million, respectively was incurred related to long-term commitments.
	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"). Under the Vitol Agreement, Vitol supplies the petroleum business 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 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 within the next year 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 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.
	Samson Resources Company, Samson Lone Star, LLC and Samson Contour Energy E&P, LLC (together, "Samson") filed fifteen lawsuits in federal and state courts in Oklahoma and two lawsuits in state courts in New Mexico against CRRM and other defendants between March 2009 and July 2009. In addition, in May 2010, separate groups of plaintiffs (the "Anstine and Arrow cases") filed two lawsuits against CRRM and other defendants in state court in Oklahoma and Kansas. All of the lawsuits filed in state court were removed to federal court. All of the lawsuits (except for the New Mexico suits, which remained in federal court in New Mexico) were then transferred to the Bankruptcy Court for the United States District Court for the District of Delaware, where the SemGroup bankruptcy resides. In March 2011, CRRM was dismissed without prejudice from the New Mexico suits. All of the lawsuits alleged that Samson or other respective plaintiffs sold crude oil to a group of companies, which generally are known as SemCrude or SemGroup (collectively, "Sem"), which later declared bankruptcy and that Sem did not pay such plaintiffs for all of the crude oil purchased from Sem. The Samson lawsuits further alleged that Sem sold some of the crude oil purchased from Samson to J. Aron & Company ("J. Aron") and that J. Aron sold some of this crude oil to CRRM. All of the lawsuits sought the same remedy, the imposition of a trust, an accounting and the return of crude oil or the proceeds therefrom. The amount of the plaintiffs' alleged claims was unknown since the price and amount of crude oil sold by the plaintiffs and eventually received by CRRM through Sem and J. Aron, if any, was unknown. CRRM timely paid for all crude oil purchased from J. Aron. On January 26, 2011, CRRM and J. Aron entered into an agreement whereby J. Aron agreed to indemnify and defend CRRM from any damage, out-of-pocket expense or loss in connection with any crude oil involved in the lawsuits which CRRM purchased through J. Aron, and J. Aron agreed to reimburse CRRM's prior attorney fees and out-of-pocket expenses in connection with the lawsuits. The indemnification agreement does not provide reimbursement for any damages that CRRM may be liable for in connection with any purchases it made directly from Sem. Samson and CRRM entered a stipulation of dismissal with respect to all of the Samson cases and the Samson cases were dismissed with prejudice on February 8, 2012. In February 2013, CRRM agreed to a settlement in the Anstine and Arrow cases which was finalized with the plaintiffs in June 2013, and CRRM was dismissed with prejudice. The settlement did not have a material adverse effect on the consolidated and combined financial statements.
	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 shutdown and secure the refinery in preparation for the flood that occurred on June 30, 2007. In connection with the discharge, CVR Refining received in May 2008, 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 consolidated and combined financial statements. CVR Refining believes that the resolution of the remaining claim will not have a material adverse effect on the consolidated and combined financial statements.
	As a result of the crude oil discharge that occurred on July 1, 2007, CVR Refining entered into an administrative order on consent (the "Consent Order") with the EPA on July 10, 2007. As set forth in the Consent Order, the U.S. Environmental Protection Agency (the "EPA") concluded that the discharge of crude oil from CVR Refining's Coffeyville refinery caused an imminent and substantial threat to the public health and welfare. Pursuant to the Consent Order, CVR Refining agreed to perform specified remedial actions to respond to the discharge of crude oil from CVR Refining's refinery. The substantial majority of all required remedial actions were completed by January 31, 2009. CVR Refining prepared and provided its final report to the EPA in January 2011 to satisfy the final requirement of the Consent Order. In April 2011, the EPA provided CVR Refining with a notice of completion indicating that CVR Refining has no continuing obligations under the Consent Order, while reserving its rights to recover oversight costs and penalties.
	On October 25, 2010, CVR Refining received a letter from the United States Coast Guard on behalf of 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 has reached an agreement with the DOJ resolving its claims under 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 related to the CWA claims 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 claims related to the alleged non-compliance with RMP. The agreement is memorialized in a separate consent decree that 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 claims. The RMP consent decree also requires CRRM to conduct several audits related to compliance with RMP requirements.
	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 potential governmental oversight costs arising from oil spills into the waters of the United States, which has been broadly interpreted to include most water bodies including intermittent streams.
	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 the RCRA to address historical contamination by the prior owners (RCRA Docket No. VII-94-H-20 and Docket No. VII-95-H-11, respectively). As of December 31, 2013 and 2012, environmental accruals of approximately $1.5 million and $2.3 million, respectively, were reflected in the Consolidated Balance Sheets for probable and estimated costs for remediation of environmental contamination under the RCRA Administrative Orders, for which approximately $0.3 million and $0.7 million, respectively, are included in other current liabilities. 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 December 31, 2013 and 2012, respectively. The accruals include estimated closure and post-closure costs of approximately $0.7 million and $0.8 million for two landfills at December 31, 2013 and 2012, respectively. The estimated future payments for these required obligations are as follows:
	Year Ending December 31,	Amount
		(in millions)
	2014	$	0.3
	2015	0.2
	2016	0.1
	2017	0.1
	2018	0.1
	Thereafter	1
	Undiscounted total	1.8
	Less amounts representing interest at 2.73%	0.3
	Accrued environmental liabilities at December 31, 2013	$	1.5
	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 triggered the loss of small refiner status. Accordingly, the MSAT II projects have been accelerated by three months. 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 December 31, 2013, approximately $24.6 million and $52.2 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. Due to mandates in the RFS requiring increasing volumes of renewable fuels to replace petroleum products in the U.S. motor fuel market, there may be a decrease in demand for petroleum products. 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. In 2013, the Wynnewood refinery was subject to the RFS for the first time. However, because the cost of purchasing RINs has been extremely volatile and has significantly increased over the last year, the Wynnewood refinery has petitioned the EPA as a "small refinery" for hardship relief from the RFS requirements in 2013 and 2014 based on the "disproportionate economic impact" 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 was extremely volatile in 2013, as the EPA's proposed 2013 renewable fuel volume mandates approached the "blend wall." The blend wall refers to the point at which refiners are required to blend more ethanol into the transportation fuel supply than can be supported by demand for E10 gasoline (gasoline containing 10 percent ethanol by volume). The EPA has published the proposed volume mandates for 2014, which acknowledge the blend wall and are generally lower than the volumes for 2013 and lower than statutory mandates. The price of RINs decreased significantly after the 2014 mandate was published; however, RIN prices have remained volatile and have increased in 2014. The cost of RINs for the years ended December 31, 2013, 2012 and 2011 was approximately $180.5 million, $21.0 million and $19.0 million, respectively. As of December 31, 2013 and 2012, CVR Refining’s biofuel blending obligation was approximately $17.4 million and $1.1 million, respectively, which is recorded in accrued expenses and other current liabilities in the Consolidated Balance Sheets. The future cost of RINs for CRRM and WRC going forward is difficult to estimate. In particular, the cost of RINs is dependent upon a variety of factors, which include the availability of RINs for purchase, the price at which RINs can be purchased, transportation fuel production levels, the mix of petroleum products, as well as the fuel blending performed at the 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 was entered by the U.S. District Court for the District of Kansas on April 19, 2012. 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.
	WRC entered into a Consent Order with the Oklahoma Department of Environmental Quality ("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. 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 air inspections of the Wynnewood refinery and pursues enforcement related to any alleged non-compliance seeking civil penalties and injunctive relief, which may necessitate the installation of controls. In January 2014, ODEQ issued a full compliance evaluation report covering the period from December 2010 to June 2013, which covers periods of the previous owner's ownership and operation and, in some cases, continued into CVR Refining's ownership of the Wynnewood refinery. ODEQ has indicated that it will pursue enforcement related to the alleged non-compliance and that it expects to enter into a second consent order with WRC, which would necessitate the payment of a civil penalty and the implementation of injunctive relief to address the alleged non-compliance. The costs of any such enforcement action cannot be predicted at this time. However, based on its experience related to Clean Air Act enforcement and control requirements, CVR Refining 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 ("OPDES") 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 its experience with wastewater treatment and controls, CVR Refining does not anticipate that the costs of any required additional controls or operational changes would be material.
	In January 2014, ODEQ issued a Notice of Violation to the Wynnewood refinery related to alleged violations of its OPDES permit. The costs of any related enforcement action cannot be predicted at this time. However, based on CVR Refining's experience related to CWA enforcement, it does not anticipate that the costs of any civil penalties, required additional controls or operation changes would be material.
	In January 2014, the EPA also issued an inspection report to the Wynnewood refinery related to a RCRA compliance evaluation inspection conducted in March 2013. The inspection report identified areas of concern for which the EPA may take enforcement action. The costs of any related enforcement action cannot be predicted at this time. However, based on CVR Refining's experiences related to RCRA enforcement, it does not anticipate that the costs of any civil penalties, 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 years ended December 31, 2013, 2012 and 2011, capital expenditures were approximately $111.3 million, $27.9 million and $7.4 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 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 startup 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. CVR Refining 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 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	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	(15) Fair Value Measurements
	ASC Topic 820 — Fair Value Measurements and Disclosures ("ASC 820") established a single authoritative definition of fair value when accounting rules require the use of fair value, set out a framework for measuring fair value and required additional disclosures about fair value measurements. ASC 820 clarifies that fair value is an exit price, representing the amount from the perspective of a market participant that holds the asset or owes the liability at the measurement date.
	ASC 820 discusses valuation techniques, such as the market approach (prices and other relevant information generated by market transactions involving identical or comparable assets, liabilities or a group of assets and liabilities such as a business), the income approach (techniques to convert future amounts to a single current amount based on market expectations about those future amounts including present value techniques and option pricing), and the cost approach (amount that would be required currently to replace the service capacity of an asset which is often referred to as a replacement cost). 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 or liabilities
	•	Level 2 — Other significant observable inputs (including quoted prices in active markets for similar assets or liabilities)
	•	Level 3 — Significant unobservable inputs (including CVR Refining'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 December 31, 2013 and 2012:
		December 31, 2013
		Level 1		Level 2			Level 3		Total
		(in millions)
	Location and Description
	Other current assets (derivative agreements)	$	—	$	0.9		$	—	$	0.9
	Other long-term assets (derivative agreements)	—		0.1			—		0.1
	Total Assets	$	—	$	1		$	—	$	1
	Other current liabilities (derivative agreements)	—		(15.3		)	—		(15.3		)
	Other current liabilities (biofuel blending obligation)	—		(16.2		)	—		(16.2		)
	Other long-term liabilities (derivative agreements)	—		(1.8		)	—		(1.8		)
	Total Liabilities	$	—	$	(33.3	)	$	—	$	(33.3	)
		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 December 31, 2013 and 2012, the only financial assets and liabilities that are measured at fair value on a recurring basis are CVR Refining's derivative instruments and uncommitted biofuel blending obligation. Additionally, the fair value of the debt issuances is disclosed in Note 9 ("Long-Term Debt"). The commodity derivative contracts and the uncommitted biofuel blending obligation, which use fair value measurements and are valued using broker quoted market prices of similar instruments, are considered level 2 inputs. CVR Refining had no transfers of assets or liabilities between any of the above levels during the year ended December 31, 2013.

Derivatives_and_Financial_Inst

Derivatives and Financial Instruments	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivatives and Financial Instruments	'
	(16) Derivative Financial Instruments
	Gain (loss) on derivatives, net and current period settlements on derivative contracts were as follows:
		Year Ended December 31,
		2013		2012			2011
		(in millions)
	Current period settlements on derivative contracts	$	6.4	$	(137.6	)	$	(7.2	)
	Gain (loss) on derivatives, net	57.1		(285.6		)	78.1
	CVR Refining is subject to price fluctuations caused by supply conditions, weather, economic conditions, interest rate fluctuations 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 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 Consolidated Balance Sheets. The maintenance margin balance is included within other current assets within the Consolidated Balance Sheets. Dependent upon the position of the open commodity derivatives, the amounts are accounted for as other current assets or other current liabilities within the 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 December 31, 2013 was an immaterial net gain included in other current assets. For the year ended December 31, 2013, 2012 and 2011, CVR Refining recognized net losses of $2.9 million, $11.7 million and $2.6 million, respectively, which are recorded in gain (loss) on derivatives, net in the Consolidated and Combined Statement 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 Consolidated Balance Sheets with changes in fair value currently recognized in the 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 both December 31, 2013 and 2012, CVR Refining had open commodity hedging instruments consisting of 23.3 million barrels of crack spreads primarily to fix the margin on a portion of its future gasoline and distillate production. The fair value of the outstanding contracts at December 31, 2013 was a net unrealized loss of $16.1 million, of which $0.9 million is included in current assets, $0.1 million is included in other long-term assets, $15.3 million is included in current liabilities and $1.8 million is included in other long-term liabilities. The fair value of the outstanding contracts at December 31, 2012 was a net unrealized loss of $66.8 million, $67.7 million of which is included in current liabilities and $0.9 million is included in other long-term assets. For the years ended December 31, 2013, 2012 and 2011, the Partnership recognized a net gain of $60.1 million, a net loss of $273.9 million and a net gain of $80.4 million, respectively, which are recorded in gain (loss) on derivatives, net in the 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. CVR Refining 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. CVR Refining 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 Consolidated Balance Sheets. As of December 31, 2013, the counterparty credit risk adjustment was not material to the consolidated and combined financial statements. Additionally, CVR Refining 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 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 Consolidated Balance Sheets for the various types of open derivative positions.
	The offsetting assets and liabilities for CVR Refining’s derivatives as of December 31, 2013 are recorded as current assets, non-current assets, current liabilities and non-current liabilities in prepaid expenses and other current assets, other long-term assets, accrued expenses and other current liabilities and other long-term liabilities, respectively, in the Consolidated Balance Sheets as follows:
		As of December 31, 2013
	Description	Gross Current Assets		Gross			Net			Cash		Net
				Amounts			Current Assets			Collateral		Amount
				Offset			Presented			Not Offset
		(in millions)
	Commodity Swaps	$	4.3	$	(3.4	)	$	0.9		$	—	$	0.9
	Total	$	4.3	$	(3.4	)	$	0.9		$	—	$	0.9
		As of December 31, 2013
	Description	Gross Non-Current Assets		Gross			Net			Cash		Net
				Amounts			Non-Current Assets			Collateral		Amount
				Offset			Presented			Not Offset
		(in millions)
	Commodity Swaps	$	0.1	$	—		$	0.1		$	—	$	0.1
	Total	$	0.1	$	—		$	0.1		$	—	$	0.1
		As of December 31, 2013
	Description	Gross Current Liabilities		Gross			Net			Cash		Net
				Amounts			Current Liabilities			Collateral		Amount
				Offset			Presented			Not Offset
		(in millions)
	Commodity Swaps	$	31.4	$	(16.1	)	$	15.3		$	—	$	15.3
	Total	$	31.4	$	(16.1	)	$	15.3		$	—	$	15.3
		As of December 31, 2013
	Description	Gross Non-Current Liabilities		Gross			Net			Cash		Net
				Amounts			Non-Current Liabilities			Collateral		Amount
				Offset			Presented			Not Offset
		(in millions)
	Commodity Swaps	$	1.9	$	(0.1	)	$	1.8		$	—	$	1.8
	Total	$	1.9	$	(0.1	)	$	1.8		$	—	$	1.8
	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 Consolidated Balance Sheets and as current liabilities in other current liabilities in the 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

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	(17) Related Party Transactions
	In connection with the formation of CVR Refining in September 2012, CVR Refining and CRRM entered into an agreement with CVR Energy and its subsidiaries that governs 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 December 31, 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 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, and other long-term liabilities, on CVR Refining's Consolidated Balance Sheets.
	Feedstock and Shared Services Agreement
	CRRM entered into a feedstock and shared services agreement with CRNF, which was amended on December 30, 2013, 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 years ended December 31, 2013, 2012 and 2011, the net sales generated from the sale of hydrogen to CRNF were approximately $0.6 million, $0.2 million and $1.0 million, respectively. For the years ended December 31, 2013, 2012 and 2011, CVR Refining also recognized $11.4 million, $6.3 million and $14.2 million, respectively, of cost of product sold (exclusive of depreciation and amortization) related to the purchase of excess hydrogen from the nitrogen fertilizer facility. At December 31, 2013 and 2012, approximately $2.6 million and $0.2 million, respectively, of payables were included in accounts payable on the 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 years ended December 31, 2013, 2012 and 2011 were approximately $(0.1) million, $10,000 and $0.2 million, 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 years ended December 31, 2013, 2012 and 2011, were approximately $0.5 million, $1.4 million and $1.5 million, respectively. No amounts were paid by CRNF to CRRM for any of the years.
	The agreement also provides a mechanism pursuant to which CRNF transfers a tail gas stream to CRRM. For each of the years ended December 31, 2013, 2012 and 2011 CRRM recognized approximately $0.2 million 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 December 31, 2013 and 2012, an asset of approximately $0.3 million and $0.5 million 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 $1.1 million and $1.3 million, respectively, in other non-current liabilities in the Consolidated Balance Sheets.
	CRNF also provided finished product tank capacity to CRRM under the agreement. Approximately $0.3 million, $0.1 million and $0.3 million, respectively, was incurred by CRRM for the use of tank capacity for the year ended December 31, 2013, 2012 and 2011. 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 December 31, 2013 and 2012, payables of $0.3 million and $0.4 million, respectively, were included in accounts payable on the 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 December 31, 2013 and 2012, receivables of $1.0 million and $0.4 million, respectively, were included in prepaid expenses and other current assets on the 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 $9.6 million, $9.9 million and $11.4 million for the years ended December 31, 2013, 2012 and 2011, respectively. Receivables of $0.6 million related to the coke supply agreement were included in accounts receivable on the Consolidated Balance Sheets at both December 31, 2013 and 2012, respectively.
	Terminal and Operating Lease Agreement
	On May 4, 2012, CRT entered into a lease and operating 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 years ended December 31, 2013 and 2012, revenue related to the terminal operating and lease agreement totaled approximately $0.1 million and $18,000, respectively.
	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 each of the years ended December 31, 2013, 2012 and 2011, 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 are 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 certain 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 certain 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 year ended December 31, 2013 were approximately $87.3 million. Of these charges approximately $62.1 million were included in selling, general and administrative expenses (exclusive of depreciation and amortization). In addition, $25.2 million were included in direct operating expenses (exclusive of depreciation and amortization). At December 31, 2013, payables of $14.8 million were included in accounts payable on the Consolidated Balance Sheets with respect to amounts billed in accordance with the services agreement. See Note 3 ("Summary of Significant Accounting Policies") - "Allocation of Costs" for costs allocated to CVR Refining for the year ended December 31, 2012 and 2011 prior to this services agreement going into effect.
	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 year ended December 31, 2013, approximately $0.3 million 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 December 31, 2013, the Partnership had borrowings of $31.5 million outstanding. See Note 9 ("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 year ended December 31, 2013, the Refining Partnership purchased seven trucks from a subsidiary of Navistar International Corporation ("Navistar") for approximately $0.8 million.
	Financing and Other
	For the year ended December 31, 2011, CVR Refining recognized approximately $0.5 million in expenses for the benefit of GS, Kelso Investment Associates VII, L.P. and related entities, and the president, chief executive officer and chairman of the Board of CVR Energy, in connection with CVR Energy's Registration Rights Agreement. These amounts included registration and filing fees, printing fees, external accounting fees and external legal fees.

Major_Customers_and_Suppliers

Major Customers and Suppliers	12 Months Ended
	Dec. 31, 2013
Major Customers and Suppliers	'
Major Customers and Suppliers	'
	(18) Major Customers and Suppliers
	Sales to major customers were as follows:
		Year Ended December 31,
		2013		2012		2011
	Customer A	12	%	10	%	15	%
	Customer B	9	%	9	%	12	%
		21	%	19	%	27	%
	CRRM obtained crude oil from one supplier under a long-term supply agreement during 2013, 2012 and 2011. Volume contracted as a percentage of the total crude oil purchases (in barrels) for each of the periods was as follows:
		Year Ended December 31,
		2013		2012		2011
	Supplier A	69	%	45	%	65	%

Selected_Quarterly_Financial_I

Selected Quarterly Financial Information (unaudited)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Selected Quarterly Financial Information (unaudited)	'
	(19) Selected Quarterly Financial Information (unaudited)
	Summarized quarterly financial data for December 31, 2013 and 2012:
		Year Ended December 31, 2013
		Quarter
		First			Second			Third			Fourth
		(in millions, except per unit data)
	Net sales	$	2,274.00		$	2,138.10		$	1,910.50		$	2,360.90
	Operating costs and expenses:
	Cost of product sold (exclusive of depreciation and amortization)	1,805.80			1,776.60			1,734.70			2,209.70
	Direct operating expenses (exclusive of depreciation and amortization)	86			83.8			104.7			87.2
	Selling, general and administrative (exclusive of depreciation and amortization)	18.6			20.2			18.9			20
	Depreciation and amortization	28			28.4			28.8			29.1
	Total operating costs and expenses	1,938.40			1,909.00			1,887.10			2,346.00
	Operating income	335.6			229.1			23.4			14.9
	Other income (expense):
	Interest expense and other financing costs	(14.2		)	(10.6		)	(10.0		)	(9.3		)
	Interest income	0.1			0.1			0.1			0.1
	Gain (loss) on derivatives, net	(20.0		)	120.5			72.5			(115.9		)
	Loss on extinguishment of debt	(26.1		)	—			—			—
	Other income, net	—			0.1			—			—
	Total other income (expense)	(60.2		)	110.1			62.6			(125.1		)
	Income before income tax expense	275.4			339.2			86			(110.2		)
	Income taxes	—			—			—			—
	Net income (loss)	$	275.4		$	339.2		$	86		$	(110.2	)
	Net income (loss) subsequent to initial public offering (January 23, 2013 through December 31, 2013)	$	197.5		$	339.2		$	86		$	(110.2	)
	Net income (loss) per common unit - basic	$	1.34		$	2.3		$	0.58		$	(0.75	)
	Net income (loss) per common unit - diluted	$	1.34		$	2.3		$	0.58		$	(0.75	)
	Weighted-average common units outstanding:
	Basic	147.6			147.6			147.6			147.6
	Diluted	147.6			147.6			147.6			147.6
		Year Ended December 31, 2012
		Quarter
		First			Second			Third			Fourth
		(in millions)
	Net sales	$	1,898.50		$	2,229.60		$	2,337.40		$	1,816.20
	Operating costs and expenses:
	Cost of product sold (exclusive of depreciation and amortization)	1,630.70			1,866.20			1,694.10			1,476.50
	Direct operating expenses (exclusive of depreciation and amortization)	92.7			71.6			88.8			173.4
	Selling, general and administrative (exclusive of depreciation and amortization)	20.2			26.1			21.2			18.6
	Depreciation and amortization	26.3			26.6			27.5			27.3
	Total operating costs and expenses	1,769.90			1,990.50			1,831.60			1,695.80
	Operating income	128.6			239.1			505.8			120.4
	Other income (expense):
	Interest expense and other financing costs	(18.8		)	(19.0		)	(18.2		)	(20.2		)
	Interest income	—			—			—			—
	Gain (loss) on derivatives, net	(147.2		)	38.8			(168.9		)	(8.2		)
	Loss on extinguishment of debt	—			—			—			(37.5		)
	Other income (expense), net	—			0.6			(0.1		)	0.1
	Total other income (expense)	(166.0		)	20.4			(187.2		)	(65.8		)
	Income before income tax expense	(37.4		)	259.5			318.6			54.6
	Income taxes	—			—			—			—
	Net income (loss)	$	(37.4	)	$	259.5		$	318.6		$	54.6

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events	'
	(20) Subsequent Events
	Distribution
	On February 19, 2014, the board of directors of the Partnership’s general partner declared a cash distribution for the fourth quarter of 2013 to the Partnership’s unitholders of $0.45 per common unit, or $66.4 million in aggregate. The cash distribution will be paid on March 10, 2014 to unitholders of record at the close of business on March 3, 2014.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Cash and Cash Equivalents	'
	Cash and Cash Equivalents
	CRLLC historically provided cash as needed to support the operations of the refining and related logistics assets and retained excess cash earned by the Partnership. The Partnership considers all highly liquid money market accounts and debt instruments with original maturities of three months or less to be cash equivalents. Cash received or paid by CRLLC on behalf of CVR Refining prior to December 31, 2012 is reflected as net contributions from or net distributions to parent on the accompanying Consolidated and Combined Statements of Changes in Partners' Capital/Divisional Equity. Effective December 31, 2012, the Partnership began operating with an independent capital structure.
	Under the Partnership's cash management system, checks issued but not presented to banks frequently result in book overdraft balances for accounting purposes and are classified within accounts payable in the Consolidated Balance Sheets. The change in book overdrafts are reported in the Consolidated and Combined Statements of Cash Flows as a component of operating cash flows for accounts payable as they do not represent bank overdrafts.
Accounts Receivable, net	'
	Accounts Receivable, net
	CVR Refining grants credit to its customers. Credit is extended based on an evaluation of a customer's financial condition; generally, collateral is not required. Accounts receivable are due on negotiated terms and are stated at amounts due from customers, net of an allowance for doubtful accounts. Accounts outstanding longer than their contractual payment terms are considered past due. CVR Refining determines its allowance for doubtful accounts by considering a number of factors, including the length of time trade accounts are past due, the customer's ability to pay its obligations to CVR Refining, and the condition of the general economy and the industry as a whole. CVR Refining writes off accounts receivable when they become uncollectible, and payments subsequently received on such receivables are credited to the allowance for doubtful accounts. Amounts collected on accounts receivable are included in net cash provided by operating activities in the Consolidated and Combined Statements of Cash Flows.
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 byproducts 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.
Prepaid Expenses and Other Current Assets	'
	Prepaid Expenses and Other Current Assets
	Prepaid expenses and other current assets consist of prepayments for crude oil deliveries to our refineries for which title had not transferred, non-trade accounts receivable, current portions of prepaid insurance, deferred financing costs, derivative agreements and other general current assets.
Property, Plant, and Equipment	'
	Property, Plant, and Equipment
	Additions to property, plant and equipment, including capitalized interest and certain costs allocable to construction and property purchases, are recorded at cost. Capitalized interest is added to any capital project over $1.0 million in cost which is expected to take more than six months to complete. Depreciation is computed using principally the straight-line method over the estimated useful lives of the various classes of depreciable assets. The lives used in computing depreciation for such assets are as follows:
	Asset	Range of Useful
		Lives, in Years
	Improvements to land	15	to	30
	Buildings	20	to	30
	Machinery and equipment	5	to	30
	Automotive equipment	5	to	15
	Furniture and fixtures	3	to	10
	Leasehold improvements are depreciated or amortized on the straight-line method over the shorter of the contractual lease term or the estimated useful life of the asset. Expenditures for routine maintenance and repair costs are expensed when incurred. Such expenses are reported in direct operating expenses (exclusive of depreciation and amortization) in the Consolidated and Combined Statements of Operations.
Deferred Financing Costs, Underwriting and Original Issue Discount	'
	Deferred Financing Costs, Underwriting and Original Issue Discount
	Deferred financing costs associated with debt issuances are amortized to interest expense and other financing costs using the effective-interest method over the life of the debt. Additionally, the underwriting and original issue discount and premium related to debt issuances have been amortized to interest expense and other financing costs using the effective-interest method over the life of the debt. Deferred financing costs related to the Amended and Restated ABL Credit Facility are amortized to interest expense and other financing costs using the straight-line method through the termination date of the facility.
Planned Major Maintenance Costs	'
	Planned Major Maintenance Costs
	The direct-expense method of accounting is used for planned major maintenance activities. Maintenance costs are recognized as expense when maintenance services are performed. Planned major maintenance activities for the refineries varies by unit, but generally is every four to five years.
	The Coffeyville refinery completed the second phase of a two-phase turnaround project during the first quarter of 2012. The first phase was completed during the fourth quarter of 2011. Costs of approximately $21.2 million and $66.4 million associated with the Coffeyville refinery's 2011/2012 turnaround were included in direct operating expenses (exclusive of depreciation and amortization) for the years ended December 31, 2012 and 2011, respectively. The Wynnewood refinery completed a turnaround in the fourth quarter of 2012. Costs of approximately $102.5 million were included in direct operating expenses (exclusive of depreciation and amortization) for the year ended December 31, 2012.
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 $4.8 million, $3.6 million and $2.4 million for the years ended December 31, 2013, 2012 and 2011, 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 share-based compensation for CVR Energy and Coffeyville Acquisition III LLC ("CALLC III"), as discussed in Note 5 ("Share-Based Compensation"). Direct operating expenses exclude depreciation and amortization of approximately $109.1 million, $103.5 million and $67.2 million for the years ended December 31, 2013, 2012 and 2011, 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 share-based compensation expense from CVR Energy and CALLC III as discussed in Note 5 ("Share-Based Compensation"). Selling, general and administrative expenses exclude depreciation and amortization of approximately $0.4 million, $0.5 million and $0.2 million for the years ended December 31, 2013, 2012 and 2011, respectively.
Income Taxes	'
	Income Taxes
	CVR Refining is treated as a partnership for U.S. federal income tax purposes. The income tax liability of the common unitholders is not reflected in the consolidated and combined financial statements of the Partnership. 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.
Segment Reporting	'
	Segment Reporting
	The Partnership accounts for segment reporting in accordance with the Financial Accounting Standards Board ("FASB") Accounting Standards Codification ("ASC") Topic ASC 280, Segment Reporting, which established standards for entities to report information about the operating segments and geographic areas in which they operate. CVR Refining only operates one segment and all of its operations are located in the United States.
Impairment of Long-Lived Assets	'
	Impairment of Long-Lived Assets
	CVR Refining accounts for long-lived assets in accordance with accounting standards issued by the FASB regarding the treatment of the impairment or disposal of long-lived assets. As required by this standard, CVR Refining reviews long-lived assets (excluding intangible assets with indefinite lives) for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to estimated undiscounted future net cash flows expected to be generated by the asset. If the carrying amount of an asset exceeds its estimated undiscounted future net cash flows, an impairment charge is recognized for the amount by which the carrying amount of the assets exceeds their fair value. Assets to be disposed of are reported at the lower of their carrying value or fair value less cost to sell.
Divisional Equity	'
	Divisional Equity
	Partners' capital is referred to as divisional equity during the periods covered by the consolidated and combined financial statements prior to the contribution of the Refining Subsidiaries to the Partnership. Upon CRLLC's contribution of the Refining Subsidiaries to the Partnership on December 31, 2012, divisional equity became partners' capital.
Revenue Recognition	'
	Revenue Recognition
	Revenues for products sold are recorded upon delivery of the products to customers, which is the point at which title is transferred, the customer has assumed the risk of loss, and payment has been received or collection is reasonably assured. Excise and other taxes collected from customers and remitted to governmental authorities are not included in reported revenues.
	Nonmonetary product exchanges and certain buy/sell crude oil transactions which are entered into in the normal course of business are included on a net cost basis in operating expenses on the Consolidated and Combined Statements of Operations.
	The Partnership also engages in trading activities, whereby the Partnership enters into agreements to purchase and sell refined products with third parties. The Partnership acts as a principal in these transactions, taking title to the products in purchases from counterparties, and accepting the risks and rewards of ownership. The Partnership records revenue for the gross amount of the sales transactions, and records costs of purchases as an operating expense in the accompanying consolidated and combined financial statements.
Shipping Costs	'
	Shipping Costs
	Pass-through finished goods delivery costs reimbursed by customers are reported in net sales, while an offsetting expense is included in cost of product sold (exclusive of depreciation and amortization).
Derivative Instruments and Fair Value of Financial Instruments	'
	Derivative Instruments and Fair Value of Financial Instruments
	The Partnership uses futures contracts, options, and forward contracts primarily to reduce exposure to changes in crude oil prices, finished goods product prices and interest rates to provide economic hedges of inventory positions and anticipated interest payments on long-term debt. Although management considers these derivatives economic hedges, these derivative instruments do not qualify as hedges for hedge accounting purposes under ASC Topic 815, Derivatives and Hedging ("ASC 815"), and accordingly are recorded at fair value in the balance sheet. Changes in the fair value of these derivative instruments are recorded into earnings as a component of other income (expense) in the period of change. The estimated fair values of forward and swap contracts are based on quoted market prices and assumptions for the estimated forward yield curves of related commodities in periods when quoted market prices are unavailable. See Note 16 ("Derivative Financial Instruments") for further discussion.
	Other financial instruments consisting of cash and cash equivalents, accounts receivable, and accounts payable are carried at cost, which approximates fair value, as a result of the short-term nature of the instruments. See Note 9 ("Long-Term Debt") for further discussion of the fair value of the debt instruments.
Share-Based Compensation	'
	Share-Based Compensation
	The Partnership has been allocated share-based compensation expense from CVR Energy, CRLLC and CALLC III. CVR Energy accounts for share-based compensation in accordance with ASC Topic 718, Compensation — Stock Compensation ("ASC 718"). ASC 718 requires that compensation costs relating to share-based payment transactions be recognized in a company's financial statements. ASC 718 applies to transactions in which an entity exchanges its equity instruments for goods or services and also may apply to liabilities an entity incurs for goods or services that are based on the fair value of those equity instruments.
Environmental Matters	'
	Environmental Matters
	Liabilities related to future remediation costs of past environmental contamination of properties are recognized when the related costs are considered probable and can be reasonably estimated. Estimates of these costs are based upon currently available facts, internal and third party assessments of contamination, available remediation technology, site-specific costs, and currently enacted laws and regulations. In reporting environmental liabilities, no offset is made for potential recoveries. Loss contingency accruals, including those for environmental remediation, are subject to revision as further information develops or circumstances change and such accruals can take into account the legal liability of other parties. Environmental expenditures are capitalized at the time of the expenditure when such costs provide future economic benefits.
Use of Estimates	'
	Use of Estimates
	The consolidated and combined financial statements have been prepared in conformity with U.S. generally accepted accounting principles ("GAAP"), using management's best estimates and judgments where appropriate. These estimates and judgments affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ materially from these estimates and judgments.
Related Party Transactions	'
	Related Party Transactions
	CVR Energy and its subsidiaries provide a variety of services to CVR Refining, including cash management and financing services, employee benefits provided through CVR Energy's benefit plans, administrative services provided by CVR Energy's employees and management, insurance and office space leased in CVR Energy's headquarters building and other locations. As such, the accompanying consolidated and combined financial statements include costs that have been incurred by CVR Energy and CRLLC on behalf of CVR Refining. These amounts incurred by CVR Energy are then billed or allocated to CVR Refining and are properly classified on the Consolidated and Combined Statements of Operations as either direct operating expenses (exclusive of depreciation and amortization) or as selling, general and administrative expenses (exclusive of depreciation and amortization). For the year ended December 31, 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. Such expenses include, but are not limited to, salaries, benefits, share-based compensation expense, insurance, accounting, tax, legal and technology services. Costs which are specifically incurred on behalf of CVR Refining, are billed directly to CVR Refining. See Note 17 ("Related Party Transactions") for a detailed discussion of the billing procedures and the basis for calculating the charges.
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 accompanying financial statements have been prepared in accordance with SAB Topic 1-B, as more fully explained in Note 2 ("Basis of Presentation"). 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 have allocated general and administrative expenses to CVR Refining based on allocation methodologies that management considers reasonable and result in an allocation of the 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.
	CVR Refining's Consolidated and Combined Statements of Operations for the years ended December 31, 2012 and 2011 reflect all of the expenses that CRLLC and CVR Energy incurred on CVR Refining's behalf. For the year ended December 31, 2013, amounts incurred by CVR Energy and its affiliates on our behalf have been governed and billed in accordance with the services agreement as discussed above. 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, mark-to-market changes in interest rate swap, 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 5 ("Share-Based Compensation").
Subsequent Events	'
	Subsequent Events
	The Partnership evaluated subsequent events, if any, that would require an adjustment to the Partnership's consolidated and combined financial statements or require disclosure in the notes to the consolidated and combined financial statements through the date of issuance of the consolidated and combined financial statements. See Note 20 ("Subsequent Events") for further discussion.
New Accounting Pronouncements	'
	New Accounting Pronouncements
	In December 2011, the FASB issued Accounting Standard Update ("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 consolidated financial statement footnote disclosures.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Schedule of lives used in computing depreciation for depreciable assets	'
	The lives used in computing depreciation for such assets are as follows:
	Asset	Range of Useful
		Lives, in Years
	Improvements to land	15	to	30
	Buildings	20	to	30
	Machinery and equipment	5	to	30
	Automotive equipment	5	to	15
	Furniture and fixtures	3	to	10
	A summary of costs for property, plant, and equipment is as follows:
		December 31,
		2013			2012
		(in millions)
	Land and improvements	$	26.6		$	24
	Buildings	37.7			36.7
	Machinery and equipment	1,757.70			1,685.60
	Automotive equipment	18.4			14.3
	Furniture and fixtures	7.3			6.2
	Leasehold improvements	0.8			0.8
	Construction in progress	157.3			46
		2,005.80			1,813.60
	Accumulated depreciation	575.6			462
	Total property, plant and equipment, net	$	1,430.20		$	1,351.60
CVR Energy and CRRLC	'
Allocation of Costs	'
Schedule of allocation of cost, either allocated or billed, by period	'
	The table below reflects cost allocations, either allocated or billed, for the years ended December 31, 2012 and 2011 reflected in the Consolidated and Combined Statements of Operations.
		Year Ended December 31,
		2012			2011
		(in millions)
	Direct operating expenses (exclusive of depreciation and amortization)	$	13.3		$	9.1
	Selling, general and administrative expenses (exclusive of depreciation and amortization)	65.5			39.7
		$	78.8		$	48.8

Wynnewood_Acquisition_Tables

Wynnewood Acquisition (Tables)	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Schedule of total final purchase price allocated to WEC's net tangible assets based on their fair values	'
	The following table displays the total final purchase price allocated to WEC's net tangible assets based on their fair values as of December 15, 2011 (in millions):
	Cash and cash equivalents	$	6.3
	Accounts receivable	159
	Inventories	213.5
	Prepaid expenses and other current assets	6
	Property, plant and equipment	577
	Accounts payable and accrued liabilities	(316.1		)
	Long-term debt	(52.3		)
	Total fair values of net assets acquired	593.4
	Less: cash acquired	6.3
	Total consideration transferred, net of cash acquired	$	587.1

ShareBased_Compensation_Tables

Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Schedule of key information for share-based compensation plans related to override units	'
	The following table provides key information for the share-based compensation plans related to the override units of CALLC, CALLC II, and CALLC III.
								*Compensation
								Expense for the
								Year Ended
								December 31,
	Award Type	Benchmark Value (per Unit)			Original Awards Issued	Grant Date		2011
								(in millions)
	Override Value Units	$	11.31		1,839,265	Jun-05		$	1.4
	Override Units	$	10		642,219	Feb-08		(0.1		)
						Total		$	1.3
	*	As CVR Energy's common stock price increased or decreased, compensation expense associated with the unvested CALLC and CALLC II override units increased or was reversed in correlation with the calculation of the fair value under the probability-weighted expected return method.
Schedule of share-based compensation activity	'
	A summary of phantom unit activity and changes under the CVR Refining LTIP during the year ended December 31, 2013 is presented below:
		Phantom Units		Weighted-		Aggregate
				Average		Intrinsic
				Grant-Date		Value
				Fair Value
						(in millions)
	Non-vested at January 16, 2013	—		$	—	$	—
	Granted	187,177		21.55
	Vested	—		—
	Forfeited	—		—
	Non-vested at December 31, 2013	187,177		$	21.55	$	4.2

Inventories_Tables

Inventories (Tables)	12 Months Ended
	Dec. 31, 2013
Inventory Disclosure [Abstract]	'
Schedule of inventories	'
	Inventories consisted of the following:
		December 31,
		2013		2012
		(in millions)
	Finished goods	$	259	$	269.5
	Raw materials and precious metals	169.1		158.1
	In-process inventories	36.8		42.7
	Parts and supplies	28.8		29.2
		$	493.7	$	499.5

Property_Plant_and_Equipment_T

Property, Plant, and Equipment (Tables)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Summary of costs for property, plant, and equipment	'
	The lives used in computing depreciation for such assets are as follows:
	Asset	Range of Useful
		Lives, in Years
	Improvements to land	15	to	30
	Buildings	20	to	30
	Machinery and equipment	5	to	30
	Automotive equipment	5	to	15
	Furniture and fixtures	3	to	10
	A summary of costs for property, plant, and equipment is as follows:
		December 31,
		2013			2012
		(in millions)
	Land and improvements	$	26.6		$	24
	Buildings	37.7			36.7
	Machinery and equipment	1,757.70			1,685.60
	Automotive equipment	18.4			14.3
	Furniture and fixtures	7.3			6.2
	Leasehold improvements	0.8			0.8
	Construction in progress	157.3			46
		2,005.80			1,813.60
	Accumulated depreciation	575.6			462
	Total property, plant and equipment, net	$	1,430.20		$	1,351.60

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Schedule of long-term debt	'
	Long-term debt was as follows:
		December 31,
		2013		2012
		(in millions)
	10.875% Second Lien Senior Secured Notes, due 2017, net of unamortized discount of $1.8 million as of December 31, 2012	$	—	$	220.9
	6.5% Second Lien Senior Secured Notes, due 2022	500		500
	Intercompany credit facility	31.5		—
	Capital lease obligations	49.9		51.2
	Long-term debt	$	581.4	$	772.1
Schedule of estimated amortization of deferred financing costs	'
	Estimated amortization of deferred financing costs is as follows:
	Year Ending December 31,	Deferred
		Financing
		(in millions)
	2014	$	1.9
	2015	1.9
	2016	1.9
	2017	1.8
	2018	0.9
	Thereafter	3.5
		$	11.9
Schedule of future payments required under capital lease	'
	Future payments required under capital lease at December 31, 2013 are as follows:
	Year Ending December 31,	Capital Lease
		(in millions)
	2014	$	6.3
	2015	6.4
	2016	6.4
	2017	6.4
	2018	6.5
	2019 and thereafter	70.3
	Total future payments	102.3
	Less: amount representing interest	51.1
	Present value of future minimum payments	51.2
	Less: current portion	1.3
	Long-term portion	$	49.9

Partners_Capital_and_Partnersh1

Partners' Capital and Partnership Distributions Partners' Capital and Partnership Distributions (Tables)	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
Distributions Made to Limited Partner, 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		30-Sep-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	$	33.2	$	378.7
	Amounts paid to non-affiliates	37.3		49.7		11.1		98
	Total amount paid	$	233.2	$	199.3	$	44.3	$	476.7
	Per common unit	$	1.58	$	1.35	$	0.3	$	3.23
	Common units outstanding	147.6		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)	12 Months Ended
	Dec. 31, 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:
		January 23, 2013 to
		31-Dec-13
		(in millions, except per unit data)
	Net income (from the closing of the offering on January 23, 2013 to December 31, 2013)	$	512.6
	Net income per common unit, basic	$	3.47
	Net income per common unit, diluted	$	3.47
	Weighted-average common units outstanding, basic	147.6
	Weighted-average common units outstanding, diluted	147.6

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 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:
	Year Ending December 31,	Operating		Unconditional
		Leases		Purchase
				Obligations(1)
		(in millions)
	2014	$	2.5	$	110.8
	2015	1.5		104.9
	2016	1		97.8
	2017	0.3		96.5
	2018	0.1		96.6
	Thereafter	0.3		874.5
		$	5.7	$	1,381.10
	-1	This amount includes approximately $973.0 million payable ratably over seventeen 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:
	Year Ending December 31,	Amount
		(in millions)
	2014	$	0.3
	2015	0.2
	2016	0.1
	2017	0.1
	2018	0.1
	Thereafter	1
	Undiscounted total	1.8
	Less amounts representing interest at 2.73%	0.3
	Accrued environmental liabilities at December 31, 2013	$	1.5

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 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 December 31, 2013 and 2012:
		December 31, 2013
		Level 1		Level 2			Level 3		Total
		(in millions)
	Location and Description
	Other current assets (derivative agreements)	$	—	$	0.9		$	—	$	0.9
	Other long-term assets (derivative agreements)	—		0.1			—		0.1
	Total Assets	$	—	$	1		$	—	$	1
	Other current liabilities (derivative agreements)	—		(15.3		)	—		(15.3		)
	Other current liabilities (biofuel blending obligation)	—		(16.2		)	—		(16.2		)
	Other long-term liabilities (derivative agreements)	—		(1.8		)	—		(1.8		)
	Total Liabilities	$	—	$	(33.3	)	$	—	$	(33.3	)
		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	)

Derivatives_and_Financial_Inst1

Derivatives and Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Components of gain (loss) on derivatives, net and current period settlements on derivative contracts	'
	Gain (loss) on derivatives, net and current period settlements on derivative contracts were as follows:
		Year Ended December 31,
		2013		2012			2011
		(in millions)
	Current period settlements on derivative contracts	$	6.4	$	(137.6	)	$	(7.2	)
	Gain (loss) on derivatives, net	57.1		(285.6		)	78.1
Schedule of Offsetting Assets	'
	The offsetting assets and liabilities for CVR Refining’s derivatives as of December 31, 2013 are recorded as current assets, non-current assets, current liabilities and non-current liabilities in prepaid expenses and other current assets, other long-term assets, accrued expenses and other current liabilities and other long-term liabilities, respectively, in the Consolidated Balance Sheets as follows:
		As of December 31, 2013
	Description	Gross Current Assets		Gross			Net			Cash		Net
				Amounts			Current Assets			Collateral		Amount
				Offset			Presented			Not Offset
		(in millions)
	Commodity Swaps	$	4.3	$	(3.4	)	$	0.9		$	—	$	0.9
	Total	$	4.3	$	(3.4	)	$	0.9		$	—	$	0.9
		As of December 31, 2013
	Description	Gross Non-Current Assets		Gross			Net			Cash		Net
				Amounts			Non-Current Assets			Collateral		Amount
				Offset			Presented			Not Offset
		(in millions)
	Commodity Swaps	$	0.1	$	—		$	0.1		$	—	$	0.1
	Total	$	0.1	$	—		$	0.1		$	—	$	0.1
		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	'
		As of December 31, 2013
	Description	Gross Current Liabilities		Gross			Net			Cash		Net
				Amounts			Current Liabilities			Collateral		Amount
				Offset			Presented			Not Offset
		(in millions)
	Commodity Swaps	$	31.4	$	(16.1	)	$	15.3		$	—	$	15.3
	Total	$	31.4	$	(16.1	)	$	15.3		$	—	$	15.3
		As of December 31, 2013
	Description	Gross Non-Current Liabilities		Gross			Net			Cash		Net
				Amounts			Non-Current Liabilities			Collateral		Amount
				Offset			Presented			Not Offset
		(in millions)
	Commodity Swaps	$	1.9	$	(0.1	)	$	1.8		$	—	$	1.8
	Total	$	1.9	$	(0.1	)	$	1.8		$	—	$	1.8
		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

Major_Customers_and_Suppliers_

Major Customers and Suppliers (Tables)	12 Months Ended
	Dec. 31, 2013
Major Customers and Suppliers	'
Schedule of sales to major customers	'
	Sales to major customers were as follows:
		Year Ended December 31,
		2013		2012		2011
	Customer A	12	%	10	%	15	%
	Customer B	9	%	9	%	12	%
		21	%	19	%	27	%
Schedule of purchases contracted as a percentage of the total cost of product sold	'
	Volume contracted as a percentage of the total crude oil purchases (in barrels) for each of the periods was as follows:
		Year Ended December 31,
		2013		2012		2011
	Supplier A	69	%	45	%	65	%

Selected_Quarterly_Financial_I1

Selected Quarterly Financial Information (unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Summary of quarterly financial data	'
	Summarized quarterly financial data for December 31, 2013 and 2012:
		Year Ended December 31, 2013
		Quarter
		First			Second			Third			Fourth
		(in millions, except per unit data)
	Net sales	$	2,274.00		$	2,138.10		$	1,910.50		$	2,360.90
	Operating costs and expenses:
	Cost of product sold (exclusive of depreciation and amortization)	1,805.80			1,776.60			1,734.70			2,209.70
	Direct operating expenses (exclusive of depreciation and amortization)	86			83.8			104.7			87.2
	Selling, general and administrative (exclusive of depreciation and amortization)	18.6			20.2			18.9			20
	Depreciation and amortization	28			28.4			28.8			29.1
	Total operating costs and expenses	1,938.40			1,909.00			1,887.10			2,346.00
	Operating income	335.6			229.1			23.4			14.9
	Other income (expense):
	Interest expense and other financing costs	(14.2		)	(10.6		)	(10.0		)	(9.3		)
	Interest income	0.1			0.1			0.1			0.1
	Gain (loss) on derivatives, net	(20.0		)	120.5			72.5			(115.9		)
	Loss on extinguishment of debt	(26.1		)	—			—			—
	Other income, net	—			0.1			—			—
	Total other income (expense)	(60.2		)	110.1			62.6			(125.1		)
	Income before income tax expense	275.4			339.2			86			(110.2		)
	Income taxes	—			—			—			—
	Net income (loss)	$	275.4		$	339.2		$	86		$	(110.2	)
	Net income (loss) subsequent to initial public offering (January 23, 2013 through December 31, 2013)	$	197.5		$	339.2		$	86		$	(110.2	)
	Net income (loss) per common unit - basic	$	1.34		$	2.3		$	0.58		$	(0.75	)
	Net income (loss) per common unit - diluted	$	1.34		$	2.3		$	0.58		$	(0.75	)
	Weighted-average common units outstanding:
	Basic	147.6			147.6			147.6			147.6
	Diluted	147.6			147.6			147.6			147.6
		Year Ended December 31, 2012
		Quarter
		First			Second			Third			Fourth
		(in millions)
	Net sales	$	1,898.50		$	2,229.60		$	2,337.40		$	1,816.20
	Operating costs and expenses:
	Cost of product sold (exclusive of depreciation and amortization)	1,630.70			1,866.20			1,694.10			1,476.50
	Direct operating expenses (exclusive of depreciation and amortization)	92.7			71.6			88.8			173.4
	Selling, general and administrative (exclusive of depreciation and amortization)	20.2			26.1			21.2			18.6
	Depreciation and amortization	26.3			26.6			27.5			27.3
	Total operating costs and expenses	1,769.90			1,990.50			1,831.60			1,695.80
	Operating income	128.6			239.1			505.8			120.4
	Other income (expense):
	Interest expense and other financing costs	(18.8		)	(19.0		)	(18.2		)	(20.2		)
	Interest income	—			—			—			—
	Gain (loss) on derivatives, net	(147.2		)	38.8			(168.9		)	(8.2		)
	Loss on extinguishment of debt	—			—			—			(37.5		)
	Other income (expense), net	—			0.6			(0.1		)	0.1
	Total other income (expense)	(166.0		)	20.4			(187.2		)	(65.8		)
	Income before income tax expense	(37.4		)	259.5			318.6			54.6
	Income taxes	—			—			—			—
	Net income (loss)	$	(37.4	)	$	259.5		$	318.6		$	54.6

Formation_of_the_Partnership_O1

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

0 Months Ended

2 Months Ended

3 Months Ended

7 Months Ended

11 Months Ended

12 Months Ended

0 Months Ended

0 Months Ended

7 Months Ended

0 Months Ended

7 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

In Millions, except Share data, unless otherwise specified

Jan. 30, 2013

Jan. 23, 2013

Mar. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Apr. 18, 2012

Jan. 23, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Jan. 23, 2013

Dec. 31, 2013

Jan. 23, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Jan. 23, 2013

Dec. 31, 2013

Jan. 23, 2013

Jun. 10, 2013

20-May-13

20-May-13

30-May-13

10.875% senior secured notes due 2017

10.875% senior secured notes due 2017

10.875% senior secured notes due 2017

CVR Energy, Inc

Affiliate of Icahn Enterprises

Affiliate of Icahn Enterprises

CVR Refining Holdings

CVR Refining Holdings

CVR Refining Holdings

CVR Refining Holdings

Coffeyville Resources LLC

CVR Energy, Inc

Initial Public Offering

Underwritten Offering

Underwritten Offering

Underwritten Offering

Underwritten Offering

Refining LLC

CVR Refining GP, LLC

CVR Partners LP [Member]

CVR Energy, Inc

CVR Energy, Inc

Minimum

Affiliate of Icahn Enterprises

Formation of the Partnership, Organization and Nature of Business [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest in general partner (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest in limited partner interests (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

71.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Majority shareholder ownership interest (as a percent)

'

'

'

'

'

'

'

82.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of membership interest in other entity transferred by limited partner

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

Limited partner interest (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

81.00%

71.00%

'

'

'

'

'

'

'

'

'

January issuance of common units to public, net of offering costs (in units)

3,600,000

24,000,000

'

'

'

'

'

'

'

'

'

'

'

4,000,000

'

'

'

'

'

'

'

'

1,209,236

12,000,000

'

'

Offering price per unit (in dollars per share)

$25

$25

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$30.75

$30.75

'

'

Underwriting fees

'

$32.50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other offering costs incurred

'

3.9

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net proceeds from the Initial Public Offering

'

653.6

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

394

'

'

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

'

'

'

'

'

'

'

'

'

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 to be utilized for general corporate purposes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

101.5

'

'

'

'

Cash on hand distributed

'

'

$233.20

[1]

$44.30

$199.30

'

$476.70

'

'

'

'

'

'

'

'

'

'

'

'

$150

'

'

'

'

'

'

Percentage of limited partner interest held by the public

'

19.00%

'

'

'

29.00%

'

'

'

'

'

'

'

3.00%

4.00%

'

'

'

'

'

'

'

'

'

'

'

Units sold in private placement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,000,000

May redemption of common units from CVR Refining Holdings, LLC (in units)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

13,209,236

'

Ownership percentage (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

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%

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

(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).

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Cash and Cash Equivalents	'	'
Checks issued but not presented to banks	11.7	14.9
Accounts receivable | Credit concentration	'	'
Accounts Receivable, net	'	'
Customers individually representing greater than this percentage for disclosure	13.00%	10.00%
Accounts receivable | Credit concentration | One customer with largest risk concentration	'	'
Accounts Receivable, net	'	'
Number of customers	1	1

Summary_of_Significant_Account4

Summary of Significant Accounting Policies (Details 2) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Property, Plant, and Equipment	'
Minimum project cost required for capitalization of interest	$1
Minimum period required for completion of project for capitalization of interest	'6 months
Improvements to land | Minimum	'
Property, Plant, and Equipment	'
Useful life	'15 years
Improvements to land | Maximum	'
Property, Plant, and Equipment	'
Useful life	'30 years
Buildings | Minimum	'
Property, Plant, and Equipment	'
Useful life	'20 years
Buildings | Maximum	'
Property, Plant, and Equipment	'
Useful life	'30 years
Machinery and equipment | Minimum	'
Property, Plant, and Equipment	'
Useful life	'5 years
Machinery and equipment | Maximum	'
Property, Plant, and Equipment	'
Useful life	'30 years
Automotive equipment | Minimum	'
Property, Plant, and Equipment	'
Useful life	'5 years
Automotive equipment | Maximum	'
Property, Plant, and Equipment	'
Useful life	'15 years
Furniture and fixtures | Minimum	'
Property, Plant, and Equipment	'
Useful life	'3 years
Furniture and fixtures | Maximum	'
Property, Plant, and Equipment	'
Useful life	'10 years

Summary_of_Significant_Account5

Summary of Significant Accounting Policies (Details 3) (USD $)	12 Months Ended					1 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2013	Mar. 31, 2012	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2012
	segment			Minimum	Maximum	Coffeyville refinery	Coffeyville refinery	Coffeyville refinery	Wynnewood refinery
						phase
Planned Major Maintenance Costs	'	'	'	'	'	'	'	'	'
Frequency of planned major maintenance activities	'	'	'	'4 years	'5 years	'	'	'	'
Number of phases	'	'	'	'	'	2	'	'	'
Turnaround costs	'	'	'	'	'	'	$21.20	$66.40	$102.50
Cost Classifications	'	'	'	'	'	'	'	'	'
Depreciation and amortization not included in cost of product sold	4.8	3.6	2.4	'	'	'	'	'	'
Depreciation and amortization not included in direct operating expenses	109.1	103.5	67.2	'	'	'	'	'	'
Depreciation and amortization not included in selling, general and administrative expenses	$0.40	$0.50	$0.20	'	'	'	'	'	'
Segment Reporting	'	'	'	'	'	'	'	'	'
Number of operating segments	1	'	'	'	'	'	'	'	'

Summary_of_Significant_Account6

Summary of Significant Accounting Policies (Details 4) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Allocation of Costs	'	'	'	'	'	'	'	'	'	'	'
Direct operating expenses (exclusive of depreciation and amortization)	$87.20	$104.70	$83.80	$86	$173.40	$88.80	$71.60	$92.70	$361.70	$426.50	$247.70
Selling, general and administrative expenses (exclusive of depreciation and amortization)	20	18.9	20.2	18.6	18.6	21.2	26.1	20.2	77.8	86.2	51
Total operating costs and expenses	2,346	1,887.10	1,909	1,938.40	1,695.80	1,831.60	1,990.50	1,769.90	8,080.50	7,287.80	4,296.10
CVR Energy and CRRLC	'	'	'	'	'	'	'	'	'	'	'
Allocation of Costs	'	'	'	'	'	'	'	'	'	'	'
Direct operating expenses (exclusive of depreciation and amortization)	'	'	'	'	'	'	'	'	'	13.3	9.1
Selling, general and administrative expenses (exclusive of depreciation and amortization)	'	'	'	'	'	'	'	'	'	65.5	39.7
Total operating costs and expenses	'	'	'	'	'	'	'	'	'	$78.80	$48.80

Wynnewood_Acquisition_Details

Wynnewood Acquisition (Details) (USD $)	12 Months Ended			0 Months Ended	12 Months Ended	0 Months Ended	1 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 15, 2011	Dec. 31, 2012	Dec. 15, 2011	Mar. 31, 2012	Nov. 30, 2011	Dec. 31, 2012	Dec. 31, 2011
				WEC	WEC	WEC	WEC	WEC	WEC	WEC
				bbl		Coffeyville Resources LLC	Coffeyville Resources LLC	Coffeyville Resources LLC	Coffeyville Resources LLC	Coffeyville Resources LLC
						subsidiary
Acquisition	'	'	'	'	'	'	'	'	'	'
Number of wholly-owned subsidiaries of acquired entity	'	'	'	'	'	2	'	'	'	'
Final purchase price	'	'	'	'	'	$593.40	'	'	'	'
Initial cash payment	'	'	'	'	'	525	'	'	'	'
Working capital adjustment	'	'	'	'	'	66.6	'	'	'	'
Capital expenditure adjustment	'	'	'	'	'	1.8	'	'	'	'
WEC's revenues included in Consolidated Statement of Operations from date of acquisition	'	'	'	'	115.7	'	'	'	'	'
WEC's operating loss before taxes included in Consolidated Statement of Operations from date of acquisition	'	'	'	'	2.3	'	'	'	'	'
Capacity of refinery acquired by the entity in Wynnewood, Oklahoma (in barrels per day)	'	'	'	70,000	'	'	'	'	'	'
Number of barrels of storage tanks owned by the entity included in the refinery of the acquiree	'	'	'	2,000,000	'	'	'	'	'	'
Refund resulting from post-closing working capital and capital expenditure adjustments	'	'	'	'	'	'	'	'	15.8	'
Amount of increase in preliminary purchase price	'	'	'	'	'	'	1.1	'	'	'
Purchase Price Allocation	'	'	'	'	'	'	'	'	'	'
Cash and cash equivalents	'	'	'	'	'	6.3	'	'	'	'
Accounts Receivable	'	'	'	'	'	159	'	'	'	'
Inventories	'	'	'	'	'	213.5	'	'	'	'
Prepaid expenses and other current assets	'	'	'	'	'	6	'	'	'	'
Property, plant and equipment	'	'	'	'	'	577	'	'	'	'
Accounts payable and accrued liabilities	'	'	'	'	'	-316.1	'	'	'	'
Long-term debt	'	'	'	'	'	-52.3	'	'	'	'
Total fair values of net assets acquired	'	'	'	'	'	593.4	'	'	'	'
Less: cash acquired	'	'	'	'	'	6.3	'	'	'	'
Total consideration transferred, net of cash acquired	0	0	587.1	'	'	587.1	'	'	'	'
Acquisition Costs	'	'	'	'	'	'	'	'	'	'
Transaction fees and expenses included in selling, general and administrative expense	'	'	'	'	'	'	'	'	11	5.2
Period of bridge loan	'	'	'	'	'	'	'	'1 year	'	'
Commitment fee and other third party costs	'	'	'	'	'	'	'	'	$3.90	'

ShareBased_Compensation_Detail

Share-Based Compensation (Details) (USD $)

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

31-May-11

Feb. 28, 2011

Feb. 28, 2011

Jun. 30, 2005

Dec. 31, 2011

Feb. 29, 2008

Feb. 29, 2008

Dec. 31, 2011

Dec. 31, 2011

CALLC III

CALLC III

CALLC III

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

Override Units

Override Units

Override Units

CALLC -Post Split

CALLC -Post Split

CALLC II

CALLC and CALLC II

CALLC and CALLC II

CALLC and CALLC II

CALLC III

CALLC III

CALLC, CALLC II and CALLC III

Override Value Units

Override Value Units

Override Units

Override Units

Override Units

Share-Based Compensation

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of allocation of share-based compensation expense

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares of common stock sold pursuant to a registered public offering

'

'

'

'

7,988,179

11,759,023

15,113,254

'

'

'

'

'

'

Key information for the share-based compensation plans related to the override units of CALLC, CALLC II and CALLC III

'

'

'

'

'

'

'

'

'

'

'

'

'

Benchmark Value (per unit)

'

'

'

'

'

'

'

$11.31

'

$10

'

'

'

Original Awards Issued (in shares)

'

'

'

'

'

'

'

1,839,265

'

'

642,219

'

'

Compensation expense

'

$0

$0

'

'

'

'

'

$1,400,000

[1]

'

'

($100,000)

[1]

$1,300,000

[1]

Unrecognized compensation expense

'

$0

$0

$0

'

'

'

'

'

'

'

'

'

[1]

As CVR Energy's common stock price increased or decreased, compensation expense associated with the unvested CALLC and CALLC II override units increased or was reversed in correlation with the calculation of the fair value under the probability-weighted expected return method.

ShareBased_Compensation_Detail1

Share-Based Compensation (Details 2) (USD $)

Apr. 18, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

31-May-12

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Performance Unit Awards

Incentive Unit Award

Phantom Unit Plans

Phantom Unit Plans

Phantom Unit Plans

Long Term Incentive Plan

Long Term Incentive Plan

Long Term Incentive Plan

Long Term Incentive Plan

Long Term Incentive Plan

Long Term Incentive Plan

Long Term Incentive Plan

Long Term Incentive Plan

Executive officers

Executive officers

trading_day

plan

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

Long Term Incentive Plan

Long Term Incentive Plan

Restricted Shares

Restricted Shares

Restricted Shares

Restricted Shares

Restricted Stock Units

Restricted Stock Units

Restricted Stock Units

CVR Energy, Inc

CVR Energy, Inc

Restricted Stock Units

Restricted Stock Units

Share-Based Compensation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of compensation plans

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

Compensation expense

'

$2,100,000

'

$0

$0

$4,300,000

'

$9,500,000

$18,500,000

$3,300,000

'

'

'

'

'

'

Unrecognized compensation expense

'

'

3,500,000

0

0

0

4,200,000

4,000,000

'

'

'

'

'

'

'

'

Award vesting period

'

'

'3 years

'

'

'

'

'3 years

'

'

'

'3 years

'

'

'1 year

'1 year

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

$30

'

'

'

'

'

'

'

'

'

$30

'

'

'

'

'

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

1

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

Additional share-based compensation as a result of modification of the plan allocated to the Partnership

'

'

'

'

'

'

'

$6,300,000

'

'

'

'

'

'

'

'

Award vesting percentage

'

'

33.33%

'

'

'

'

'

'

'

'

'

33.33%

33.33%

'

'

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

'

'

1

'

'

'

'

'

'

'

'

1

'

'

'

'

Period for recognition for unrecognized compensation expense

'

'

'2 years

'

'

'

'2 years

'1 year 2 months 12 days

'

'

'

'

'

'

'

'

Period for determination of cash payment value upon vesting

'

'

10

'

'

'

'

'

'

'

'

'

'

'

'

'

ShareBased_Compensation_Detail2

Share-Based Compensation (Details 3) (Long Term Incentive Plan, USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2013	Jan. 16, 2013
		trading_day
Share-Based Compensation	'	'	'
Number of shares available for issuance	11,070,000	11,070,000	11,070,000
Weighted Average Grant-Date Fair Value	'	'	'
Unrecognized compensation expense	$4.20	$4.20	'
Period for recognition for unrecognized compensation expense	'	'2 years	'
Phantom Unit Plans	'	'	'
Share-Based Compensation	'	'	'
Award vesting period	'	'3 years	'
Award vesting percentage	'	33.33%	'
Number of shares considered for determining cash payment for each award upon vesting	'	1	'
Period for determination of cash payment value upon vesting	'	10	'
Phantom Units Activity	'	'	'
Non-vested, beginning of period (in shares)	0	'	'
Granted (in shares)	187,177	'	'
Vested (in shares)	0	'	'
Forfeited (in shares)	0	'	'
Non-vested, end of period (in shares)	187,177	187,177	'
Weighted Average Grant-Date Fair Value	'	'	'
Non-vested, beginning of period (in dollars per share)	$0	'	'
Granted (in dollars per share)	$21.55	'	'
Vested (in dollars per share)	$0	'	'
Forfeited (in dollars per share)	$0	'	'
Non-vested, end of period (in dollars per share)	$21.55	$21.55	'
Aggregate Intrinsic Value	$4.20	$4.20	$0

Inventories_Details

Inventories (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Inventory Disclosure [Abstract]	'	'
Finished goods	$259	$269.50
Raw materials and precious metals	169.1	158.1
In-process inventories	36.8	42.7
Parts and supplies	28.8	29.2
Inventories	$493.70	$499.50

Property_Plant_and_Equipment_D

Property, Plant, and Equipment (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Property, Plant, and Equipment	'	'	'
Gross property, plant and equipment	$2,005.80	$1,813.60	'
Accumulated depreciation	575.6	462	'
Total net, property, plant and equipment	1,430.20	1,351.60	'
Capitalized interest	3.2	3	1.1
Original carrying value of assets under capital lease obligations	24.8	24.8	'
Land and improvements	'	'	'
Property, Plant, and Equipment	'	'	'
Gross property, plant and equipment	26.6	24	'
Buildings	'	'	'
Property, Plant, and Equipment	'	'	'
Gross property, plant and equipment	37.7	36.7	'
Machinery and equipment	'	'	'
Property, Plant, and Equipment	'	'	'
Gross property, plant and equipment	1,757.70	1,685.60	'
Automotive equipment	'	'	'
Property, Plant, and Equipment	'	'	'
Gross property, plant and equipment	18.4	14.3	'
Furniture and fixtures	'	'	'
Property, Plant, and Equipment	'	'	'
Gross property, plant and equipment	7.3	6.2	'
Leasehold improvements	'	'	'
Property, Plant, and Equipment	'	'	'
Gross property, plant and equipment	0.8	0.8	'
Construction in progress	'	'	'
Property, Plant, and Equipment	'	'	'
Gross property, plant and equipment	$157.30	$46	'

Insurance_Claims_Details

Insurance Claims (Details) (USD $)	12 Months Ended			0 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012
				Coffeyville refinery incident in connection with FCCU	Coffeyville refinery incident in connection with FCCU	Coffeyville refinery incident in connection with FCCU	Coffeyville refinery incident in connection with FCCU	Coffeyville refinery incident in connection with FCCU
							Coffeyville Resources LLC	Coffeyville Resources LLC
Insurance Claims	'	'	'	'	'	'	'	'
Repairs and other associated costs	'	'	'	$8	$0	$0	'	'
Property damage insurance deductible amount	'	'	'	'	'	'	2.5	'
Insurance proceeds	4	'	'	'	'	'	'	'
Insurance receivable	'	$0	$1.30	'	'	'	'	$1.30

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)

3 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

3 Months Ended

3 Months Ended

0 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Jan. 23, 2013

Dec. 31, 2013

Dec. 31, 2012

Apr. 06, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Oct. 23, 2012

Sep. 17, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Jan. 23, 2013

Apr. 06, 2010

16-May-11

Dec. 30, 2010

Dec. 31, 2011

Dec. 15, 2011

Dec. 15, 2011

Jun. 04, 2012

Dec. 31, 2011

Nov. 23, 2012

Oct. 23, 2012

Dec. 31, 2012

Dec. 15, 2011

Mar. 31, 2011

Dec. 31, 2011

Feb. 22, 2011

Dec. 30, 2010

Mar. 31, 2011

Feb. 22, 2011

Dec. 20, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 20, 2012

Dec. 20, 2012

Dec. 20, 2012

Dec. 20, 2012

Dec. 20, 2012

Dec. 20, 2012

Dec. 20, 2012

Dec. 20, 2012

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

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

Intercompany Credit Facility

Intercompany Credit Facility

Intercompany Credit Facility

Intercompany Credit Facility

Original Notes

Original Notes

Original Notes

Original Notes

Additional First Lien Notes

Additional First Lien Notes

Old Notes

Old Notes

9.0% Senior Secured Notes, due 2015

9.0% Senior Secured Notes, due 2015

9.0% Senior Secured Notes, due 2015

ABL Credit Facility

ABL Credit Facility

ABL Credit Facility

ABL Credit Facility

ABL Credit Facility

First Priority Credit Facility

First Priority Credit Facility

Amended and Restated Asset Backed Credit Facility

Amended and Restated Asset Backed Credit Facility

Amended and Restated Asset Backed Credit Facility

Amended and Restated Asset Backed Credit Facility

Amended and Restated Asset Backed Credit Facility

Amended and Restated Asset Backed Credit Facility

Amended and Restated Asset Backed Credit Facility

Amended and Restated Asset Backed Credit Facility

Amended and Restated Asset Backed Credit Facility

Amended and Restated Asset Backed Credit Facility

Amended and Restated Asset Backed Credit Facility

Amended and Restated Asset Backed Credit Facility

Coffeyville Resources LLC

CRLLC and Coffeyville Finance Inc. (Issuers)

Level 2

Refining LLC

Refining LLC

Coffeyville Resources LLC

Coffeyville Resources LLC

CRLLC and Coffeyville Finance Inc. (Issuers)

Coffeyville Resources LLC

Coffeyville Resources LLC

Coffeyville Resources LLC

CRLLC and Coffeyville Finance Inc. (Issuers)

Coffeyville Resources LLC

CRLLC and Coffeyville Finance Inc. (Issuers)

Coffeyville Resources LLC

Coffeyville Resources LLC

Coffeyville Resources LLC

Coffeyville Resources LLC

Coffeyville Resources LLC

Coffeyville Resources LLC

Coffeyville Resources LLC

Coffeyville Resources LLC

Coffeyville Resources LLC

Coffeyville Resources LLC

Coffeyville Resources LLC

Credit parties

Credit parties

Credit parties

Credit parties

Credit parties

Credit parties

Credit parties

Credit parties

Credit parties

Credit parties

Credit parties

Credit parties

Intercompany Credit Facility

Minimum

LIBOR

Quarterly Average Excess Availability Exceeding Fifty Percent of Lesser of Borrowing Base and Total Commitments

Quarterly Average Excess Availability Less than or Equal to Fifty Percent of Lesser of Borrowing Base and Total Commitments

Daily Average Amount of Loans and Letters of Credit Outstanding Less than Fifty Percent of Lesser of Borrowing Base and Total Commitments

Daily Average Amount of Loans and Letters of Credit Outstanding Equal to or Greater than Fifty Percent of Lesser of Borrowing Base and Total Commitments

LIBOR

LIBOR

Prime

Prime

Maximum

Quarterly Average Excess Availability Exceeding Fifty Percent of Lesser of Borrowing Base and Total Commitments

Quarterly Average Excess Availability Less than or Equal to Fifty Percent of Lesser of Borrowing Base and Total Commitments

Quarterly Average Excess Availability Exceeding Fifty Percent of Lesser of Borrowing Base and Total Commitments

Quarterly Average Excess Availability Less than or Equal to Fifty Percent of Lesser of Borrowing Base and Total Commitments

Long-Term Debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt

$581,400,000

'

'

'

$772,100,000

'

'

'

$581,400,000

$772,100,000

'

'

'

$0

$220,900,000

'

$500,000,000

$500,000,000

'

'

'

$31,500,000

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capital lease obligations

49,900,000

'

'

'

51,200,000

'

'

'

49,900,000

51,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stated interest rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

10.88%

10.88%

10.88%

6.50%

'

'

6.50%

'

'

'

'

'

9.00%

'

'

'

9.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unamortized discount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate principal amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

225,000,000

'

'

'

500,000,000

500,000,000

'

'

'

'

275,000,000

'

'

'

200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issue price as a percentage of principal amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

98.81%

'

'

'

'

'

'

'

'

'

99.51%

'

'

'

105.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Principal payment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,700,000

27,500,000

'

'

'

'

'

124,100,000

323,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Prepayment premium (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Basis spread on variable rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.75%

2.00%

0.75%

1.00%

3.00%

Loss on extinguishment of debt

0

0

0

-26,100,000

-37,500,000

0

0

0

-26,100,000

-37,500,000

-2,100,000

'

'

-26,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

1,600,000

'

'

'

'

'

'

'

33,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchase price as a percentage of the principal amount at which the entity is required to purchase a portion of the notes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

103.00%

'

'

'

'

101.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Write-off of deferred financing costs and original issue discount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

89,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Portion of prepayment premium recorded as loss on extinguishment of debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

81,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unamortized premium

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total net proceeds from the offering

'

'

'

'

'

'

'

'

0

0

206,000,000

'

'

'

'

'

'

'

'

492,500,000

'

'

'

'

'

'

'

'

'

'

202,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred underwriting discounts

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Bridge loan commitment and other associated fees

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Commitment fees

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Structuring fees

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Third party fees

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Third party costs capitalized

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from IPO to be utilized for repurchase of debt

'

'

'

'

'

'

'

'

'

'

'

'

253,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repurchased debt, face amount

'

'

'

'

'

'

'

'

'

'

'

'

222,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued interest settled on redemption

'

'

'

'

'

'

'

'

'

'

'

'

9,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,600,000

1,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Write-off of previously deferred financing charges

'

'

'

'

'

'

'

'

'

'

'

'

'

3,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,100,000

'

'

'

'

'

1,900,000

'

'

'

4,100,000

'

'

'

'

'

'

'

'

'

'

Unamortized discount written off

'

'

'

'

'

'

'

'

'

'

'

'

'

1,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest (as a percent)

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from IPO to be utilized for repurchase of debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

348,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Prepayment premium

'

'

'

'

'

'

'

'

'

'

'

'

20,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,400,000

23,200,000

31,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Portion of unamortized premium written off

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred finance costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,100,000

'

'

'

'

'

2,100,000

2,100,000

'

'

'

'

'

'

'

'

'

'

Debt issuance cost

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued interest payable

5,400,000

'

'

'

12,200,000

'

'

'

5,400,000

12,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated fair value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

491,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

400,000,000

'

'

250,000,000

'

'

150,000,000

400,000,000

'

'

'

'

'

'

'

'

'

'

'

150,000,000

Maximum borrowing capacity optional expansion

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

250,000,000

'

'

'

200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Swingline loans sublimit as a percentage of the total facility commitment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

90.00%

'

'

'

90.00%

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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 interest rate on borrowings

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

800,000

'

'

'

'

'

'

2,800,000

'

'

'

'

'

'

'

'

'

'

'

Aggregate availability

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

118,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

372,900,000

'

'

'

'

'

'

'

'

'

Outstanding letters of credit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

27,100,000

'

'

'

'

'

'

'

'

'

Line of credit facility term

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'6 years

Variable rate basis

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'LIBOR

Amount of customary default of indebtedness

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowings outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$31,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

LongTerm_Debt_Details_2

Long-Term Debt (Details 2) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Deferred Financing Costs and Original Issue Discount	'	'	'
Amortization of deferred financing costs reported as interest expense and other financing costs	$2	$4.10	$4.20
Estimated amortization of deferred financing costs	'	'	'
2014	1.9	'	'
2015	1.9	'	'
2016	1.9	'	'
2017	1.8	'	'
2018	0.9	'	'
Thereafter	3.5	'	'
Total	11.9	'	'
Capital lease obligations	51.2	'	'
Future payments required under capital leases	'	'	'
Less: current portion	-1.3	-1.1	'
Long-term portion	49.9	51.2	'
Wynnewood Acquisition | Capital lease	'	'	'
Future payments required under capital leases	'	'	'
2014	6.3	'	'
2015	6.4	'	'
2016	6.4	'	'
2017	6.4	'	'
2018	6.5	'	'
2019 and thereafter	70.3	'	'
Total future payments	102.3	'	'
Less: amount representing interest	51.1	'	'
Present value of future minimum payments	51.2	'	'
Less: current portion	-1.3	'	'
Long-term portion	$49.90	'	'
Wynnewood Acquisition | Capital Lease related to Excel Pipeline LLC	'	'	'
Estimated amortization of deferred financing costs	'	'	'
Remaining term of leases	'190 months	'	'
Wynnewood Acquisition | Capital Lease related to Magellan Pipeline Terminals, L.P.	'	'	'
Estimated amortization of deferred financing costs	'	'	'
Remaining term of leases	'189 months	'	'

Partners_Capital_and_Partnersh2

Partners' Capital and Partnership Distributions (Details) (USD $)	2 Months Ended		3 Months Ended		11 Months Ended	12 Months Ended	0 Months Ended	7 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2013		Sep. 30, 2013	Jun. 30, 2013	Dec. 31, 2013	Dec. 31, 2013	Jan. 23, 2013	Dec. 31, 2013
					partnership_interest	partnership_interest	CVR Refining Holdings	CVR Refining Holdings
Equity [Abstract]	'		'	'	'	'	'	'
Number of types of partnership interests outstanding	'		'	'	2	2	'	'
Common units issued (in shares)	'		'	'	147,600,000	147,600,000	'	'
Maximum period after the end of each quarter of cash distribution to common unitholders	'		'	'	'	'60 days	'	'
Amount paid to CVR Refining Holdings, LLC and affiliates	$195.90	[1]	$33.20	$149.60	$378.70	'	'	'
Amounts paid to non-affiliates	37.3	[1]	11.1	49.7	98	'	'	'
Total amount paid	$233.20	[1]	$44.30	$199.30	$476.70	'	'	'
Cash distributions paid per common unit (in dollars per share)	$1.58	[1]	$0.30	$1.35	$3.23	'	'	'
Common units outstanding (in shares)	147,600,000		147,600,000	147,600,000	147,600,000	147,600,000	'	'
Partners' Capital and Partnership Distributions	'		'	'	'	'	'	'
Number of issued and outstanding common units owned	'		'	'	'	'	'	104,790,764
Percentage of outstanding units owned by CVR Refining Holdings	'		'	'	'	'	81.00%	71.00%
[1]	(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				12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2013
Earnings Per Share [Abstract]	'	'	'	'	'
Net income subsequent to initial public offering (January 23, 2013 through December 31, 2013)	($110.20)	$86	$339.20	$197.50	$512.60
Net income per common unit - basic (in dollars per share)	($0.75)	$0.58	$2.30	$1.34	$3.47	[1]
Net income per common unit - diluted (in dollars per share)	($0.75)	$0.58	$2.30	$1.34	$3.47	[1]
Weighted-average common units outstanding, basic (in shares)	147.6	147.6	147.6	147.6	147.6
Weighted-average common units outstanding, diluted (in shares)	147.6	147.6	147.6	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 11 to the consolidated and combined financial statements.

Benefit_Plans_Details

Benefit Plans (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Benefit Plans	'	'	'
Number of defined-contribution 401(k) plans	2	'	'
Vesting schedule for employer's matching funds	'3 years	'	'
CVR Energy	'	'	'
Benefit Plans	'	'	'
Employee contribution limit per calendar year as a percentage of annual salaries	50.00%	'	'
Employee contribution limit per calendar year as a percentage of annual income sharing	100.00%	'	'
Matching contributions made by the company during the year	$4.20	$3.30	$1.40
Nonunion plan | CVR Energy	'	'	'
Benefit Plans	'	'	'
Percentage employer matches of employee's contribution	100.00%	'	'
Percentage of eligible compensation, matched by employer	6.00%	'	'
Union plan | CVR Energy	'	'	'
Benefit Plans	'	'	'
Percentage employer matches of employee's contribution	100.00%	'	'
Percentage of eligible compensation, matched by employer	6.00%	'	'

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
Operating Leases	'		'	'
2014	$2.50		'	'
2015	1.5		'	'
2017	1		'	'
2017	0.3		'	'
2018	0.1		'	'
Thereafter	0.3		'	'
Operating leases	5.7		'	'
Unconditional Purchase Obligations	'		'	'
2014	110.8	[1]	'	'
2015	104.9	[1]	'	'
2016	97.8	[1]	'	'
2017	96.5	[1]	'	'
2018	96.6	[1]	'	'
Thereafter	874.5	[1]	'	'
Unconditional purchase obligations	1,381.10	[1]	'	'
Lease expenses	3.2		2.9	1.4
Storage Capacity and Pipeline Transportation Services	'		'	'
Unrecorded purchase agreements	'		'	'
Expense incurred related to long-term purchase commitments	117.1		107.5	83.1
CRRM | Petroleum transportation service agreement with TransCanada	'		'	'
Unrecorded purchase agreements	'		'	'
Amount payable related to petroleum transportation service agreements	$973		'	'
Period over which minimum quantity of crude oil is receivable	'17 years		'	'
Minimum quantity of crude oil to be received per day (in barrels)	25,000		'	'
Period over which minimum quantity of crude oil is receivable	'20 years		'	'
CRRM | New Vitol Agreement	'		'	'
Unrecorded purchase agreements	'		'	'
Renewal term of agreement	'1 year		'	'
Period for prior notice of nonrenewal	'180 days		'	'
[1]	This amount includes approximately $973.0 million payable ratably over seventeen 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 $)

12 Months Ended

1 Months Ended

12 Months Ended

5 Months Ended

1 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jun. 30, 2010

Oct. 31, 2009

31-May-08

Dec. 31, 2013

Oct. 25, 2010

Jul. 02, 2013

Feb. 12, 2013

Jul. 31, 2009

Jul. 31, 2009

31-May-10

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

CRRM

CRRM

CRRM

CRRM

CRRM

Flood Crude Oil Discharge and Insurance

Flood Crude Oil Discharge and Insurance

Oklahoma

New Mexico

Oklahoma and Kansas

Litigation

Litigation

Litigation

Long-term commitments

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of lawsuits filed

'

'

'

'

'

'

'

'

'

'

15

2

2

Number of private claimants

'

'

'

'

'

16

'

'

'

'

'

'

'

Aggregate amount of claims

'

'

'

$3.20

$3.20

$4.40

'

'

'

'

'

'

'

Number of additional plaintiffs

'

'

'

'

3

'

'

'

'

'

'

'

'

Number of claims not settled

'

'

'

'

'

'

1

'

'

'

'

'

'

Reimbursement of oversight cost

'

'

'

'

'

'

'

1.8

'

'

'

'

'

Civil penalty related to Clean Water Act claims

'

'

'

'

'

'

'

'

'

0.6

'

'

'

Amount of reimbursement agreed for oversight cost

'

'

'

'

'

'

'

'

'

1.7

'

'

'

Civil penalty related to Risk Management Program

'

'

'

'

'

'

'

'

0.3

'

'

'

'

Insurance proceeds under primary environmental liability insurance policy

$1.30

$0.70

$0

'

'

'

$25

'

'

'

'

'

'

Commitments_and_Contingencies_3

Commitments and Contingencies (Details 3) (USD $)

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Mar. 31, 2012

Mar. 31, 2012

Dec. 31, 2013

Sep. 28, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Aug. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

EHS

EHS

EHS

EHS

EHS

Mobile Source Air Toxic II

Wynnewood refinery incident

CRRM

CRRM

CRRM

CRRM

WRC Refinery

WRC Refinery

WRC Refinery

landfill

landfill

Minimum

Maximum

employee

EHS

EHS

Propose Tier 3 Gasoline Sulfur Standards

Mobile Source Air Toxic II

Mobile Source Air Toxic II

issue

Maximum

Commitments and Contingencies

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Offset for potential recoveries

'

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Environmental accruals

'

1,500,000

2,300,000

'

'

'

'

'

'

'

'

'

'

'

'

Environmental accruals included in other current liabilities

'

300,000

700,000

'

'

'

'

'

'

'

'

'

'

'

'

Estimated closure and post-closure costs

'

700,000

800,000

'

'

'

'

'

'

'

'

'

'

'

'

Number of landfills

'

2

2

'

'

'

'

'

'

'

'

'

'

'

'

Estimated future payments for environmental obligations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2014

'

300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

2015

'

200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

2016

'

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

2017

'

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

2018

'

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Thereafter

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Undiscounted total

'

1,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Less amounts representing interest at 2.73%

'

300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued environmental liabilities at the end of the year

'

1,500,000

2,300,000

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate (as a percent)

2.73%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acceleration of project completion

'

'

'

'

'

'

'3 months

'

'

'

'

'

'

'

'

Environmental Cost Expected

'

'

'

'

'

'

'

'

'

'

20,000,000

63,000,000

'

'

105,000,000

Expense incurred to date for capital expenditures

'

'

'

'

'

'

'

'

'

'

'

24,600,000

'

'

52,200,000

Required percentage of renewable fuel

'

9.74%

'

'

'

'

'

'

'

'

'

'

'

'

'

Expense incurred to purchase renewable identification numbers

'

180,500,000

21,000,000

19,000,000

'

'

'

'

'

'

'

'

'

'

'

Biofuels blending obligation

'

17,400,000

1,100,000

'

'

'

'

'

'

'

'

'

'

'

'

Marquee issues under the Clean Air Act

'

'

'

'

'

'

'

'

'

4

'

'

'

'

'

Percentage of required refining capacity

'

'

'

'

'

'

'

'

90.00%

'

'

'

'

'

'

Environmental civil penalty

'

'

'

'

'

'

'

'

700,000

'

'

'

'

'

'

Remaining 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

'

$111,300,000

$27,900,000

$7,400,000

'

'

'

'

'

'

'

'

'

'

'

Number of employees fatally injured

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (Recurring, USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
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	0
Other current liabilities (biofuel blending obligation)	0	0
Other long-term liabilities (derivative agreements)	0	'
Total Liabilities	0	0
Level 2	'	'
Fair Value Measurements	'	'
Other current assets (derivative agreements)	0.9	'
Other long-term assets (derivative agreements)	0.1	0.9
Total Assets	1	0.9
Other current liabilities (derivative agreements)	-15.3	-67.7
Other current liabilities (biofuel blending obligation)	-16.2	-1.1
Other long-term liabilities (derivative agreements)	-1.8	'
Total Liabilities	-33.3	-68.8
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	0
Other current liabilities (biofuel blending obligation)	0	0
Other long-term liabilities (derivative agreements)	0	'
Total Liabilities	0	0
Total	'	'
Fair Value Measurements	'	'
Other current assets (derivative agreements)	0.9	'
Other long-term assets (derivative agreements)	0.1	0.9
Total Assets	1	0.9
Other current liabilities (derivative agreements)	-15.3	-67.7
Other current liabilities (biofuel blending obligation)	-16.2	-1.1
Other long-term liabilities (derivative agreements)	-1.8	'
Total Liabilities	($33.30)	($68.80)

Derivatives_and_Financial_Inst2

Derivatives and Financial Instruments (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Derivative Financial Instruments	'	'	'	'	'	'	'	'	'	'	'
Current period settlements on derivative contracts	'	'	'	'	'	'	'	'	$6.40	($137.60)	($7.20)
Gain (loss) on derivatives, net	-115.9	72.5	120.5	-20	-8.2	-168.9	38.8	-147.2	57.1	-285.6	78.1
Commodity derivatives	'	'	'	'	'	'	'	'	'	'	'
Derivative Financial Instruments	'	'	'	'	'	'	'	'	'	'	'
Gain (loss) on derivatives, net	'	'	'	'	'	'	'	'	-2.9	-11.7	-2.6
Commodity swap	'	'	'	'	'	'	'	'	'	'	'
Derivative Financial Instruments	'	'	'	'	'	'	'	'	'	'	'
Gain (loss) on derivatives, net	'	'	'	'	'	'	'	'	60.1	-273.9	80.4
Commodity swap | Not designated as hedges	'	'	'	'	'	'	'	'	'	'	'
Derivative Financial Instruments	'	'	'	'	'	'	'	'	'	'	'
Number of barrels	23,300,000	'	'	'	23,300,000	'	'	'	23,300,000	23,300,000	'
Net unrealized loss	16.1	'	'	'	-66.8	'	'	'	16.1	-66.8	'
Portion of net unrealized loss in current assets	0.9	'	'	'	'	'	'	'	0.9	'	'
Portion of net unrealized gain in non-current assets	0.1	'	'	'	0.9	'	'	'	0.1	0.9	'
Portion of net unrealized loss in current liabilities	-15.3	'	'	'	-67.7	'	'	'	-15.3	-67.7	'
Portion of net unrealized loss in non-current liabilities	($1.80)	'	'	'	'	'	'	'	($1.80)	'	'

Derivatives_and_Financial_Inst3

Derivatives and Financial Instruments (Details 2) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Current Assets	'	'
Offsetting assets	'	'
Gross Assets	$4.30	'
Gross Amounts Offset	-3.4	'
Net Assets Presented	0.9	'
Cash Collateral Not Offset	0	'
Net Amount	0.9	'
Non-Current Assets	'	'
Offsetting assets	'	'
Gross Assets	0.1	0.9
Gross Amounts Offset	0	0
Net Assets Presented	0.1	0.9
Cash Collateral Not Offset	0	0
Net Amount	0.1	0.9
Current Liabilities	'	'
Offsetting liabilities	'	'
Gross Liabilities	31.4	74.2
Gross Amounts Offset	-16.1	-6.5
Net Liabilities Presented	15.3	67.7
Cash Collateral Not Offset	0	0
Net Amount	15.3	67.7
Non-Current Liabilities	'	'
Offsetting liabilities	'	'
Gross Liabilities	1.9	'
Gross Amounts Offset	-0.1	'
Net Liabilities Presented	1.8	'
Cash Collateral Not Offset	0	'
Net Amount	1.8	'
Commodity Swaps | Current Assets	'	'
Offsetting assets	'	'
Gross Assets	4.3	'
Gross Amounts Offset	-3.4	'
Net Assets Presented	0.9	'
Cash Collateral Not Offset	0	'
Net Amount	0.9	'
Commodity Swaps | Non-Current Assets	'	'
Offsetting assets	'	'
Gross Assets	0.1	0.9
Gross Amounts Offset	0	0
Net Assets Presented	0.1	0.9
Cash Collateral Not Offset	0	0
Net Amount	0.1	0.9
Commodity Swaps | Current Liabilities	'	'
Offsetting liabilities	'	'
Gross Liabilities	31.4	74.2
Gross Amounts Offset	-16.1	-6.5
Net Liabilities Presented	15.3	67.7
Cash Collateral Not Offset	0	0
Net Amount	15.3	67.7
Commodity Swaps | Non-Current Liabilities	'	'
Offsetting liabilities	'	'
Gross Liabilities	1.9	'
Gross Amounts Offset	-0.1	'
Net Liabilities Presented	1.8	'
Cash Collateral Not Offset	0	'
Net Amount	$1.80	'

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)

3 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 30, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

4-May-12

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Jan. 23, 2013

Dec. 31, 2013

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

Lease Agreement

Lease Agreement

Lease Agreement

Environmental Agreement

Limited Partnership Agreement

CRRM

CRRM

CRRM

Coffeyville Resources LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

Coffeyville Resources Nitrogen Fertilizers LLC

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

CVR Energy, Inc

Coffeyville Resources LLC

Navistar International Corporation

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

Intercompany Credit Facility

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

Coffeyville Resources Terminal LLC

Coffeyville Resources Terminal LLC

Coffeyville Resources Terminal LLC

General Partner Interest

General Partner Interest

General Partner Interest

GS, Kelso and the president, chief executive officer and chairman of the board of CVR Energy

Intercompany Credit Facility

truck

Tail gas

Tail gas

Tail gas

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

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

Services Agreement

Services Agreement

Services Agreement

Minimum

Nitrogen

Nitrogen

Nitrogen

Tail gas

Tank capacity

Tank capacity

Tank capacity

T

Minimum

Minimum

Maximum

Minimum

Maximum

Minimum

Maximum

T

renewal

Related party transactions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenue from related party

$2,360,900,000

$1,910,500,000

$2,138,100,000

$2,274,000,000

$1,816,200,000

$2,337,400,000

$2,229,600,000

$1,898,500,000

$8,683,500,000

$8,281,700,000

$4,752,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$600,000

$200,000

$1,000,000

'

'

'

'

'

'

'

'

'

$9,600,000

$9,900,000

$11,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost of product sold (exclusive of depreciation and amortization)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

11,400,000

6,300,000

14,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accounts payable, due to affiliates

17,700,000

'

'

'

400,000

'

'

'

17,700,000

400,000

'

2,600,000

200,000

300,000

400,000

'

'

'

200,000

200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

14,800,000

'

'

'

'

'

Related party transaction reimbursed payment of direct operating costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-100,000

10,000

200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount paid for direct operating expenses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

200,000

200,000

200,000

'

'

'

'

'

'

500,000

1,400,000

1,500,000

'

300,000

100,000

300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Prepaid expenses and other current assets, due from affiliates

1,500,000

'

'

'

900,000

'

'

'

1,500,000

900,000

'

'

'

1,000,000

400,000

'

'

'

300,000

500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

600,000

600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other long-term assets, due from affiliates

100,000

'

'

'

400,000

'

'

'

100,000

400,000

'

'

'

'

'

'

'

'

100,000

400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liability included in other non-current liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,100,000

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Transaction notice period for termination of agreement during any renewal term

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'180 days

'

'

'

'

'

'

'

'

Transaction annual rent to be paid

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

Fees to be paid for urea ammonium nitrate placed into terminal

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

'

'

'

'

'

'

'

'

Fees to be paid for urea ammonium nitrate placed out of terminal

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

'

'

'

'

'

'

'

'

Operating lease revenue

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000

100,000

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000

18,000

'

'

'

'

'

'

Number of times the agreement can be renewed

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

'

'

'

'

'

'

'

'

'

Additional renewal period of agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'1 year

'

'

'

'

'

'

'

'

'

'

'

Notice period for renewal of agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'60 days

'

'

'

'

'

'

'

'

'

'

Notice period for exclusion of service from agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'180 days

'

'

'

'

'

Expenses from transactions with related party

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

87,300,000

'

'

'

'

'

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

20,000,000

18,900,000

20,200,000

18,600,000

18,600,000

21,200,000

26,100,000

20,200,000

77,800,000

86,200,000

51,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

62,100,000

'

'

'

'

'

Direct operating expenses (exclusive of depreciation and amortization)

87,200,000

104,700,000

83,800,000

86,000,000

173,400,000

88,800,000

71,600,000

92,700,000

361,700,000

426,500,000

247,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25,200,000

'

'

'

'

'

Net reimbursed or (paid) direct operating expenses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

150,000,000

'

Line of credit facility term

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'6 years

'

Variable rate basis

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'LIBOR

'

Basis spread on variable rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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3.00%

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Borrowings outstanding

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31,500,000

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Number of trucks purchased

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7

Purchases from related party

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800,000

Expenses related to registration rights agreement

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'

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$500,000

'

'

Major_Customers_and_Suppliers_1

Major Customers and Suppliers (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Sales | Customer concentration	'	'	'
Major Customers and Suppliers	'	'	'
Concentration risk (as a percent)	21.00%	19.00%	27.00%
Sales | Customer concentration | Customer A	'	'	'
Major Customers and Suppliers	'	'	'
Concentration risk (as a percent)	12.00%	10.00%	15.00%
Sales | Customer concentration | Customer B	'	'	'
Major Customers and Suppliers	'	'	'
Concentration risk (as a percent)	9.00%	9.00%	12.00%
Contracted volume | Supplier concentration | Supplier A	'	'	'
Major Customers and Suppliers	'	'	'
Concentration risk (as a percent)	69.00%	45.00%	65.00%
Contracted volume | Supplier concentration | CRRM	'	'	'
Major Customers and Suppliers	'	'	'
Number of major suppliers	1	1	1

Selected_Quarterly_Financial_I2

Selected Quarterly Financial Information (unaudited) (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
Quarterly Financial Information Disclosure [Abstract]	'	'	'	'	'	'	'	'	'		'	'
Net sales	$2,360.90	$1,910.50	$2,138.10	$2,274	$1,816.20	$2,337.40	$2,229.60	$1,898.50	$8,683.50		$8,281.70	$4,752.80
Operating costs and expenses:	'	'	'	'	'	'	'	'	'		'	'
Cost of product sold (exclusive of depreciation and amortization)	2,209.70	1,734.70	1,776.60	1,805.80	1,476.50	1,694.10	1,866.20	1,630.70	7,526.70		6,667.50	3,927.60
Direct operating expenses (exclusive of depreciation and amortization)	87.2	104.7	83.8	86	173.4	88.8	71.6	92.7	361.7		426.5	247.7
Selling, general and administrative (exclusive of depreciation and amortization)	20	18.9	20.2	18.6	18.6	21.2	26.1	20.2	77.8		86.2	51
Depreciation and amortization	29.1	28.8	28.4	28	27.3	27.5	26.6	26.3	114.3		107.6	69.8
Total operating costs and expenses	2,346	1,887.10	1,909	1,938.40	1,695.80	1,831.60	1,990.50	1,769.90	8,080.50		7,287.80	4,296.10
Operating income	14.9	23.4	229.1	335.6	120.4	505.8	239.1	128.6	603		993.9	456.7
Other income (expense):	'	'	'	'	'	'	'	'	'		'	'
Interest expense and other financing costs	-9.3	-10	-10.6	-14.2	-20.2	-18.2	-19	-18.8	-44.1		-76.2	-53
Interest income	0.1	0.1	0.1	0.1	0	0	0	0	0.4		0	0
Gain (loss) on derivatives, net	-115.9	72.5	120.5	-20	-8.2	-168.9	38.8	-147.2	57.1		-285.6	78.1
Loss on extinguishment of debt	0	0	0	-26.1	-37.5	0	0	0	-26.1		-37.5	-2.1
Other income (expense), net	0	0	0.1	0	0.1	-0.1	0.6	0	0.1		0.7	0.6
Total other income (expense)	-125.1	62.6	110.1	-60.2	-65.8	-187.2	20.4	-166	-12.6		-398.6	23.6
Income before income tax expense	-110.2	86	339.2	275.4	54.6	318.6	259.5	-37.4	590.4		595.3	480.3
Income taxes	0	0	0	0	0	0	0	0	0		0	0
Net income	-110.2	86	339.2	275.4	54.6	318.6	259.5	-37.4	590.4		595.3	480.3
Net income subsequent to initial public offering (January 23, 2013 through December 31, 2013)	($110.20)	$86	$339.20	$197.50	'	'	'	'	$512.60		'	'
Net income per common unit - basic (in dollars per share)	($0.75)	$0.58	$2.30	$1.34	'	'	'	'	$3.47	[1]	'	'
Net income per common unit - diluted (in dollars per share)	($0.75)	$0.58	$2.30	$1.34	'	'	'	'	$3.47	[1]	'	'
Weighted-average common units outstanding:	'	'	'	'	'	'	'	'	'		'	'
Basic (in shares)	147.6	147.6	147.6	147.6	'	'	'	'	147.6		'	'
Diluted (in shares)	147.6	147.6	147.6	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 11 to the consolidated and combined financial statements.

Subsequent_Events_Details

Subsequent Events (Details) (Subsequent event, USD $)	0 Months Ended
In Millions, except Per Share data, unless otherwise specified	Feb. 19, 2014
Subsequent event	'
Subsequent Events	'
Cash distribution declared (in dollars per unit)	$0.45
Aggregate cash distribution declared	$66.40