CVR Energy (CVI) 10-Q 3 Nov 14 2014 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2014	Oct. 28, 2014
Document and Entity Information	'	'
Entity Registrant Name	'CVR ENERGY INC	'
Entity Central Index Key	'0001376139	'
Document Type	'10-Q	'
Document Period End Date	30-Sep-14	'
Amendment Flag	'false	'
Current Fiscal Year End Date	'--12-31	'
Entity Current Reporting Status	'Yes	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	86,831,050
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q3	'

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$793.10	$842.10
Accounts receivable, net of allowance for doubtful accounts of $0.5 and $0.9, respectively	230.5	241.9
Inventories	516.8	526.6
Prepaid expenses and other current assets	213.6	82.5
Income tax receivable	2.7	10.8
Deferred income taxes	8.8	27.8
Total current assets	1,765.50	1,731.70
Property, plant, and equipment, net of accumulated depreciation	1,909.60	1,864.40
Intangible assets, net	0.2	0.3
Goodwill	41	41
Deferred financing costs, net	9.1	11.2
Other long-term assets	27	17.2
Total assets	3,752.40	3,665.80
Current liabilities:	'	'
Note payable and capital lease obligations	1.4	1.3
Accounts payable	421.2	377.9
Personnel accruals	49.5	45.8
Accrued taxes other than income taxes	23	31.5
Due to parent	15.8	0.1
Deferred revenue	1.8	0.7
Other current liabilities	61.3	44.2
Total current liabilities	574	501.5
Long-term liabilities:	'	'
Long-term debt and capital lease obligations, net of current portion	673.9	674.9
Accrued environmental liabilities, net of current portion	1	1.2
Deferred income taxes	600.4	601.7
Other long-term liabilities	48.8	51.1
Total long-term liabilities	1,324.10	1,328.90
Commitments and contingencies	'	'
CVR stockholders’ equity:	'	'
Common stock $0.01 par value per share, 350,000,000 shares authorized, 86,929,660 shares issued	0.9	0.9
Additional paid-in-capital	1,174.70	1,114.40
Retained earnings (deficit)	-75.2	76.2
Treasury stock, 98,610 shares at cost	-2.3	-2.3
Accumulated other comprehensive income (loss), net of tax	7.6	-0.6
Total CVR stockholders’ equity	1,105.70	1,188.60
Noncontrolling interest	748.6	646.8
Total equity	1,854.30	1,835.40
Total liabilities and equity	$3,752.40	$3,665.80

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, except Share data, unless otherwise specified
Statement of Financial Position [Abstract]	'	'
Accounts receivable, allowance for doubtful accounts (in dollars)	$0.50	$0.90
Common stock, par value (in dollars per share)	$0.01	$0.01
Common stock, shares authorized	350,000,000	350,000,000
Common stock, shares issued	86,929,660	86,929,660
Treasury stock, shares	98,610	98,610

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	3 Months Ended		9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Income Statement [Abstract]	'	'	'	'
Net sales	$2,279.90	$1,977.10	$7,267.70	$6,549.80
Operating costs and expenses:	'	'	'	'
Cost of product sold (exclusive of depreciation and amortization)	2,066.70	1,744.40	6,332.60	5,343.50
Direct operating expenses (exclusive of depreciation and amortization)	136.8	128.4	380.3	345.2
Selling, general and administrative expenses (exclusive of depreciation and amortization)	31.8	27.7	86.2	85
Depreciation and amortization	37.8	36.2	113.7	105.4
Total operating costs and expenses	2,273.10	1,936.70	6,912.80	5,879.10
Operating income	6.8	40.4	354.9	670.7
Other income (expense):	'	'	'	'
Interest expense and other financing costs	-9.4	-11.7	-28.8	-39.6
Interest income	0.3	0.3	0.7	0.9
Gain on derivatives, net	25.7	72.5	171.1	173
Loss on extinguishment of debt	0	0	0	-26.1
Other income (expense), net	2.1	6.2	-0.1	6.5
Total other income	18.7	67.3	142.9	114.7
Income before income taxes	25.5	107.7	497.8	785.4
Income tax expense	4.2	29.5	118.8	222.8
Net income	21.3	78.2	379	562.6
Less: Net income attributable to noncontrolling interest	13.4	34.2	160.7	170.2
Net income attributable to CVR Energy stockholders	$7.90	$44	$218.30	$392.40
Basic earnings per share (in dollars per share)	$0.09	$0.51	$2.51	$4.52
Diluted earnings per share (in dollars per share)	$0.09	$0.51	$2.51	$4.52
Dividends declared per share (in dollars per share)	$2.75	$0.75	$4.25	$13.50
Weighted-average common shares outstanding:	'	'	'	'
Basic (in shares)	86.8	86.8	86.8	86.8
Diluted (in shares)	86.8	86.8	86.8	86.8

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Statement of Comprehensive Income [Abstract]	'	'	'	'
Net income	$21.30	$78.20	$379	$562.60
Other comprehensive income (loss):	'	'	'	'
Unrealized gain on available-for-sale securities, net of tax of $5.2, $1.5, $5.2 and $2.4	8	2.3	8	3.7
Net gain reclassified into income on sale of available-for-sale securities, net of tax of $0, $(2.4), $0 and $(2.4)	0	-3.7	0	-3.7
Change in fair value of interest rate swap, net of tax of $0, $(0.1), $0 and $0	0	-0.2	-0.1	-0.1
Net loss reclassified into income on settlement of interest rate swap, net of tax of $0.1, $0.1, $0.2 and $0.2 (Note 13)	0.2	0.3	0.6	0.6
Total other comprehensive income (loss)	8.2	-1.3	8.5	0.5
Comprehensive income	29.5	76.9	387.5	563.1
Less: Comprehensive income attributable to noncontrolling interest	13.5	34.2	161	170.4
Comprehensive income attributable to CVR Energy stockholders	$16	$42.70	$226.50	$392.70

CONDENSED_CONSOLIDATED_STATEME2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Statement of Comprehensive Income [Abstract]	'	'	'	'
Unrealized gain on available-for-sale securities, tax	$5.20	$1.50	$5.20	$2.40
Net gain reclassified into income on sale of AFS securities, tax	0	-2.4	0	-2.4
Change in fair value of interest rate swap, tax	0	-0.1	0	0
Net loss reclassified into income on settlement of interest rate swap, tax	$0.10	$0.10	$0.20	$0.20

CONDENSED_CONSOLIDATED_STATEME3

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY (USD $)

Total

CVR Partners, LP

CVR Refining, LP

Total CVR Stockholders' Equity

$0.01 Par Value Common Stock

Additional Paid-In Capital

Retained Earnings (Deficit)

Treasury Stock

Accumulated Other Comprehensive Income (Loss)

Noncontrolling Interest

Noncontrolling Interest

Noncontrolling Interest

In Millions, except Share data, unless otherwise specified

CVR Partners, LP

CVR Refining, LP

Balance at Dec. 31, 2013

$1,835.40

'

'

$1,188.60

$0.90

$1,114.40

$76.20

($2.30)

($0.60)

$646.80

'

'

Balance (in shares) at Dec. 31, 2013

86,800,000

'

'

'

86,929,660

'

'

'

'

'

'

'

Increase (Decrease) in Stockholders' Equity

'

'

'

'

'

'

'

'

'

'

'

'

June issuance of CVR Refining's common units to the public, net of $39.4 tax impact

148.9

'

'

60.3

'

60.3

'

'

'

88.6

'

'

June issuance of CVR Refining's common units to the public tax

39.4

'

'

'

'

'

'

'

'

'

'

'

Dividends paid to CVR Energy stockholders

-369

'

'

-369

'

'

-369

'

'

'

'

'

Distributions to noncontrolling interest holders

'

-39

-109.5

'

'

'

'

'

'

'

-39

-109.5

Share-based compensation

0

'

'

-0.7

'

0

-0.7

'

'

0.7

'

'

Net income

379

'

'

218.3

'

'

218.3

'

'

160.7

'

'

Net unrealized gain on available for sale securities, net of tax

8

'

'

8

'

'

'

'

8

'

'

'

Net gain on interest rate swaps, net of tax

0.5

'

'

0.2

'

'

'

'

0.2

0.3

'

'

Balance at Sep. 30, 2014

$1,854.30

'

'

$1,105.70

$0.90

$1,174.70

($75.20)

($2.30)

$7.60

$748.60

'

'

Balance (in shares) at Sep. 30, 2014

'

'

'

'

86,929,660

'

'

'

'

'

'

'

CONDENSED_CONSOLIDATED_STATEME4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Cash flows from operating activities:	'	'
Net income	$379	$562.60
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation and amortization	113.7	105.4
Allowance for doubtful accounts	-0.4	0.6
Amortization of deferred financing costs	2.1	2.2
Deferred income taxes	-28.5	-72.1
Loss on disposition of assets	0.2	0
Loss on extinguishment of debt	0	26.1
Share-based compensation	10.8	13.7
Gain on sale of available-for-sale securities	0	-6.1
Gain on derivatives, net	-171.1	-173
Current period settlements on derivative contracts	93.2	-3.9
Changes in assets and liabilities:	'	'
Accounts receivable	11.8	-30.9
Inventories	9.8	-152.2
Prepaid expenses and other current assets	13.1	12.3
Other long-term assets	-1.9	-0.4
Accounts payable	55.9	-21.3
Due to parent	15.7	42.9
Accrued income tax	8.1	1
Deferred revenue	1.1	-0.2
Other current liabilities	16.7	14.8
Accrued environmental liabilities	-0.2	-0.2
Other long-term liabilities	1.7	0
Net cash provided by operating activities	530.8	321.3
Cash flows from investing activities:	'	'
Capital expenditures	-171.4	-183.6
Proceeds from sale of assets	0.1	0.1
Purchase of available-for-sale securities	-78.3	-18.6
Proceeds from sale of available-for-sale securities	0	24.7
Net cash used in investing activities	-249.6	-177.4
Cash flows from financing activities:	'	'
Payment of capital lease obligations	-1	-0.9
Payments on senior secured notes	0	-243.4
Payment of financing costs	0	-0.4
Redemption of common units	0	-0.2
Dividends to CVR Energy's stockholders	-369	-1,172.20
Net cash used in financing activities	-330.2	-152.8
Net decrease in cash and cash equivalents	-49	-8.9
Cash and cash equivalents, beginning of period	842.1	896
Cash and cash equivalents, end of period	793.1	887.1
Supplemental disclosures:	'	'
Cash paid for income taxes, net of refunds	123.4	251.1
Cash paid for interest net of capitalized interest of $8.2 and $2.0 in 2014 and 2013, respectively	18.4	36.6
Non-cash investing and financing activities:	'	'
Construction in process additions included in accounts payable	20.1	32
Change in accounts payable related to construction in process additions	-12.7	-24.2
CVR Refining, LP	'	'
Cash flows from financing activities:	'	'
Distributions to noncontrolling interest holders	-109.5	-37.7
CVR Partners, LP	'	'
Cash flows from financing activities:	'	'
Distributions to noncontrolling interest holders	-39	-101.4
Initial Public Offering | CVR Refining, LP	'	'
Cash flows from financing activities:	'	'
Proceeds from CVR Refining and Partner's offering, net of offering costs	0	655.7
Underwritten Offering | CVR Refining, LP	'	'
Cash flows from financing activities:	'	'
Proceeds from CVR Refining and Partner's offering, net of offering costs	0	393.6
Private placement | CVR Refining, LP	'	'
Cash flows from financing activities:	'	'
Proceeds from CVR Refining and Partner's offering, net of offering costs	0	61.5
Second Underwritten Offering | CVR Refining, LP	'	'
Cash flows from financing activities:	'	'
Proceeds from CVR Refining and Partner's offering, net of offering costs	188.3	0
Secondary Offering | CVR Partners, LP	'	'
Cash flows from financing activities:	'	'
Proceeds from CVR Refining and Partner's offering, net of offering costs	$0	$292.60

CONDENSED_CONSOLIDATED_STATEME5

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Statement of Cash Flows [Abstract]	'	'	'	'
Capitalized interest	$3	$0.80	$8.20	$2

Organization_and_History_of_th

Organization and History of the Company and Basis of Presentation	9 Months Ended
	Sep. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Organization and History of the Company and Basis of Presentation	'
	(1) Organization and History of the Company and Basis of Presentation
	Organization
	The “Company,” “CVR Energy” or “CVR” are used in this report to refer to CVR Energy, Inc. and, unless the context otherwise requires, its subsidiaries.
	CVR is a diversified holding company primarily engaged in the petroleum refining and nitrogen fertilizer manufacturing industries through its holdings in CVR Refining, LP (“CVR Refining” or the “Refining Partnership”) and CVR Partners, LP (“CVR Partners” or the “Nitrogen Fertilizer Partnership”). The Refining Partnership is an independent petroleum refiner and marketer of high value transportation fuels. The Nitrogen Fertilizer Partnership produces nitrogen fertilizers in the form of UAN and ammonia. The Company reports in two business segments: the petroleum segment (the operations of CVR Refining) and the nitrogen fertilizer segment (the operations of CVR Partners).
	CVR’s common stock is listed on the NYSE under the symbol “CVI.” On May 7, 2012, IEP Energy LLC and certain of its affiliates (collectively, “IEP”) announced that they had acquired control of CVR pursuant to a tender offer for all of the Company's common stock (the “IEP Acquisition”). As of September 30, 2014, IEP owned approximately 82% of all of the outstanding shares of CVR.
	CVR Partners, LP
	On April 13, 2011, the Nitrogen Fertilizer Partnership completed its initial public offering (the “Nitrogen Fertilizer Partnership IPO”). The common units, which are listed on the NYSE, began trading on April 8, 2011 under the symbol “UAN.” In connection with the Nitrogen Fertilizer Partnership IPO and through May 27, 2013, the Company recorded a 30% noncontrolling interest for the common units sold into the public market. On May 28, 2013, Coffeyville Resources, LLC (“CRLLC”), a wholly-owned subsidiary of the Company, completed a registered public offering (the “Secondary Offering”) whereby it sold 12,000,000 Nitrogen Fertilizer Partnership common units to the public at a price of $25.15 per unit.
	Subsequent to the closing of the Secondary Offering and as of September 30, 2014, public security holders held approximately 47% of the total outstanding Nitrogen Fertilizer Partnership common units, and CRLLC held approximately 53% of the total Nitrogen Fertilizer Partnership common units. In addition, CRLLC owns 100% of the Nitrogen Fertilizer Partnership’s general partner, CVR GP, LLC, which only holds a non-economic general partner interest. The noncontrolling interest reflected on the Condensed Consolidated Balance Sheets of CVR is impacted by the net income of, and distributions from, the Nitrogen Fertilizer Partnership.
	The Nitrogen Fertilizer Partnership has adopted a policy pursuant to which the Nitrogen Fertilizer Partnership 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 Nitrogen Fertilizer Partnership’s general partner following the end of such quarter. The partnership agreement does not require that the Nitrogen Fertilizer Partnership make cash distributions on a quarterly basis or at all, and the board of directors of the general partner of the Nitrogen Fertilizer Partnership can change the Nitrogen Fertilizer Partnership's distribution policy at any time.
	The Nitrogen Fertilizer Partnership is operated by CVR’s senior management (together with other officers of the general partner) pursuant to a services agreement among CVR, the general partner and the Nitrogen Fertilizer Partnership. The Nitrogen Fertilizer Partnership’s general partner manages the operations and activities of the Nitrogen Fertilizer Partnership, subject to the terms and conditions specified in the partnership agreement. 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 CRLLC as the sole member of the general partner and not by the board of directors of the general partner. The members of the board of directors of the general partner are not elected by the common unitholders and are not subject to re-election on a regular basis. The officers of the general partner manage the day-to-day affairs of the business of the Nitrogen Fertilizer Partnership. CVR, the Nitrogen Fertilizer Partnership, their respective subsidiaries and the general partner are parties to a number of agreements to regulate certain business relations between them. Certain of these agreements were amended in connection with the Nitrogen Fertilizer Partnership IPO.
	CVR Refining, LP
	On January 23, 2013, the Refining Partnership completed its initial public offering (the “Refining Partnership IPO”). The Refining Partnership sold 24,000,000 common units to the public at a price of $25.00 per unit. Additionally, on January 30, 2013, the Refining Partnership sold an additional 3,600,000 common units to the public at a price of $25.00 per unit in connection with the underwriters’ exercise of their option to purchase additional common units. The common units, which are listed on the NYSE, began trading on January 17, 2013 under the symbol “CVRR.” In connection with the Refining Partnership IPO, the Company recorded a noncontrolling interest for the common units sold into the public market which represented an approximately 19% interest in the Refining Partnership at the time of the Refining Partnership IPO. Prior to the Refining Partnership IPO, CVR owned 100% of the Refining Partnership and net income earned during this period was fully attributable to the Company.
	On May 20, 2013, the Refining 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 IEP, also purchased an additional 2,000,000 common units at the public offering price in a privately negotiated transaction with a subsidiary of CVR Energy, which was completed on May 29, 2013. In connection with the Underwritten Offering, on June 10, 2013, the Refining 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.”
	Subsequent to the closing of the Transactions and prior to June 30, 2014, public security holders held approximately 29% of the total Refining Partnership common units (including units owned by IEP representing 4% of the total Refining Partnership common units), and CVR Refining Holdings, LLC (“CVR Refining Holdings”), a wholly-owned subsidiary of the Company, held approximately 71% of the total Refining Partnership common units.
	On June 30, 2014, the Refining Partnership completed a second underwritten offering (the “Second Underwritten Offering”) by selling 6,500,000 common units to the public at a price of $26.07 per unit. The Refining Partnership paid approximately $5.3 million in underwriting fees and approximately $0.5 million in offering costs. The Refining Partnership utilized net proceeds of approximately $164.1 million from the Second Underwritten Offering to redeem 6,500,000 common units from CVR Refining Holdings. Subsequent to the closing of the Second Underwritten Offering and as of June 30, 2014, public security holders held approximately 33% of the total Refining Partnership common units, and CVR Refining Holdings held approximately 67% of the total Refining Partnership common units.
	On July 24, 2014, the Refining Partnership sold an additional 589,100 common units to the public at a price of $26.07 per unit in connection with the underwriters' exercise of their option to purchase additional common units. The Refining Partnership utilized net proceeds of approximately $14.9 million from the underwriters' exercise of their option to purchase additional common units to redeem an equal amount of common units from CVR Refining Holdings. Additionally, on July 24, 2014, CVR Refining Holdings sold 385,900 common units to the public at a price of $26.07 per unit in connection with the underwriters' exercise of their remaining option to purchase additional common units. CVR Refining Holdings received net proceeds of $9.7 million.
	Subsequent to the closing of the underwriters' option of the Second Underwritten Offering and as of September 30, 2014, public security holders held approximately 34% of the total Refining Partnership common units (including units owned by IEP, representing 4% of the total Refining Partnership common units), and CVR Refining Holdings held approximately 66% of the total Refining Partnership common units. In addition, CVR Refining Holdings owns 100% of the Refining Partnership's general partner, CVR Refining GP, LLC, which holds a non-economic general partner interest. The noncontrolling interest reflected on the Condensed Consolidated Balance Sheets of CVR is impacted by the net income of, and distributions from, the Refining Partnership.
	The Refining Partnership’s general partner manages the Refining Partnership’s activities subject to the terms and conditions specified in the Refining Partnership’s partnership agreement. The Refining Partnership’s general partner is owned by CVR Refining Holdings. The operations of its general partner, in its capacity as general partner, are managed by its board of directors. Actions by its general partner that are made in its individual capacity are made by CVR Refining Holdings as the sole member of the Refining Partnership’s general partner and not by the board of directors of its general partner. The members of the board of directors of the Refining Partnership’s general partner are not elected by the Refining Partnership’s unitholders and are not subject to re-election on a regular basis. The officers of the general partner manage the day-to-day affairs of the business of the Refining Partnership.
	The Refining 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 Refining Partnership’s general partner following the end of such quarter. The partnership agreement does not require that the Refining Partnership make cash distributions on a quarterly basis or at all, and the board of directors of the general partner of the Refining Partnership can change the distribution policy at any time.
	The Refining Partnership entered into a services agreement on December 31, 2012, pursuant to which the Refining Partnership and its general partner obtain certain management and other services from CVR Energy. In addition, by virtue of the fact that the Refining Partnership is a controlled affiliate of CVR Energy, the Refining 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 Refining 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 the Nitrogen Fertilizer Partnership’s outstanding units.
	Basis of Presentation
	The accompanying condensed consolidated financial statements were prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) and in accordance with the rules and regulations of the Securities and Exchange Commission (the “SEC”). The condensed consolidated financial statements include the accounts of CVR and its majority-owned direct and indirect subsidiaries including the Nitrogen Fertilizer Partnership, the Refining Partnership and their respective subsidiaries. The ownership interests of noncontrolling investors in CVR’s subsidiaries are recorded as a noncontrolling interest included as a separate component of equity for all periods presented. All intercompany account balances and transactions have been eliminated in consolidation. Certain information and footnotes required for complete financial statements under GAAP have been condensed or omitted pursuant to SEC rules and regulations. These condensed consolidated financial statements should be read in conjunction with the December 31, 2013 audited consolidated financial statements and notes thereto included in CVR’s Annual Report on Form 10-K for the year ended December 31, 2013, which was filed with the SEC on February 26, 2014 (the “2013 Form 10-K”).
	The Nitrogen Fertilizer Partnership and the Refining Partnership are both consolidated based upon the fact that their general partners are owned by CVR and, therefore, CVR has the ability to control their activities. The general partners of the Nitrogen Fertilizer Partnership and the Refining Partnership manage their respective operations and activities subject to the terms and conditions specified in their respective partnership agreements. The operations of each general partner in its capacity as general partner are managed by its board of directors. The limited rights of the common unitholders of the Nitrogen Fertilizer Partnership and the Refining Partnership are demonstrated by the fact that the common unitholders have no right to elect either general partner or either general partner’s directors on an annual or other continuing basis. Each general partner can only be removed by a vote of the holders of at least 66 2/3% of the outstanding common units, including any common units owned by the general partner and its affiliates (including CVR) voting together as a single class. Actions by the general partner that are made in its individual capacity are made by the CVR subsidiary that serves as the sole member of the general partner and not by the board of directors of the general partner. The officers of the general partner manage the day-to-day affairs of the business. The majority of the officers of both general partners are also officers of CVR. Based upon the general partner’s role and rights as afforded by the partnership agreements and the limited rights afforded to the limited partners, the condensed consolidated financial statements of CVR will include the assets, liabilities, cash flows, revenues and expenses of the Nitrogen Fertilizer Partnership and the Refining Partnership.
	In the opinion of the Company’s management, the accompanying condensed consolidated financial statements reflect all adjustments (consisting only of normal recurring adjustments) that are necessary to fairly present the financial position of the Company as of September 30, 2014 and December 31, 2013, the results of operations and comprehensive income for the three and nine month periods ended September 30, 2014 and 2013, changes in equity for the nine month period ended September 30, 2014 and cash flows of the Company for the nine month periods ended September 30, 2014 and 2013.
	The preparation of the condensed consolidated financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results could differ from those estimates. Results of operations and cash flows for the interim periods presented are not necessarily indicative of the results that will be realized for the year ending December 31, 2014 or any other interim or annual period.

Recent_Accounting_Pronouncemen

Recent Accounting Pronouncements	9 Months Ended
	Sep. 30, 2014
Accounting Changes and Error Corrections [Abstract]	'
Recent Accounting Pronouncements	'
	(2) Recent Accounting Pronouncements
	In July 2013, the Financial Accounting Standards Board (“FASB”) issued Accounting Standard Update (“ASU”) No. 2013-11, “Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists” (“ASU 2013-11”). ASU 2013-11 requires the netting of unrecognized tax benefits against a deferred tax asset for a loss or other carryforward that would apply in settlement of the uncertain tax positions. The standard is effective for interim and annual periods beginning after December 15, 2013 and is to be applied prospectively with optional retrospective adoption permitted. The Company adopted this standard prospectively as of January 1, 2014. The adoption of this standard resulted in a reclassification on the Condensed Consolidated Balance Sheets.
	In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”), which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. ASU 2014-09 will replace most existing revenue recognition guidance in U.S. GAAP when it becomes effective. The standard is effective for interim and annual periods beginning after December 15, 2016 and permits the use of either the retrospective or cumulative effect transition method. Early adoption is not permitted. The Company has not yet selected a transition method and is currently evaluating the standard and the impact on its consolidated financial statements and footnote disclosures.

ShareBased_Compensation

Share-Based Compensation	9 Months Ended
	Sep. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Share-Based Compensation	'
	(3) Share-Based Compensation
	Long-Term Incentive Plan – CVR Energy
	CVR has a Long-Term Incentive Plan (“LTIP”), which permits the grant of options, stock appreciation rights, restricted shares, restricted stock units, dividend equivalent rights, share awards and performance awards (including performance share units, performance units and performance-based restricted stock). As of September 30, 2014, only restricted stock units and performance units under the LTIP remain outstanding. Individuals who are eligible to receive awards and grants under the LTIP include the Company’s employees, officers, consultants, advisors and directors. The LTIP authorized a share pool of 7,500,000 shares of the Company’s common stock, 1,000,000 of which may be issued in respect of incentive stock options. A summary of the principal features of the LTIP is provided below.
	Restricted Stock Units
	A summary of restricted stock units grant activity and changes during the nine months ended September 30, 2014 is presented below:
		Shares		Weighted-Average
				Grant-Date
				Fair Value
	Non-vested at January 1, 2014	359,552		$	28.09
	Granted	—		—
	Vested	(40,926	)	20.75
	Forfeited	(23,822	)	37.28
	Non-vested at September 30, 2014	294,804		$	28.37
	Through the LTIP, restricted shares have been granted to employees of the Company. The IEP Acquisition and related Transaction Agreement dated April 18, 2012 between CVR and IEP (“Transaction Agreement”) triggered a modification to outstanding awards under the LTIP. Pursuant to the Transaction Agreement, 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 of $30.00 per share or the fair market value as determined at the most recent valuation date of December 31 of each year. The awards, which generally vest over a three-year period, will be remeasured at each subsequent reporting date until they vest. As a result of the modification of the awards, the classification changed from equity-classified awards to liability-classified awards.
	In December 2012 and during 2013, restricted stock units and dividend equivalent rights were granted to certain employees of CVR. 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, the Company'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 Company’s common stock, plus (b) the cash value of all dividends declared and paid by the Company per share of the Company’s common stock 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.
	As of September 30, 2014, there was approximately $2.1 million of total unrecognized compensation cost related to non-vested restricted stock units and associated dividend equivalent rights to be recognized over a weighted-average period of approximately 0.5 years. Total compensation expense for the three months ended September 30, 2014 and 2013 was approximately $0.7 million and $3.0 million, respectively, related to the awards. Total compensation expense for the nine months ended September 30, 2014 and 2013 was approximately $2.2 million and $12.1 million, respectively, related to the awards.
	As of September 30, 2014 and December 31, 2013, the Company had a liability of $11.0 million and $8.9 million, respectively, for non-vested restricted stock unit awards and associated dividend equivalent rights, which is recorded in personnel accruals on the Condensed Consolidated Balance Sheets.
	Performance Unit Awards
	In December 2013, the Company 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, the Company 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 the related awards is being recognized over the substantive service period. Total compensation expense for the three and nine months ended September 30, 2014 related to the performance awards was approximately $0.1 million, and $3.8 million, respectively.
	On June 30, 2014, the first award of Mr. Lipinski's Performance Unit Award Agreements vested. The Company paid Mr. Lipinski approximately $3.9 million on July 15, 2014 as a result of the vesting. As of September 30, 2014, the Company had a liability of $3.8 million for non-vested performance unit awards, which is recorded in personnel accruals on the Condensed Consolidated Balance Sheets.
	Long-Term Incentive Plan – CVR Partners
	Common Units and Phantom Units
	In April 2011, the board of directors of the Nitrogen Fertilizer Partnership's general partner adopted the CVR Partners, LP Long-Term Incentive Plan (“CVR Partners LTIP”). Individuals who are eligible to receive awards under the CVR Partners LTIP include (1) employees of the Nitrogen Fertilizer Partnership and its subsidiaries, (2) employees of its general partner, (3) members of the board of directors of its general partner and (4) employees, consultants and directors of CVR Energy. The CVR Partners LTIP provides for the grant of options, unit appreciation rights, distribution equivalent rights, restricted units, phantom units and other unit-based awards. The maximum number of common units issuable under the CVR Partners LTIP is 5,000,000.
	Through the CVR Partners LTIP, phantom and common units have been awarded to employees of the Nitrogen Fertilizer Partnership and its general partner and to members of the board of directors of its general partner. In December 2013 and during 2014, awards of phantom units and distribution equivalent rights were granted to certain employees of the Nitrogen Fertilizer Partnership and its subsidiaries and its general partner. The awards generally 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 Nitrogen Fertilizer 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 Nitrogen Fertilizer 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 common units and phantom units (collectively “units”) activity and changes under the CVR Partners LTIP during the nine months ended September 30, 2014 is presented below:
		Units		Weighted‑Average
				Grant-Date
				Fair Value
	Non-vested at January 1, 2014	171,119		$	21.34
	Granted	5,093		18.86
	Vested	(5,085	)	21.39
	Forfeited	(77,004	)	23.49
	Non-vested at September 30, 2014	94,123		$	19.45
	As of September 30, 2014, there was approximately $0.6 million of total unrecognized compensation cost related to the awards under the CVR Partners LTIP to be recognized over a weighted-average period of 1.0 year. Total compensation expense recorded for the three months ended September 30, 2014 and 2013 related to the awards under the CVR Partners LTIP was approximately $(0.1) million and $0.4 million, respectively. Total compensation expense recorded for the nine months ended September 30, 2014 and 2013 related to the awards under the CVR Partners LTIP was approximately $0.4 million and $1.6 million, respectively.
	As of September 30, 2014 and December 31, 2013, the Nitrogen Fertilizer Partnership had a liability of $0.6 million and $0.2 million, respectively, for cash settled non-vested phantom unit awards and associated distribution equivalent rights, which is recorded in personnel accruals on the Condensed Consolidated Balance Sheets.
	Performance-Based Phantom Units
	In May 2014, the Nitrogen Fertilizer Partnership entered into a Phantom Unit Agreement with Mark A. Pytosh, its Chief Executive Officer and President, that included performance-based phantom units and distribution equivalent rights. Compensation cost for these awards is being recognized over the performance cycles of May 1, 2014 to December 31, 2014, January 1, 2015 to December 31, 2015 and January 1, 2016 to December 31, 2016, as the services are provided. Each phantom unit and distribution equivalent right represents the right to receive, upon vesting, a cash payment equal to (a) the average closing price of the Nitrogen Fertilizer Partnership's common units for the first ten business days of the last month of the performance cycle, multiplied by a performance factor that is based upon the level of the Nitrogen Fertilizer Partnership’s production of UAN, and (b) the per unit cash value of all distributions declared and paid by the Nitrogen Fertilizer Partnership from the grant date to and including the vesting date. Total compensation expense recorded for the three and nine months ended September 30, 2014 related to the award was not material. Assuming a target performance threshold, unrecognized compensation expense associated with the unvested phantom units at September 30, 2014 was approximately $0.3 million and is expected to be recognized over a weighted average period of 1.3 years.
	Long-Term Incentive Plan – CVR Refining
	In connection with the Refining Partnership IPO, on January 16, 2013, the board of directors of the general partner of the Refining 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 Refining 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 Refining 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. The maximum number of common units issuable under the CVR Refining LTIP is 11,070,000.
	In December 2013, awards of phantom units and distribution equivalent rights were granted to employees of the Refining Partnership and its subsidiaries, its general partner and certain employees of CRLLC and CVR Energy who perform services solely for the benefit of the Refining Partnership. The awards are expected to vest over three years with one-third of the awards 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 Refining 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 Refining 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 nine months ended September 30, 2014 is presented below:
		Units		Weighted-Average Grant-Date
				Fair Value
	Non-vested at January 1, 2014	187,177		$	21.55
	Granted	—		—
	Vested	—		—
	Forfeited	(4,176	)	21.55
	Non-vested at September 30, 2014	183,001		$	21.55
	As of September 30, 2014, there was approximately $2.6 million of total unrecognized compensation cost related to the awards under the CVR Refining LTIP to be recognized over a weighted-average period of 1.2 years. Total compensation expense recorded for the three and nine months ended September 30, 2014 related to the awards under the CVR Refining LTIP was approximately $0.6 million and $2.1 million, respectively.
	As of September 30, 2014, the Refining Partnership had a liability of $2.1 million for non-vested phantom unit awards and associated distribution equivalent rights, which is recorded in personnel accruals on the Condensed Consolidated Balance Sheets.
	Incentive Unit Awards
	In December 2013 and during 2014, the Company granted awards of incentive units and distribution equivalent rights to certain employees of CRLLC and CVR Energy. The awards generally 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 Refining 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 Refining 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 incentive unit activity and changes during the nine months ended September 30, 2014 is presented below:
		Incentive Units		Weighted-Average Grant-Date
				Fair Value
	Non-vested at January 1, 2014	251,431		$	22.62
	Granted	4,320		23.02
	Vested	—		—
	Forfeited	(56,841	)	22.62
	Non-vested at September 30, 2014	198,910		$	22.63
	As of September 30, 2014, there was approximately $2.9 million of total unrecognized compensation cost related to non-vested incentive units and associated distribution equivalent rights to be recognized over a weighted-average period of approximately 1.2 years. Total compensation expense for the three and nine months ended September 30, 2014 related to the awards was approximately $0.6 million and $2.2 million, respectively.
	As of September 30, 2014, the Company had a liability of $2.2 million for non-vested incentive units and associated distribution equivalent rights, which is recorded in personnel accruals on the Condensed Consolidated Balance Sheets.

Inventories

Inventories	9 Months Ended
	Sep. 30, 2014
Inventory Disclosure [Abstract]	'
Inventories	'
	(4) Inventories
	Inventories consist primarily of domestic and foreign crude oil, blending stock and components, work-in-progress, fertilizer products, and refined fuels and by-products. For all periods presented, inventories are valued at the lower of the first-in, first-out (“FIFO”) cost or market for fertilizer products, refined fuels and by-products. Refinery unfinished and finished products inventory values were determined using the ability-to-bear process, whereby raw materials and production costs are allocated to work-in-process and finished products based on their relative fair values. Other inventories, including other raw materials, spare parts, and supplies, are valued at the lower of moving-average cost, which approximates FIFO, or market. The cost of inventories includes inbound freight costs.
	Inventories consisted of the following:
		30-Sep-14		31-Dec-13
		(in millions)
	Finished goods	$	273.2	$	268.2
	Raw materials and precious metals	165		177
	In-process inventories	33.6		36.9
	Parts and supplies	45		44.5
		$	516.8	$	526.6

Property_Plant_and_Equipment

Property, Plant, and Equipment	9 Months Ended
	Sep. 30, 2014
Property, Plant and Equipment [Abstract]	'
Property, Plant, and Equipment	'
	(5) Property, Plant and Equipment
	A summary of costs for property, plant, and equipment is as follows:
		30-Sep-14		31-Dec-13
		(in millions)
	Land and improvements	$	37.2	$	36.1
	Buildings	44.9		42.6
	Machinery and equipment	2,410.30		2,312.50
	Automotive equipment	20.6		19.2
	Furniture and fixtures	20		18.3
	Leasehold improvements	3.4		2.5
	Aircraft	2.3		2.3
	Railcars	7.9		7.9
	Construction in progress	212		164.9
		2,758.60		2,606.30
	Accumulated depreciation	849		741.9
	Total property, plant and equipment, net	$	1,909.60	$	1,864.40
	Capitalized interest recognized as a reduction in interest expense for the three months ended September 30, 2014 and 2013 totaled approximately $3.0 million and $0.8 million, respectively. Capitalized interest recognized as a reduction in interest expense for the nine months ended September 30, 2014 and 2013 totaled approximately $8.2 million and $2.0 million, respectively. Land, buildings and equipment that are under a capital lease obligation had an original carrying value of approximately $24.8 million at both September 30, 2014 and December 31, 2013. Amortization of assets held under capital leases is included in depreciation expense.

Cost_Classifications

Cost Classifications	9 Months Ended
	Sep. 30, 2014
Costs and Expenses [Abstract]	'
Cost Classifications	'
	(6) Cost Classifications
	Cost of product sold (exclusive of depreciation and amortization) includes cost of crude oil, other feedstocks, blendstocks, purchased refined products, pet coke expense, renewable identification numbers (“RINs”) expense and freight and distribution expenses. Cost of product sold excludes depreciation and amortization of approximately $1.7 million and $1.3 million for the three months ended September 30, 2014 and 2013, respectively. For the nine months ended September 30, 2014 and 2013, cost of product sold excludes depreciation and amortization of approximately $4.7 million and $3.7 million, respectively.
	Direct operating expenses (exclusive of depreciation and amortization) includes direct costs of labor, maintenance and services, energy and utility costs, property taxes, environmental compliance costs, as well as chemicals and catalysts and other direct operating expenses. Direct operating expenses exclude depreciation and amortization of approximately $34.4 million and $34.0 million for the three months ended September 30, 2014 and 2013, respectively. For the nine months ended September 30, 2014 and 2013, direct operating expenses exclude depreciation and amortization of approximately $104.4 million and $99.8 million, respectively.
	Selling, general and administrative expenses (exclusive of depreciation and amortization) consist primarily of legal expenses, treasury, accounting, marketing, human resources and maintaining the corporate and administrative office in Texas and the administrative offices in Kansas and Oklahoma. Selling, general and administrative expenses exclude depreciation and amortization of approximately $1.7 million and $0.9 million for the three months ended September 30, 2014 and 2013, respectively. For the nine months ended September 30, 2014 and 2013, selling, general and administrative expense excludes depreciation and amortization of approximately $4.6 million and $1.9 million, respectively.

Income_Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2014
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	(7) Income Taxes
	On May 19, 2012, CVR became a member of the consolidated federal tax group of AEPC, a wholly-owned subsidiary of IEP, and subsequently entered into a tax allocation agreement with AEPC (the “Tax Allocation Agreement”). The Tax Allocation Agreement provides that AEPC will pay all consolidated federal income taxes on behalf of the consolidated tax group. CVR is required to make payments to AEPC in an amount equal to the tax liability, if any, that it would have paid if it were to file as a consolidated group separate and apart from AEPC. As of September 30, 2014, the Company has recorded a liability of $15.8 million for federal income taxes due to AEPC under the Tax Allocation Agreement. During the three months ended September 30, 2014 and 2013, the Company paid $22.0 million and $95.0 million, respectively, to AEPC under the Tax Allocation Agreement. During the nine months ended September 30, 2014 and 2013, the Company paid $120.1 million and $234.0 million, respectively, to AEPC under the Tax Allocation Agreement.
	The Company recognizes liabilities, interest and penalties for potential tax issues based on its estimate of whether, and the extent to which, additional taxes may be due as determined under ASC Topic 740—Income Taxes. As of September 30, 2014, the Company had unrecognized tax benefits of approximately $55.0 million, of which $25.1 million, if recognized, would impact the Company’s effective tax rate. Approximately $14.2 million of unrecognized tax benefits were netted with deferred tax asset carryforwards. The remaining unrecognized tax benefits are included in other long-term liabilities in the Condensed Consolidated Balance Sheets. There are no unrecognized tax benefits expected to be settled within the next twelve months in income taxes payable. The Company has accrued interest of $5.5 million related to uncertain tax positions. The Company’s accounting policy with respect to interest and penalties related to tax uncertainties is to classify these amounts as income taxes.
	CVR and its subsidiaries file U.S. federal and various state income and franchise tax returns. At September 30, 2014, the Company’s tax filings are generally open to examination in the United States for the tax years ended December 31, 2011 through December 31, 2013 and in various individual states for the tax years ended December 31, 2009 through December 31, 2013.
	The Company’s effective tax rate for the three and nine months ended September 30, 2014 was 16.5% and 23.9%, respectively, as compared to the Company’s combined federal and state expected statutory tax rate of 39.6%. The Company’s effective tax rate for the three and nine months ended September 30, 2014 is lower than the statutory rate primarily due to the reduction of income subject to tax associated with the noncontrolling ownership interests of CVR Refining’s and CVR Partners’ earnings, as well as benefits for domestic production activities and state income tax credits. The effective tax rate for the three months ended September 30, 2014 of 16.5% reflects the realization of additional domestic production activities deduction benefits of $1.7 million in the period. The Company’s effective tax rate for the three and nine months ended September 30, 2013 was 27.4% and 28.4% as compared to the Company’s combined federal and state expected statutory tax rate of 39.2%. The Company’s effective tax rate for the three and nine months ended September 30, 2013 was lower than the statutory rate primarily due to the reduction of income subject to tax associated with the noncontrolling ownership interests of CVR Refining's and CVR Partners’ earnings, as well as benefits for domestic production activities and state income tax credits.

LongTerm_Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2014
Debt Disclosure [Abstract]	'
Long-Term Debt	'
	(8) Long-Term Debt
	Long-term debt was as follows:
		30-Sep-14		31-Dec-13
		(in millions)
	6.5% Senior Notes due 2022	$	500	$	500
	CRNF credit facility	125		125
	Capital lease obligations	48.9		49.9
	Long-term debt	$	673.9	$	674.9
	2022 Senior Notes
	The Refining Partnership has $500.0 million aggregate principal amount of 6.5% Senior Notes due 2022 (the “2022 Notes”) outstanding, which were issued by CVR Refining, LLC (“Refining LLC”) and Coffeyville Finance Inc. (“Coffeyville Finance”) on October 23, 2012. The 2022 Notes were issued at par and 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 Refining Partnership can make distributions to holders of its common units provided, among other things, it has a minimum fixed charge coverage ratio and there is no default or event of default under the 2022 Notes. As of September 30, 2014, the Refining Partnership was in compliance with the covenants contained in the 2022 Notes.
	At September 30, 2014, the estimated fair value of the 2022 Notes was approximately $510.0 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.
	Amended and Restated Asset Based (ABL) Credit Facility
	The Refining Partnership has a senior secured asset based revolving credit facility (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 has an aggregate principal amount of up to $400.0 million with an incremental facility, which permits an increase in borrowings of up to $200.0 million subject to receipt of additional lender commitments and certain other conditions. The proceeds of the loans may be used for capital expenditures and working capital and general corporate purposes of the Refining Partnership and its subsidiaries. The Amended and Restated ABL Credit Facility provides for loans and letters of credit in an amount up to the aggregate availability under the facility, subject to meeting certain borrowing base conditions, with sub-limits of 10% of the total facility commitment for swingline loans and 90% of the total facility commitment for letters of credit. The Amended and Restated ABL Credit Facility is scheduled to mature on December 20, 2017.
	The Amended and Restated ABL Credit Facility also contains customary covenants for a financing of this type that limit the ability of the Refining Partnership and its respective subsidiaries to, among other things, incur liens, engage in a consolidation, merger, purchase or sale of assets, pay dividends, incur indebtedness, make advances, investments and loans, enter into affiliate transactions, issue equity interests, or create subsidiaries and unrestricted subsidiaries. The amended and restated facility also contains a fixed charge coverage ratio financial covenant, as defined therein. The Refining Partnership was in compliance with the covenants of the Amended and Restated ABL Credit Facility as of September 30, 2014.
	As of September 30, 2014, the Refining Partnership and its subsidiaries had availability under the Amended and Restated ABL Credit Facility of $372.7 million and had letters of credit outstanding of approximately $27.3 million. There were no borrowings outstanding under the Amended and Restated ABL Credit Facility as of September 30, 2014.
	Nitrogen Fertilizer Partnership Credit Facility
	Coffeyville Resources Nitrogen Fertilizer, LLC (“CRNF”), as borrower, and the Nitrogen Fertilizer Partnership, as guarantor, have a credit facility with a group of lenders including Goldman Sachs Lending Partners LLC, as administrative and collateral agent. The credit facility includes a term loan facility of $125.0 million and a revolving credit facility of $25.0 million with an uncommitted incremental facility of up to $50.0 million. No amounts were outstanding under the revolving credit facility at September 30, 2014. There is no scheduled amortization of the credit facility, which matures in April 2016. The carrying value of the Nitrogen Fertilizer Partnership’s debt approximates fair value.
	The credit facility requires the Nitrogen Fertilizer Partnership to maintain a minimum interest coverage ratio and a maximum leverage ratio and contains 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 restricted payments, investments and acquisitions, and the ability to enter into sale-leaseback transactions or affiliate transactions. The credit facility provides that the Nitrogen Fertilizer Partnership can make distributions to holders of its common units provided, among other things, it is in compliance with the leverage ratio and interest coverage ratio on a pro forma basis after giving effect to any distribution and there is no default or event of default under the credit facility. As of September 30, 2014, CRNF was in compliance with the covenants contained in the credit facility and there were no borrowings outstanding under the credit facility.
	Capital Lease Obligations
	As a result of the acquisition of the Wynnewood refinery, the Refining Partnership acquired certain lease assets and assumed related capital lease obligations related to Magellan Pipeline Terminals, L.P. and Excel Pipeline LLC. The underlying assets and related depreciation are 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 181 months remaining through September 2029. The financing agreement relates to the Magellan Pipeline terminals, bulk terminal and loading facility. The lease has 180 months remaining and will expire in September 2029.
	Loss on Extinguishment of Debt
	On January 23, 2013, $253.0 million of the proceeds from the Refining Partnership’s IPO were utilized to satisfy and discharge the indenture governing the previously outstanding Second Lien Senior Secured Notes due 2017 (the “Second Lien Notes”). The amounts were used to (i) repay the face amount of all $222.8 million aggregate principal amount of Second Lien Notes then outstanding, (ii) pay the redemption premium of approximately $20.6 million and (iii) settle accrued interest with respect thereto in an amount of approximately $9.5 million. The repurchase of the Second Lien Notes resulted in a loss on extinguishment of debt of approximately $26.1 million for the nine months ended September 30, 2013, which includes the write-off of previously deferred financing fees of $3.7 million and unamortized original issue discount of $1.8 million.

Earnings_Per_Share

Earnings Per Share	9 Months Ended
	Sep. 30, 2014
Earnings Per Share [Abstract]	'
Earnings Per Share	'
	(9) Earnings Per Share
	Basic and diluted earnings per share are computed by dividing net income attributable to CVR stockholders by the weighted-average number of shares of common stock outstanding. The components of the basic and diluted earnings per share calculation are as follows:
		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2014		2013		2014		2013
		(in millions, except per share data)
	Net income attributable to CVR Energy stockholders	$	7.9	$	44	$	218.3	$	392.4
	Weighted-average shares of common stock outstanding - Basic	86.8		86.8		86.8		86.8
	Weighted-average shares of common stock outstanding - Diluted	86.8		86.8		86.8		86.8
	Basic earnings per share	$	0.09	$	0.51	$	2.51	$	4.52
	Diluted earnings per share	$	0.09	$	0.51	$	2.51	$	4.52
	There were no dilutive awards outstanding during the three and nine months ended September 30, 2014 and 2013, as all unvested awards under the LTIP were liability-classified awards. See Note 3 ("Share-Based Compensation").

Commitments_and_Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	(10) Commitments and Contingencies
	Leases and Unconditional Purchase Obligations
	The minimum required payments for CVR’s lease agreements and unconditional purchase obligations are as follows:
		Operating		Unconditional
		Leases		Purchase
				Obligations(1)
		(in millions)
	Three Months Ending December 31, 2014	$	2.4	$	65.9
	Year Ending December 31,
	2015	8.1		120.9
	2016	6.7		114.1
	2017	4.4		112
	2018	3.2		112.1
	Thereafter	5.3		902.5
		$	30.1	$	1,427.50
	-1	This amount includes approximately $929.8 million payable ratably over seventeen years pursuant to petroleum transportation service agreements between Coffeyville Resources Refining & Marketing, LLC (“CRRM”) and each of TransCanada Keystone Pipeline Limited Partnership and TransCanada Keystone Pipeline, LP (together, “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.
	CVR leases various equipment, including railcars and real properties, under long-term operating leases which expire at various dates. For each of the three months ended September 30, 2014 and 2013, lease expense totaled approximately $2.4 million. For the nine months ended September 30, 2014 and 2013, lease expense totaled approximately $6.9 million and $7.0 million, respectively. The lease agreements have various remaining terms. Some agreements are renewable, at CVR’s option, for additional periods. It is expected, in the ordinary course of business, that leases will be renewed or replaced as they expire.
	Additionally, in the normal course of business, the Company has long-term commitments to purchase oxygen, nitrogen, electricity, storage capacity and pipeline transportation services. For the three months ended September 30, 2014 and 2013, total expense of approximately $31.2 million and $28.3 million, respectively, was incurred related to long-term commitments. For the nine months ended September 30, 2014 and 2013, total expense of approximately $100.0 million and $94.6 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 Refining Partnership's inventory position and mitigate crude oil pricing risk. The Vitol Agreement has an initial term commencing on August 31, 2012 and extending through December 31, 2014 (the “Initial Term”). Following the Initial Term, the Vitol Agreement will automatically renew for successive one-year terms (each such term, a “Renewal Term”) unless either party provides the other with notice of nonrenewal at least 180 days prior to the expiration of the Initial Term or any Renewal Term. The Vitol Agreement was extended for a one-year Renewal Term through December 31, 2015.
	Litigation
	From time to time, the Company is involved in various lawsuits arising in the normal course of business, including matters such as those described below under, “Environmental, Health, and Safety (“EHS”) Matters.” Liabilities related to such litigation are recognized when the related costs are probable and can be reasonably estimated. These provisions are reviewed at least quarterly and adjusted to reflect the impacts of negotiations, settlements, rulings, advice of legal counsel, and other information and events pertaining to a particular case. It is possible that management’s estimates of the outcomes will change due to uncertainties inherent in litigation and settlement negotiations. Except as described below, there were no new proceedings or material developments in proceedings that CVR previously reported in its 2013 Form 10-K or in its Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2014 (“2014 Q1 Form 10-Q”) and June 30, 2014 (“2014 Q2 Form 10-Q”), which were filed with the SEC on May 2, 2014 and August 1, 2014, respectively. In the opinion of management, the ultimate resolution of any other litigation matters is not expected to have a material adverse effect on the accompanying condensed consolidated financial statements. There can be no assurance that management’s beliefs or opinions with respect to liability for potential litigation matters will prove to be accurate.
	On June 21, 2012, Goldman, Sachs & Co. (“GS”) filed suit against CVR in state court in New York, alleging that CVR failed to pay GS fees allegedly due to GS by CVR pursuant to an engagement letter dated March 21, 2012, which according to the allegations set forth in the complaint, provided that GS was engaged by CVR to assist CVR and the CVR board of directors in connection with a tender offer for CVR's stock, made by Carl C. Icahn and certain of his affiliates. On September 8, 2014, the court (in its decision granting GS’s motion for summary judgment against CVR) directed the court clerk to enter judgment against CVR in the amount of approximately $22.6 million, which has been fully accrued as of September 30, 2014. CVR filed its notice of appeal on October 3, 2014 and intends to vigorously pursue the appeal.
	On August 10, 2012, Deutsche Bank (“DB”) filed suit against CVR in state court in New York, alleging that CVR failed to pay DB fees allegedly due to DB by CVR pursuant to an engagement letter dated March 23, 2012, which according to the allegations set forth in the complaint, provided that DB was engaged by CVR to assist CVR and the CVR board of directors in connection with a tender offer for CVR's stock made by Carl C. Icahn and certain of his affiliates.  On September 8, 2014, the court (in its decision granting DB’s motion for summary judgment against CVR) directed the court clerk to enter judgment against CVR in the amount of approximately $22.7 million, which has been fully accrued as of September 30, 2014. CVR filed its notice of appeal on October 3, 2014 and intends to vigorously pursue the appeal. On October 27, 2014, CVR paid the judgment to DB, subject to a right of refund if it is successful on appeal.
	Environmental, Health, and Safety (“EHS”) Matters
	The petroleum and nitrogen fertilizer businesses 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, CRNF, Coffeyville Resources Crude Transportation, LLC (“CRCT”), Wynnewood Refining Company, LLC (“WRC”) and Coffeyville Resources Terminal, LLC (“CRT”) own and/or operate manufacturing and ancillary operations at various locations directly related to petroleum refining and distribution and nitrogen fertilizer manufacturing. Therefore, CRRM, CRNF, 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 can 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 Oil Pollution Act 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, CRNF, 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, and the storage, handling, use and transportation of petroleum and nitrogen products, 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.
	As previously reported, the petroleum and nitrogen fertilizer businesses are party to, or otherwise subject to administrative orders and consent decrees with federal, state and local environmental authorities, as applicable, addressing corrective actions under RCRA, the Clean Air Act and the Clean Water Act. The petroleum business also is subject to (i) the Mobile Source Air Toxic II (“MSAT II”) rule which requires reductions of benzene in gasoline; (ii) 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; and (iii) “Tier 3” gasoline sulfur standards. Except as otherwise described below, there have been no new developments or material changes to the environmental accruals or expected capital expenditures related to compliance with the foregoing environmental matters from those provided in CVR's 2013 Form 10-K, 2014 Q1 Form 10-Q or 2014 Q2 Form 10-Q. CRRM, CRNF, 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 or referenced herein or other EHS matters which may develop in the future will not have a material adverse effect on the Company's business, financial condition, or results of operations.
	At September 30, 2014, the Company’s Condensed Consolidated Balance Sheet included total environmental accruals of $1.2 million, compared with $1.5 million at December 31, 2013. 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.
	Environmental expenditures are capitalized when such expenditures are expected to result in future economic benefits. For the three months ended September 30, 2014 and 2013, capital expenditures were approximately $23.1 million and $35.5 million, respectively. For the nine months ended September 30, 2014 and 2013, capital expenditures were approximately $83.3 million and $73.5 million, respectively. These expenditures were incurred for environmental compliance and efficiency of the operations.
	The cost of RINs for the three months ended September 30, 2014 and 2013 was approximately $18.5 million and $57.4 million, respectively. The cost of RINs for the nine months ended September 30, 2014 and 2013 was approximately $82.3 million and $155.0 million, respectively. As of September 30, 2014 and December 31, 2013, the petroleum business’ biofuel blending obligation was approximately $36.3 million and $17.4 million, respectively, which was recorded in other current liabilities on the Condensed Consolidated Balance Sheets.
	Affiliate Pension Obligations
	Mr. Icahn, through certain affiliates, owns approximately 82% of the Company’s capital stock. Applicable pension and tax laws make each member of a “controlled group” of entities, generally defined as entities in which there is at least an 80% common ownership interest, jointly and severally liable for certain pension plan obligations of any member of the controlled group. These pension obligations include ongoing contributions to fund the plan, as well as liability for any unfunded liabilities that may exist at the time the plan is terminated. In addition, the failure to pay these pension obligations when due may result in the creation of liens in favor of the pension plan or the Pension Benefit Guaranty Corporation (“PBGC”) against the assets of each member of the controlled group.
	As a result of the more than 80% ownership interest in CVR Energy by Mr. Icahn's affiliates, the Company is subject to the pension liabilities of all entities in which Mr. Icahn has a direct or indirect ownership interest of at least 80%. Two such entities, ACF Industries LLC (“ACF”) and Federal-Mogul, are the sponsors of several pension plans. All the minimum funding requirements of the Code and the Employee Retirement Income Security Act of 1974, as amended by the Pension Protection Act of 2006, for these plans have been met as of September 30, 2014 and December 31, 2013. If the ACF and Federal-Mogul plans were voluntarily terminated, they would be underfunded by approximately $442.6 million and $591.8 million as of September 30, 2014 and December 31, 2013, respectively. These results are based on the most recent information provided by Mr. Icahn's affiliates based on information from the plans' actuaries. These liabilities could increase or decrease, depending on a number of factors, including future changes in benefits, investment returns, and the assumptions used to calculate the liability. As members of the controlled group, CVR Energy would be liable for any failure of ACF and Federal-Mogul to make ongoing pension contributions or to pay the unfunded liabilities upon a termination of their respective pension plans. In addition, other entities now or in the future within the controlled group that includes CVR Energy may have pension plan obligations that are, or may become, underfunded, and the Company would be liable for any failure of such entities to make ongoing pension contributions or to pay the unfunded liabilities upon a termination of such plans. The current underfunded status of the ACF and Federal-Mogul pension plans requires such entities to notify the PBGC of certain “reportable events,” such as if CVR Energy were to cease to be a member of the controlled group, or if CVR Energy makes certain extraordinary dividends or stock redemptions. The obligation to report could cause the Company to seek to delay or reconsider the occurrence of such reportable events. Based on the contingent nature of potential exposure related to these affiliate pension obligations, no liability has been recorded in the condensed consolidated financial statements.

Coffeyville_Refinery_Incident

Coffeyville Refinery Incident	9 Months Ended
	Sep. 30, 2014
Insurance [Abstract]	'
Insurance Disclosure [Text Block]	'
	(11) Coffeyville Refinery Incident
	On July 29, 2014, the Coffeyville refinery experienced a fire at its isomerization unit. Four employees were injured in the fire, including one employee who was fatally injured. The fire was extinguished, and the refinery was subsequently shut down due to a failure of its plant-wide Distributed Control System, which was directly caused by the fire. The Coffeyville refinery returned to operations in mid-August, with all units except the isomerization unit in operation by August 23, 2014. This interruption adversely impacted production of refined products for the petroleum business in the third quarter of 2014. Total gross repair and other costs recorded related to the incident for the three and nine months ended September 30, 2014 were approximately $5.5 million.
	The Refining Partnership maintains property damage insurance policies which have an associated deductible of $5.0 million for the Coffeyville refinery. The Refining Partnership anticipates amounts in excess of the $5.0 million deductible will be recoverable under the property insurance policies. As of September 30, 2014, the Refining Partnership recorded an insurance receivable related to the incident of approximately $0.5 million, which is included in prepaid expenses and other current assets in the Condensed Consolidated Balance Sheet. The recording of the receivable resulted in a reduction of direct operating expenses (exclusive of depreciation and amortization). The Refining Partnership also maintains workers' compensation insurance with a $0.5 million per accident deductible.
	During the outage at the Coffeyville refinery as discussed above, the Refining Partnership accelerated certain planned turnaround activities scheduled for 2015 and incurred approximately $5.5 million in turnaround expenses for the three and nine months ended September 30, 2014.

Fair_Value_Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	(12) Fair Value Measurements
	In accordance with ASC Topic 820 — Fair Value Measurements and Disclosures (“ASC 820”), the Company utilizes the market approach to measure fair value for its financial assets and liabilities. The market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets, liabilities or a group of assets or liabilities, such as a business.
	ASC 820 utilizes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three broad levels. The following is a brief description of those three levels:
	•	Level 1 — Quoted prices in active markets for identical assets and liabilities
	•	Level 2 — Other significant observable inputs (including quoted prices in active markets for similar assets or liabilities)
	•	Level 3 — Significant unobservable inputs (including the Company’s own assumptions in determining the fair value)
	The following table sets forth the assets and liabilities measured at fair value on a recurring basis, by input level, as of September 30, 2014 and December 31, 2013:
		30-Sep-14
		Level 1		Level 2			Level 3		Total
		(in millions)
	Location and Description
	Cash equivalents	$	69	$	—		$	—	$	69
	Other current assets (investments)	89.4		4.4			—		93.8
	Other current assets (other derivative agreements)	—		53.2			—		53.2
	Other long-term assets (other derivative agreements)	—		8.6			—		8.6
	Total Assets	$	158.4	$	66.2		$	—	$	224.6
	Other current liabilities (interest rate swaps)	—		(0.9		)	—		(0.9		)
	Other current liabilities (biofuel blending obligations)	—		(9.9		)	—		(9.9		)
	Other long-term liabilities (interest rate swaps)	—		(0.3		)	—		(0.3		)
	Total Liabilities	$	—	$	(11.1	)	$	—	$	(11.1	)
		31-Dec-13
		Level 1		Level 2			Level 3		Total
		(in millions)
	Location and Description
	Cash equivalents	$	81	$	—		$	—	$	81
	Other current assets (other derivative agreements)	—		0.9			—		0.9
	Other long-term assets (other derivative agreements)	—		0.1			—		0.1
	Total Assets	$	81	$	1		$	—	$	82
	Other current liabilities (other derivative agreements)	—		(15.3		)	—		(15.3		)
	Other current liabilities (interest rate swaps)	—		(0.9		)	—		(0.9		)
	Other current liabilities (biofuel blending obligation)	—		(16.2		)	—		(16.2		)
	Other long-term liabilities (other derivative agreements)	—		(1.8		)	—		(1.8		)
	Other long-term liabilities (interest rate swaps)	—		(1.0		)	—		(1.0		)
	Total Liabilities	$	—	$	(35.2	)	$	—	$	(35.2	)
	As of September 30, 2014 and December 31, 2013, the only financial assets and liabilities that are measured at fair value on a recurring basis are the Company’s cash equivalents, investments, derivative instruments and the uncommitted biofuel blending obligation. Additionally, the fair value of the Company’s debt issuances is disclosed in Note 8 ("Long-Term Debt"). The Refining Partnership’s commodity derivative contracts, certain investments 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. The Nitrogen Fertilizer Partnership has interest rate swaps that are measured at fair value on a recurring basis using Level 2 inputs. The fair value of these interest rate swap instruments are based on discounted cash flow models that incorporate the cash flows of the derivatives, as well as the current LIBOR rate and a forward LIBOR curve, along with other observable market inputs. The Company's investments in marketable securities are classified as available-for-sale, and as a result, are reported at fair market value using quoted market prices. As of September 30, 2014, the aggregate cost basis for the Company's available-for-sale securities is approximately $76.2 million. The Company recognized an unrealized gain of $13.2 million on the available-for-sale securities for the three and nine months ended September 30, 2014, which is recorded in accumulated other comprehensive income (loss) (“AOCI”). The Company had no transfers of assets or liabilities between any of the above levels during the nine months ended September 30, 2014.

Derivative_Financial_Instrumen

Derivative Financial Instruments	9 Months Ended
	Sep. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Financial Instruments	'
	(13) Derivative Financial Instruments
	Gain (loss) on derivatives, net and current period settlements on derivative contracts were as follows:
		Three Months Ended					Nine Months Ended
		September 30,					September 30,
		2014		2013			2014		2013
		(in millions)
	Current period settlements on derivative contracts	$	38.2	$	33.9		$	93.2	$	(3.9	)
	Gain on derivatives, net	25.7		72.5			171.1		173
	The Refining Partnership and Nitrogen Fertilizer Partnership are 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, the Refining Partnership from time to time enters into various commodity derivative transactions.
	The Refining Partnership has adopted accounting standards which impose extensive record-keeping requirements in order to designate a derivative financial instrument as a hedge. The Refining Partnership holds derivative instruments, such as exchange-traded crude oil futures and certain over-the-counter forward swap agreements, which it believes provide an economic hedge on future transactions, but such instruments are not designated as hedges for GAAP purposes. Gains or losses related to the change in fair value and periodic settlements of these derivative instruments are classified as gain (loss) on derivatives, net in the Condensed Consolidated 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.
	The Refining Partnership maintains a margin account to facilitate other commodity derivative activities. A portion of this account may include funds available for withdrawal. These funds are included in cash and cash equivalents within the Condensed Consolidated Balance Sheets. The maintenance margin balance is included within other current assets within the Condensed Consolidated Balance Sheets. Dependent upon the position of the open commodity derivatives, the amounts are accounted for as other current assets or other current liabilities within the Condensed Consolidated Balance Sheets. From time to time, the Refining Partnership may be required to deposit additional funds into this margin account. There were no open commodity positions as of September 30, 2014. For the three months ended September 30, 2014 and 2013, the Refining Partnership recognized net gains of $43,000 and $0.1 million, respectively. For the nine months ended September 30, 2014 and 2013, the Refining Partnership recognized net losses of $0.3 million and $2.3 million, respectively. These recognized net gains and losses are recorded in gain (loss) on derivatives, net in the Condensed Consolidated Statements of Operations.
	Commodity Swaps
	The Refining Partnership enters into commodity swap contracts in order to fix the margin on a portion of future production. The physical volumes are not exchanged and these contracts are net settled with cash. The contract fair value of the commodity swaps is reflected on the Condensed Consolidated Balance Sheets with changes in fair value currently recognized in the Condensed Consolidated Statements of Operations. Quoted prices for similar assets or liabilities in active markets (Level 2) are considered to determine the fair values for the purpose of marking to market the hedging instruments at each period end. At September 30, 2014 and December 31, 2013, the Refining Partnership had open commodity hedging instruments consisting of 9.8 million barrels and 23.3 million barrels of crack spreads, respectively, primarily to fix the margin on a portion of its future gasoline and distillate production. The fair value of the outstanding contracts at September 30, 2014 was a net unrealized gain of $61.8 million, of which $53.2 million was included in current assets and $8.6 million was included in non-current assets. For the three months ended September 30, 2014 and 2013, the Refining Partnership recognized net gains of $25.7 million and $72.4 million, respectively. For the nine months ended September 30, 2014 and 2013, the Refining Partnership recognized net gains of $171.4 million and $175.3 million, respectively. These recognized net gains are recorded in gain (loss) on derivatives, net in the Condensed Consolidated Statements of Operations.
	Nitrogen Fertilizer Partnership Interest Rate Swaps
	CRNF is subject to two floating-to-fixed interest rate swap agreements for the purpose of hedging the interest rate risk associated with a portion of the nitrogen fertilizer business’ $125.0 million floating rate term debt which matures in April 2016, as further discussed in Note 8 ("Long-Term Debt"). The aggregate notional amount covered under these agreements, which commenced on August 12, 2011 and expires on February 12, 2016, totals $62.5 million (split evenly between the two agreement dates). Under the terms of the interest rate swap agreement entered into on June 30, 2011, CRNF will receive a floating rate based on three month LIBOR and pay a fixed rate of 1.94%. Under the terms of the interest rate swap agreement entered into on July 1, 2011, CRNF will receive a floating rate based on three month LIBOR and pay a fixed rate of 1.975%. Both swap agreements are settled every 90 days. The effect of these swap agreements is to lock in a fixed rate of interest of approximately 1.96% plus the applicable margin paid to lenders over three month LIBOR as calculated under the CRNF credit facility. At September 30, 2014, the effective rate was approximately 4.56%. The agreements were designated as cash flow hedges at inception and accordingly, the effective portion of the gain or loss on the swap is reported as a component of AOCI and will be reclassified into interest expense when the interest rate swap transaction affects earnings. The ineffective portion of the gain or loss will be recognized immediately in current interest expense on the Condensed Consolidated Statements of Operations.
	The realized loss on the interest rate swaps re-classed from AOCI into interest expense and other financing costs on the Condensed Consolidated Statements of Operations was $0.3 million for each of the three months ended September 30, 2014 and 2013, respectively. For the three months ended September 30, 2014 and 2013, the Nitrogen Fertilizer Partnership recognized decreases in fair value of the interest rate swap agreements of $0 and $0.3 million, respectively, which were unrealized in AOCI. The realized loss on the interest rate swaps re-classed from AOCI into interest expense and other financing costs on the Condensed Consolidated Statements of Operations was $0.8 million for each of the nine months ended September 30, 2014 and 2013, respectively. For each of the nine months ended September 30, 2014 and 2013, the Nitrogen Fertilizer Partnership recognized a decrease in fair value of the interest rate swap agreements of $0.1 million, which were unrealized in AOCI.
	Counterparty Credit Risk
	The Refining Partnership’s exchange-traded crude oil futures and certain over-the-counter forward swap agreements are potentially exposed to concentrations of credit risk as a result of economic conditions and periods of uncertainty and illiquidity in the credit and capital markets. The Refining Partnership manages credit risk on its exchange-traded crude oil futures by completing trades with an exchange clearinghouse, which subjects the trades to mandatory margin requirements until the contract settles. The Refining Partnership also monitors the creditworthiness of its commodity swap counterparties and assesses the risk of nonperformance on a quarterly basis. Counterparty credit risk identified as a result of this assessment is recognized as a valuation adjustment to the fair value of the commodity swaps recorded in the Condensed Consolidated Balance Sheets. As of September 30, 2014, the counterparty credit risk adjustment was not material to the condensed consolidated financial statements. Additionally, the Refining Partnership does not require any collateral to support commodity swaps into which it enters; however, it does have master netting arrangements that allow for the setoff of amounts receivable from and payable to the same party, which mitigates the risk associated with nonperformance.
	Offsetting Assets and Liabilities
	The commodity swaps and other commodity derivatives agreements discussed above include multiple derivative positions with a number of counterparties for which the Refining Partnership 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 the Refining Partnership. As a result of the right to setoff, the Refining Partnership’s recognized assets and liabilities associated with the outstanding derivative positions have been presented net in the Condensed Consolidated Balance Sheets. The interest rate swap agreements held by the Nitrogen Fertilizer Partnership also provide for the right to setoff. However, as the interest rate swaps are in a liability position, there are no amounts offset in the Condensed Consolidated Balance Sheets as of September 30, 2014 and December 31, 2013. In accordance with guidance issued by the FASB related to “Disclosures about Offsetting Assets and Liabilities,” the tables below outline the gross amounts of the recognized assets and liabilities and the gross amounts offset in the Condensed Consolidated Balance Sheets for the various types of open derivative positions at the Refining Partnership.
	The offsetting assets and liabilities for the Refining Partnership’s derivatives as of September 30, 2014 are recorded as current assets and non-current assets in prepaid expenses and other current assets and other long-term assets, respectively, in the Condensed Consolidated Balance Sheets as follows:
		As of September 30, 2014
	Description	Gross		Gross			Net		Cash			Net
		Current Assets		Amounts			Current Assets		Collateral			Amount
				Offset			Presented		Not Offset
		(in millions)
	Commodity Swaps	$	53.2	$	—		$	53.2	$	—		$	53.2
	Total	$	53.2	$	—		$	53.2	$	—		$	53.2
		As of September 30, 2014
	Description	Gross		Gross			Net		Cash			Net
		Non-Current Assets		Amounts			Non-Current Assets		Collateral			Amount
				Offset			Presented		Not Offset
		(in millions)
	Commodity Swaps	$	8.6	$	—		$	8.6	$	—		$	8.6
	Total	$	8.6	$	—		$	8.6	$	—		$	8.6
	The offsetting assets and liabilities for the Refining Partnership’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, other current liabilities and other long-term liabilities, respectively, in the Condensed Consolidated Balance Sheets as follows:
		As of December 31, 2013
	Description	Gross		Gross			Net		Cash			Net
		Current Assets		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		Gross			Net		Cash			Net
		Non-Current Assets		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		Gross			Net		Cash			Net
		Current Liabilities		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		Gross			Net		Cash			Net
		Non-Current Liabilities		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

Related_Party_Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	(14) Related Party Transactions
	Icahn Enterprises
	In May 2012, IEP announced that it had acquired control of CVR pursuant to a tender offer to purchase all of the issued and outstanding shares of the Company's common stock. As of September 30, 2014, IEP owned approximately 82% of all common shares outstanding.
	The following is a summary of the quarterly and special dividends paid to the Company's stockholders, including IEP, during 2014:
		31-Dec-13		31-Mar-14		30-Jun-14		17-Jul-14		Total Dividends
										Paid in 2014
		(in millions, except per share data)
		Quarterly		Quarterly		Quarterly		Special
	Amount paid to IEP	$	53.4	$	53.4	$	53.4	$	142.4	$	302.6
	Amounts paid to public stockholders	11.7		11.7		11.7		31.3		66.4
	Total amount paid	$	65.1	$	65.1	$	65.1	$	173.7	$	369
	Per common share	$	0.75	$	0.75	$	0.75	$	2	$	4.25
	Shares outstanding	86.8		86.8		86.8		86.8
	American Railcar Industries, Inc.
	In the second quarter of 2014, the Nitrogen Fertilizer Partnership entered into a contract to purchase approximately 50 new UAN railcars from American Railcar Industries, Inc. (“ARI”), an affiliate of IEP, for approximately $6.7 million. The Nitrogen Fertilizer Partnership has received 25 new UAN railcars in the third quarter of 2014 and expects the delivery of the remaining new railcars from ARI will be completed by December 2014. During each of the three and nine months ended September 30, 2014, the Nitrogen Fertilizer Partnership paid approximately $3.3 million for the delivered railcars.
	ARI performed railcar maintenance for the Nitrogen Fertilizer Partnership starting in 2014. The expenses associated with this maintenance were approximately $50,000 for each of the three and nine months ended September 30, 2014.
	Tax Allocation Agreement
	On May 19, 2012, CVR became a member of the consolidated federal tax group of AEPC, a wholly-owned subsidiary of IEP, and subsequently entered into a tax allocation agreement with AEPC (the “Tax Allocation Agreement”). The Tax Allocation Agreement provides that AEPC will pay all consolidated federal income taxes on behalf of the consolidated tax group. CVR is required to make payments to AEPC in an amount equal to the tax liability, if any, that it would have paid if it were to file as a consolidated group separate and apart from AEPC.
	As of September 30, 2014, the Company has recorded approximately $15.8 million for federal income taxes due to AEPC under the Tax Allocation Agreement. During the three months ended September 30, 2014 and 2013, the Company paid $22.0 million and $95.0 million, respectively, to AEPC under the Tax Allocation Agreement. During the nine months ended September 30, 2014 and 2013, the Company paid $120.1 million and $234.0 million, respectively, to AEPC under the Tax Allocation Agreement.
	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 and agreed to pay a portion of Insight Portfolio Group’s operating expenses in 2013 and subsequent periods. The Company paid Insight Portfolio Group approximately $0.2 million and $0 during the three months ended September 30, 2014 and 2013, respectively. The Company paid Insight Portfolio Group approximately $0.3 million and $0.1 million during the nine months ended September 30, 2014 and 2013, respectively. The Company may purchase a variety of goods and services as a member of the buying group at prices and terms that management believes would be more favorable than those which would be achieved on a stand-alone basis.

Business_Segments

Business Segments	9 Months Ended
	Sep. 30, 2014
Segment Reporting [Abstract]	'
Business Segments	'
	(15) Business Segments
	The Company measures segment profit as operating income for petroleum and nitrogen fertilizer, CVR’s two reporting segments, based on the definitions provided in ASC Topic 280 – Segment Reporting. All operations of the segments are located within the United States.
	Petroleum
	Principal products of the petroleum segment are refined fuels, propane, and petroleum refining by-products, including pet coke. The petroleum segment’s Coffeyville refinery sells pet coke to the Nitrogen Fertilizer Partnership for use in the manufacture of nitrogen fertilizer at the adjacent nitrogen fertilizer plant. For the petroleum segment, a per-ton transfer price is used to record intercompany sales on the part of the petroleum segment and corresponding intercompany cost of product sold (exclusive of depreciation and amortization) for the nitrogen fertilizer segment. The per ton transfer price paid, pursuant to the pet coke supply agreement that became effective October 24, 2007, is based on the lesser of a pet coke price derived from the price received by the nitrogen fertilizer segment for UAN (subject to a UAN based price ceiling and floor) and a pet coke price index for pet coke. The intercompany transactions are eliminated in the other segment. Intercompany sales included in petroleum net sales were approximately $1.9 million and $1.6 million for the three months ended September 30, 2014 and 2013, respectively. Intercompany net sales included in petroleum net sales were approximately $6.5 million and $7.0 million for the nine months ended September 30, 2014 and 2013, respectively.
	The petroleum segment recorded intercompany cost of product sold (exclusive of depreciation and amortization) for the hydrogen purchases described below under “Nitrogen Fertilizer” of approximately $0.1 million and $0.8 million for the three months ended September 30, 2014 and 2013, respectively. For the nine months ended September 30, 2014 and 2013, the petroleum segment recorded intercompany cost of product sold (exclusive of depreciation and amortization) of approximately $6.9 million and $4.7 million, respectively. The petroleum segment recorded intercompany revenue for hydrogen sales of approximately $0 and $0.3 million for the three months ended September 30, 2014 and 2013, respectively. For the nine months ended September 30, 2014 and 2013, the petroleum segment recorded intercompany revenue for hydrogen sales of approximately $0 and $0.6 million, respectively.
	Nitrogen Fertilizer
	The principal product of the nitrogen fertilizer segment is nitrogen fertilizer. Intercompany cost of product sold (exclusive of depreciation and amortization) for the pet coke transfer described above was approximately $2.1 million and $2.2 million for the three months ended September 30, 2014 and 2013, respectively. Intercompany cost of product sold (exclusive of depreciation and amortization) for the pet coke transfer described above was approximately $6.6 million and $7.4 million for the nine months ended September 30, 2014 and 2013, respectively.
	Pursuant to the feedstock agreement, the Company’s segments have the right to transfer hydrogen between the Coffeyville refinery and nitrogen fertilizer plant. Sales of hydrogen to the petroleum segment have been reflected as net sales for the nitrogen fertilizer segment. Receipts of hydrogen from the petroleum segment have been reflected in cost of product sold (exclusive of depreciation and amortization) for the nitrogen fertilizer segment. For the three months ended September 30, 2014 and 2013, the net sales generated from intercompany hydrogen sales were $0.1 million and $0.8 million, respectively. For the nine months ended September 30, 2014 and 2013, the net sales generated from intercompany hydrogen sales were $6.9 million and $4.7 million, respectively. For the three months ended September 30, 2014 and 2013, the nitrogen fertilizer segment also recognized approximately $0 and $0.3 million, respectively, of cost of product sold related to the transfer of excess hydrogen. For the nine months ended September 30, 2014 and 2013, the nitrogen fertilizer segment also recognized approximately $0 and $0.6 million, respectively, of cost of product sold related to the transfer of excess hydrogen. As these intercompany sales and cost of product sold are eliminated, there is no financial statement impact on the condensed consolidated financial statements.
	Other Segment
	The other segment reflects intercompany eliminations, corporate cash and cash equivalents, income tax activities and other corporate activities that are not allocated to the operating segments.
	The following table summarizes certain operating results and capital expenditures information by segment:
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
		(in millions)
	Net sales
	Petroleum	$	2,215.20		$	1,910.50		$	7,056.90		$	6,322.60
	Nitrogen Fertilizer	66.7			69.2			224.3			239.4
	Intersegment elimination	(2.0		)	(2.6		)	(13.5		)	(12.2		)
	Total	$	2,279.90		$	1,977.10		$	7,267.70		$	6,549.80
	Cost of product sold (exclusive of depreciation and amortization)
	Petroleum	$	2,053.70		$	1,734.70		$	6,289.60		$	5,317.00
	Nitrogen Fertilizer	15.4			13			56.6			39.2
	Intersegment elimination	(2.4		)	(3.3		)	(13.6		)	(12.7		)
	Total	$	2,066.70		$	1,744.40		$	6,332.60		$	5,343.50
	Direct operating expenses (exclusive of depreciation and amortization)
	Petroleum	$	110.6		$	104.7		$	303		$	274.5
	Nitrogen Fertilizer	26.1			23.7			77.2			70.7
	Other	0.1			—			0.1			—
	Total	$	136.8		$	128.4		$	380.3		$	345.2
	Depreciation and amortization
	Petroleum	$	29.7		$	28.8		$	89.9		$	85.2
	Nitrogen Fertilizer	6.8			6.6			20.3			18.5
	Other	1.3			0.8			3.5			1.7
	Total	$	37.8		$	36.2		$	113.7		$	105.4
	Operating income
	Petroleum	$	3.9		$	23.4		$	320.4		$	588.1
	Nitrogen Fertilizer	14.4			21.3			56.3			95.2
	Other	(11.5		)	(4.3		)	(21.8		)	(12.6		)
	Total	$	6.8		$	40.4		$	354.9		$	670.7
	Capital expenditures
	Petroleum	$	48.9		$	60.7		$	154.2		$	140.8
	Nitrogen fertilizer	6			4			13.5			35.8
	Other	1.6			4.3			3.7			7
	Total	$	56.5		$	69		$	171.4		$	183.6
		As of September 30, 2014			As of December 31, 2013
		(in millions)
	Total assets
	Petroleum	$	2,691.70		$	2,533.30
	Nitrogen Fertilizer	562.1			593.5
	Other	498.6			539
	Total	$	3,752.40		$	3,665.80
	Goodwill
	Petroleum	$	—		$	—
	Nitrogen Fertilizer	41			41
	Other	—			—
	Total	$	41		$	41

Subsequent_Events

Subsequent Events	9 Months Ended
	Sep. 30, 2014
Subsequent Events [Abstract]	'
Subsequent Events	'
	(16) Subsequent Events
	Dividend
	On October 29, 2014, the board of directors of the Company declared a cash dividend for the third quarter of 2014 to the Company’s stockholders of $0.75 per share, or $65.1 million in aggregate. The dividend will be paid on November 17, 2014 to stockholders of record at the close of business on November 10, 2014. IEP will receive $53.4 million in respect of its 82% ownership interest in the Company’s shares.
	Nitrogen Fertilizer Partnership Distribution
	On October 29, 2014, the board of directors of the Nitrogen Fertilizer Partnership’s general partner declared a cash distribution for the third quarter of 2014 to the Nitrogen Fertilizer Partnership’s unitholders of $0.27 per common unit, or $19.7 million in aggregate. The cash distribution will be paid on November 17, 2014 to unitholders of record at the close of business on November 10, 2014. The Company will receive $10.5 million in respect of its Nitrogen Fertilizer Partnership common units.
	Refining Partnership Distribution
	On October 29, 2014, the board of directors of the Refining Partnership’s general partner declared a cash distribution for the third quarter of 2014 to the Refining Partnership’s unitholders of $0.54 per common unit, or $79.7 million in aggregate. The cash distribution will be paid on November 17, 2014 to unitholders of record at the close of business on November 10, 2014. The Company will receive $52.5 million in respect of its Refining Partnership common units.

ShareBased_Compensation_Tables

Share-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2014
Share-Based Compensation	'
Summary of restricted stock units activity	'
	A summary of restricted stock units grant activity and changes during the nine months ended September 30, 2014 is presented below:
		Shares		Weighted-Average
				Grant-Date
				Fair Value
	Non-vested at January 1, 2014	359,552		$	28.09
	Granted	—		—
	Vested	(40,926	)	20.75
	Forfeited	(23,822	)	37.28
	Non-vested at September 30, 2014	294,804		$	28.37
Summary of common units and phantom units activity	'
	A summary of common units and phantom units (collectively “units”) activity and changes under the CVR Partners LTIP during the nine months ended September 30, 2014 is presented below:
		Units		Weighted‑Average
				Grant-Date
				Fair Value
	Non-vested at January 1, 2014	171,119		$	21.34
	Granted	5,093		18.86
	Vested	(5,085	)	21.39
	Forfeited	(77,004	)	23.49
	Non-vested at September 30, 2014	94,123		$	19.45
CVR Refining Long Term Incentive Plan	'
Share-Based Compensation	'
Summary of phantom unit activity	'
	A summary of phantom unit activity and changes under the CVR Refining LTIP during the nine months ended September 30, 2014 is presented below:
		Units		Weighted-Average Grant-Date
				Fair Value
	Non-vested at January 1, 2014	187,177		$	21.55
	Granted	—		—
	Vested	—		—
	Forfeited	(4,176	)	21.55
	Non-vested at September 30, 2014	183,001		$	21.55
Incentive Unit Award	'
Share-Based Compensation	'
Summary of phantom unit activity	'
	A summary of incentive unit activity and changes during the nine months ended September 30, 2014 is presented below:
		Incentive Units		Weighted-Average Grant-Date
				Fair Value
	Non-vested at January 1, 2014	251,431		$	22.62
	Granted	4,320		23.02
	Vested	—		—
	Forfeited	(56,841	)	22.62
	Non-vested at September 30, 2014	198,910		$	22.63

Inventories_Tables

Inventories (Tables)	9 Months Ended
	Sep. 30, 2014
Inventory Disclosure [Abstract]	'
Schedule of inventories	'
	Inventories consisted of the following:
		30-Sep-14		31-Dec-13
		(in millions)
	Finished goods	$	273.2	$	268.2
	Raw materials and precious metals	165		177
	In-process inventories	33.6		36.9
	Parts and supplies	45		44.5
		$	516.8	$	526.6

Property_Plant_and_Equipment_T

Property, Plant, and Equipment (Tables)	9 Months Ended
	Sep. 30, 2014
Property, Plant and Equipment [Abstract]	'
Summary of costs for property, plant, and equipment	'
	A summary of costs for property, plant, and equipment is as follows:
		30-Sep-14		31-Dec-13
		(in millions)
	Land and improvements	$	37.2	$	36.1
	Buildings	44.9		42.6
	Machinery and equipment	2,410.30		2,312.50
	Automotive equipment	20.6		19.2
	Furniture and fixtures	20		18.3
	Leasehold improvements	3.4		2.5
	Aircraft	2.3		2.3
	Railcars	7.9		7.9
	Construction in progress	212		164.9
		2,758.60		2,606.30
	Accumulated depreciation	849		741.9
	Total property, plant and equipment, net	$	1,909.60	$	1,864.40

LongTerm_Debt_Tables

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2014
Debt Disclosure [Abstract]	'
Schedule of long-term debt	'
	Long-term debt was as follows:
		30-Sep-14		31-Dec-13
		(in millions)
	6.5% Senior Notes due 2022	$	500	$	500
	CRNF credit facility	125		125
	Capital lease obligations	48.9		49.9
	Long-term debt	$	673.9	$	674.9

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	9 Months Ended
	Sep. 30, 2014
Earnings Per Share [Abstract]	'
Schedule of computations of the basic and diluted earnings per share calculation	'
	The components of the basic and diluted earnings per share calculation are as follows:
		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2014		2013		2014		2013
		(in millions, except per share data)
	Net income attributable to CVR Energy stockholders	$	7.9	$	44	$	218.3	$	392.4
	Weighted-average shares of common stock outstanding - Basic	86.8		86.8		86.8		86.8
	Weighted-average shares of common stock outstanding - Diluted	86.8		86.8		86.8		86.8
	Basic earnings per share	$	0.09	$	0.51	$	2.51	$	4.52
	Diluted earnings per share	$	0.09	$	0.51	$	2.51	$	4.52

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	9 Months Ended
	Sep. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of minimum required payments for CVR's lease agreements and unconditional purchase obligations	'
	The minimum required payments for CVR’s lease agreements and unconditional purchase obligations are as follows:
		Operating		Unconditional
		Leases		Purchase
				Obligations(1)
		(in millions)
	Three Months Ending December 31, 2014	$	2.4	$	65.9
	Year Ending December 31,
	2015	8.1		120.9
	2016	6.7		114.1
	2017	4.4		112
	2018	3.2		112.1
	Thereafter	5.3		902.5
		$	30.1	$	1,427.50
	-1	This amount includes approximately $929.8 million payable ratably over seventeen years pursuant to petroleum transportation service agreements between Coffeyville Resources Refining & Marketing, LLC (“CRRM”) and each of TransCanada Keystone Pipeline Limited Partnership and TransCanada Keystone Pipeline, LP (together, “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.

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2014
Fair Value Disclosures [Abstract]	'
Schedule of assets and liabilities measured at fair value on a recurring basis	'
	The following table sets forth the assets and liabilities measured at fair value on a recurring basis, by input level, as of September 30, 2014 and December 31, 2013:
		30-Sep-14
		Level 1		Level 2			Level 3		Total
		(in millions)
	Location and Description
	Cash equivalents	$	69	$	—		$	—	$	69
	Other current assets (investments)	89.4		4.4			—		93.8
	Other current assets (other derivative agreements)	—		53.2			—		53.2
	Other long-term assets (other derivative agreements)	—		8.6			—		8.6
	Total Assets	$	158.4	$	66.2		$	—	$	224.6
	Other current liabilities (interest rate swaps)	—		(0.9		)	—		(0.9		)
	Other current liabilities (biofuel blending obligations)	—		(9.9		)	—		(9.9		)
	Other long-term liabilities (interest rate swaps)	—		(0.3		)	—		(0.3		)
	Total Liabilities	$	—	$	(11.1	)	$	—	$	(11.1	)
		31-Dec-13
		Level 1		Level 2			Level 3		Total
		(in millions)
	Location and Description
	Cash equivalents	$	81	$	—		$	—	$	81
	Other current assets (other derivative agreements)	—		0.9			—		0.9
	Other long-term assets (other derivative agreements)	—		0.1			—		0.1
	Total Assets	$	81	$	1		$	—	$	82
	Other current liabilities (other derivative agreements)	—		(15.3		)	—		(15.3		)
	Other current liabilities (interest rate swaps)	—		(0.9		)	—		(0.9		)
	Other current liabilities (biofuel blending obligation)	—		(16.2		)	—		(16.2		)
	Other long-term liabilities (other derivative agreements)	—		(1.8		)	—		(1.8		)
	Other long-term liabilities (interest rate swaps)	—		(1.0		)	—		(1.0		)
	Total Liabilities	$	—	$	(35.2	)	$	—	$	(35.2	)

Derivative_Financial_Instrumen1

Derivative Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Components of gain (loss) on derivatives, net	'
	Gain (loss) on derivatives, net and current period settlements on derivative contracts were as follows:
		Three Months Ended					Nine Months Ended
		September 30,					September 30,
		2014		2013			2014		2013
		(in millions)
	Current period settlements on derivative contracts	$	38.2	$	33.9		$	93.2	$	(3.9	)
	Gain on derivatives, net	25.7		72.5			171.1		173
Schedule of offsetting assets recorded as current assets and non-current assets in prepaid expenses and other current assets and other long-term assets in the Condensed Consolidated Balance Sheets	'
	The offsetting assets and liabilities for the Refining Partnership’s derivatives as of September 30, 2014 are recorded as current assets and non-current assets in prepaid expenses and other current assets and other long-term assets, respectively, in the Condensed Consolidated Balance Sheets as follows:
		As of September 30, 2014
	Description	Gross		Gross			Net		Cash			Net
		Current Assets		Amounts			Current Assets		Collateral			Amount
				Offset			Presented		Not Offset
		(in millions)
	Commodity Swaps	$	53.2	$	—		$	53.2	$	—		$	53.2
	Total	$	53.2	$	—		$	53.2	$	—		$	53.2
		As of September 30, 2014
	Description	Gross		Gross			Net		Cash			Net
		Non-Current Assets		Amounts			Non-Current Assets		Collateral			Amount
				Offset			Presented		Not Offset
		(in millions)
	Commodity Swaps	$	8.6	$	—		$	8.6	$	—		$	8.6
	Total	$	8.6	$	—		$	8.6	$	—		$	8.6
	The offsetting assets and liabilities for the Refining Partnership’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, other current liabilities and other long-term liabilities, respectively, in the Condensed Consolidated Balance Sheets as follows:
		As of December 31, 2013
	Description	Gross		Gross			Net		Cash			Net
		Current Assets		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		Gross			Net		Cash			Net
		Non-Current Assets		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
Schedule of offsetting liabilities recorded as current liabilities and non-current liabilities in other current liabilities and other long-term liabilities in the Condensed Consolidated Balance Sheet	'
		As of December 31, 2013
	Description	Gross		Gross			Net		Cash			Net
		Current Liabilities		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		Gross			Net		Cash			Net
		Non-Current Liabilities		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

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2014
Related Party Transactions [Abstract]	'
Dividends Declared	'
	The following is a summary of the quarterly and special dividends paid to the Company's stockholders, including IEP, during 2014:
		31-Dec-13		31-Mar-14		30-Jun-14		17-Jul-14		Total Dividends
										Paid in 2014
		(in millions, except per share data)
		Quarterly		Quarterly		Quarterly		Special
	Amount paid to IEP	$	53.4	$	53.4	$	53.4	$	142.4	$	302.6
	Amounts paid to public stockholders	11.7		11.7		11.7		31.3		66.4
	Total amount paid	$	65.1	$	65.1	$	65.1	$	173.7	$	369
	Per common share	$	0.75	$	0.75	$	0.75	$	2	$	4.25
	Shares outstanding	86.8		86.8		86.8		86.8

Business_Segments_Tables

Business Segments (Tables)	9 Months Ended
	Sep. 30, 2014
Segment Reporting [Abstract]	'
Schedule of segment information	'
	The following table summarizes certain operating results and capital expenditures information by segment:
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
		(in millions)
	Net sales
	Petroleum	$	2,215.20		$	1,910.50		$	7,056.90		$	6,322.60
	Nitrogen Fertilizer	66.7			69.2			224.3			239.4
	Intersegment elimination	(2.0		)	(2.6		)	(13.5		)	(12.2		)
	Total	$	2,279.90		$	1,977.10		$	7,267.70		$	6,549.80
	Cost of product sold (exclusive of depreciation and amortization)
	Petroleum	$	2,053.70		$	1,734.70		$	6,289.60		$	5,317.00
	Nitrogen Fertilizer	15.4			13			56.6			39.2
	Intersegment elimination	(2.4		)	(3.3		)	(13.6		)	(12.7		)
	Total	$	2,066.70		$	1,744.40		$	6,332.60		$	5,343.50
	Direct operating expenses (exclusive of depreciation and amortization)
	Petroleum	$	110.6		$	104.7		$	303		$	274.5
	Nitrogen Fertilizer	26.1			23.7			77.2			70.7
	Other	0.1			—			0.1			—
	Total	$	136.8		$	128.4		$	380.3		$	345.2
	Depreciation and amortization
	Petroleum	$	29.7		$	28.8		$	89.9		$	85.2
	Nitrogen Fertilizer	6.8			6.6			20.3			18.5
	Other	1.3			0.8			3.5			1.7
	Total	$	37.8		$	36.2		$	113.7		$	105.4
	Operating income
	Petroleum	$	3.9		$	23.4		$	320.4		$	588.1
	Nitrogen Fertilizer	14.4			21.3			56.3			95.2
	Other	(11.5		)	(4.3		)	(21.8		)	(12.6		)
	Total	$	6.8		$	40.4		$	354.9		$	670.7
	Capital expenditures
	Petroleum	$	48.9		$	60.7		$	154.2		$	140.8
	Nitrogen fertilizer	6			4			13.5			35.8
	Other	1.6			4.3			3.7			7
	Total	$	56.5		$	69		$	171.4		$	183.6
		As of September 30, 2014			As of December 31, 2013
		(in millions)
	Total assets
	Petroleum	$	2,691.70		$	2,533.30
	Nitrogen Fertilizer	562.1			593.5
	Other	498.6			539
	Total	$	3,752.40		$	3,665.80
	Goodwill
	Petroleum	$	—		$	—
	Nitrogen Fertilizer	41			41
	Other	—			—
	Total	$	41		$	41

Organization_and_History_of_th1

Organization and History of the Company and Basis of Presentation (Details) (USD $)

9 Months Ended

16 Months Ended

25 Months Ended

9 Months Ended

16 Months Ended

0 Months Ended

2 Months Ended

4 Months Ended

13 Months Ended

2 Months Ended

9 Months Ended

2 Months Ended

13 Months Ended

0 Months Ended

2 Months Ended

13 Months Ended

0 Months Ended

In Millions, except Share data, unless otherwise specified

Sep. 30, 2014

Sep. 30, 2014

27-May-13

Sep. 30, 2014

Sep. 30, 2014

Jul. 24, 2014

Jun. 30, 2014

Jan. 22, 2013

Sep. 30, 2014

19-May-13

Jun. 29, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Jun. 29, 2014

Jul. 24, 2014

Jun. 30, 2014

Sep. 30, 2014

Jun. 29, 2014

28-May-13

Jan. 30, 2013

Jan. 23, 2013

Jun. 10, 2013

20-May-13

29-May-13

Jun. 30, 2014

Jun. 30, 2014

segment

CVR Partners, LP

CVR Partners, LP

CVR Partners, LP

CVR GP, LLC

CVR Refining, LP

CVR Refining, LP

CVR Refining, LP

CVR Refining, LP

CVR Refining, LP

CVR Refining, LP

CVR Refining GP, LLC

IEP Energy LLC

IEP Energy LLC

IEP Energy LLC

CVR Refining Holdings LLC

CVR Refining Holdings LLC

CVR Refining Holdings LLC

CVR Refining Holdings LLC

Secondary Offering

Initial Public Offering

Initial Public Offering

Underwritten Offering

Underwritten Offering

Private placement

Second Underwritten Offering

Second Underwritten Offering

Minimum

CVR Refining, LP

CVR Refining, LP

CVR Refining, LP

CVR Refining, LP

CVR Refining, LP

CVR Partners, LP

CVR Refining, LP

CVR Refining, LP

CVR Refining, LP

CVR Refining, LP

AEPC

CVR Refining, LP

CVR Refining, LP

Organization, Consolidation, and Presentation of Financial Statements [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of reportable segments

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership percentage held by controlling stockholder

'

'

'

'

'

'

'

'

'

'

'

'

82.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership percentage held by public

'

47.00%

30.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of partnership units sold in offering (in shares)

'

'

'

'

'

589,100

'

'

'

'

'

'

'

'

'

385,900

'

'

'

12,000,000

3,600,000

24,000,000

1,209,236

12,000,000

'

'

6,500,000

Offering price per unit (in dollars per share)

'

'

'

'

'

$26.07

'

'

'

'

'

'

'

'

'

$26.07

'

'

'

$25.15

$25

$25

$30.75

$30.75

'

'

$26.07

Percentage of limited partner interest held by the public

'

'

'

'

'

'

33.00%

'

34.00%

19.00%

29.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest held by public

'

'

'

'

'

'

'

'

'

'

'

'

'

4.00%

4.00%

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of CVR's indirect ownership in CVR Partners, LP

'

53.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of common units owned by limited partner

'

'

'

50.00%

100.00%

'

'

100.00%

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,000,000

'

'

Percentage of common units owned by the CVR Refining Holdings

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

67.00%

66.00%

71.00%

'

'

'

'

'

'

'

'

Payments for Underwriting Expense

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$5.30

'

Payments of Stock Issuance Costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.5

Proceeds from Issuance of Common Limited Partners Units

'

'

'

'

'

$14.90

'

'

'

'

'

'

'

'

'

$9.70

'

'

'

'

'

'

'

'

'

'

$164.10

Partners' Capital Account, Units, Redeemed

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,500,000

Percentage of holders of the outstanding common units required to vote for removal of the general partner

66.67%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

ShareBased_Compensation_Detail

Share-Based Compensation (Details) (USD $)

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Jul. 15, 2014

Sep. 30, 2014

In Millions, except Share data, unless otherwise specified

Long-Term Incentive Plan

Stock Options

Restricted stock units

Restricted stock units

Restricted stock units

Restricted stock units

Restricted stock units

Restricted stock units

Restricted stock units

Restricted stock units

Performance Unit Awards

Performance Unit Awards

Performance Unit Awards

Performance Unit Awards

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

Long-Term Incentive Plan

Long-Term Incentive Plan

Long-Term Incentive Plan

Long-Term Incentive Plan

Personnel Accruals

Personnel Accruals

Certain executive officers

Personnel Accruals

Share-Based Compensation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock authorized for issuance (in shares)

'

'

7,500,000

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Offer price per share received as cash settlement on restricted stock awards vested in 2012

'

'

'

'

'

$30

'

$30

'

'

'

'

'

'

'

'

Vesting period

'

'

'

'

'

'

'

'3 years

'

'

'

'1 year

'

'

'

'

Vesting rights percentage

'

'

'

'

33.33%

'

'

'

'

'

'

'

'

'

'

'

Number of shares, right to receive cash payment equal to fair value of which is received per unit on vesting of award

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

Unrecognized compensation cost

'

'

'

'

'

$2.10

'

$2.10

'

'

'

'

'

'

'

'

Weighted-average period for amortization of unrecognized compensation cost

'

'

'

'

'

'

'

'0 years 6 months

'

'

'

'

'

'

'

'

Compensation expense

'

'

'

'

'

0.7

3

2.2

12.1

'

'

'

0.1

3.8

'

'

Share-based Compensation Paid Performance Unit Awards

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.9

'

Liability for unvested restricted share awards

$49.50

$45.80

'

'

'

'

'

'

'

$11

$8.90

'

'

'

'

$3.80

ShareBased_Compensation_Detail1

Share-Based Compensation (Details 2) (Long-Term Incentive Plan, Restricted stock units, USD $)	9 Months Ended
	Sep. 30, 2014
Long-Term Incentive Plan | Restricted stock units	'
Non-vested shares activity	'
Non-vested at the beginning of the period (in shares)	359,552
Granted (in shares)	0
Vested (in shares)	-40,926
Forfeited (in shares)	-23,822
Non-vested at the end of the period (in shares)	294,804
Weighted-Average Grant-Date Fair Value	'
Non-vested at the beginning of the period (in dollars per share)	$28.09
Granted (in dollars per share)	$0
Vested (in dollars per share)	$20.75
Forfeited (in dollars per share)	$37.28
Non-vested at the end of the period (in dollars per share)	$28.37

ShareBased_Compensation_Detail2

Share-Based Compensation (Details 3) (USD $)	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2014	Apr. 30, 2011	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2014
In Millions, except Share data, unless otherwise specified			CVR Partners, LP	CVR Partners, LP	CVR Partners, LP	CVR Partners, LP	CVR Partners, LP	CVR Partners, LP	CVR Partners, LP	CVR Partners, LP	CVR Partners, LP
			CVR Partners Long Term Incentive Plan	CVR Partners Long Term Incentive Plan	CVR Partners Long Term Incentive Plan	CVR Partners Long Term Incentive Plan	CVR Partners Long Term Incentive Plan	CVR Partners Long Term Incentive Plan	CVR Partners Long Term Incentive Plan	CVR Partners Long Term Incentive Plan	CVR Partners Long Term Incentive Plan
			trading_day		Phantom Unit and Common Unit	Phantom Unit and Common Unit	Phantom Unit and Common Unit	Phantom Unit and Common Unit	Phantom Unit and Common Unit	Phantom Unit and Common Unit	Performance-Based Phantom Unit
									Personnel Accruals	Personnel Accruals	trading_day
Share-Based Compensation	'	'	'	'	'	'	'	'	'	'	'
Common stock authorized for issuance (in shares)	'	'	'	5,000,000	'	'	'	'	'	'	'
Vesting period	'	'	'3 years	'	'	'	'	'	'	'	'
Vesting rights percentage	'	'	33.33%	'	'	'	'	'	'	'	'
Number of share right to receive cash payment on vesting equal to fair market value is received per award	'	'	1	'	'	'	'	'	'	'	'
Period for determination of cash payment value	'	'	10	'	'	'	'	'	'	'	10
Unrecognized compensation cost	'	'	'	'	$0.60	'	$0.60	'	'	'	$0.30
Weighted-average period for amortization of unrecognized compensation cost	'	'	'	'	'	'	'1 year	'	'	'	'1 year 3 months
Compensation expense	'	'	'	'	-0.1	0.4	0.4	1.6	'	'	'
Liability for unvested restricted share awards	$49.50	$45.80	'	'	'	'	'	'	$0.60	$0.20	'

ShareBased_Compensation_Detail3

Share-Based Compensation (Details 4) (CVR Partners, LP, CVR Partners Long Term Incentive Plan, Phantom Unit and Common Unit, USD $)	9 Months Ended
	Sep. 30, 2014
CVR Partners, LP | CVR Partners Long Term Incentive Plan | Phantom Unit and Common Unit	'
Non-vested shares activity	'
Non-vested at the beginning of the period (in shares)	171,119
Granted (in shares)	5,093
Vested (in shares)	-5,085
Forfeited (in shares)	-77,004
Non-vested at the end of the period (in shares)	94,123
Weighted-Average Grant-Date Fair Value	'
Non-vested at the beginning of the period (in dollars per share)	$21.34
Granted (in dollars per share)	$18.86
Vested (in dollars per share)	$21.39
Forfeited (in dollars per share)	$23.49
Non-vested at the end of the period (in dollars per share)	$19.45

ShareBased_Compensation_Detail4

Share-Based Compensation (Details 5) (USD $)	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014
In Millions, except Share data, unless otherwise specified			CVR Refining, LP	CVR Refining, LP	CVR Refining, LP	CVR Refining, LP
			CVR Refining Long Term Incentive Plan	CVR Refining Long Term Incentive Plan	CVR Refining Long Term Incentive Plan	CVR Refining Long Term Incentive Plan
			trading_day	Phantom Unit Plan	Phantom Unit Plan	Phantom Unit Plan
						Personnel Accruals
Share-Based Compensation	'	'	'	'	'	'
Common stock authorized for issuance (in shares)	'	'	11,070,000	'	'	'
Vesting period	'	'	'3 years	'	'	'
Vesting rights percentage	'	'	33.33%	'	'	'
Number of share right to receive cash payment on vesting equal to fair market value is received per award	'	'	1	'	'	'
Period for determination of cash payment value	'	'	10	'	'	'
Unrecognized compensation cost	'	'	'	$2.60	$2.60	'
Weighted-average period for amortization of unrecognized compensation cost	'	'	'	'	'1 year 2 months 12 days	'
Compensation expense	'	'	'	0.6	2.1	'
Liability for unvested restricted share awards	$49.50	$45.80	'	'	'	$2.10

ShareBased_Compensation_Detail5

Share-Based Compensation (Details 6) (CVR Refining, LP, CVR Refining Long Term Incentive Plan, Phantom Unit Plan, USD $)	9 Months Ended
	Sep. 30, 2014
CVR Refining, LP | CVR Refining Long Term Incentive Plan | Phantom Unit Plan	'
Non-vested shares activity	'
Non-vested at the beginning of the period (in shares)	187,177
Granted (in shares)	0
Vested (in shares)	0
Forfeited (in shares)	-4,176
Non-vested at the end of the period (in shares)	183,001
Weighted-Average Grant-Date Fair Value	'
Non-vested at the beginning of the period (in dollars per share)	$21.55
Granted (in dollars per share)	$0
Vested (in dollars per share)	$0
Forfeited (in dollars per share)	$21.55
Non-vested at the end of the period (in dollars per share)	$21.55

ShareBased_Compensation_Detail6

Share-Based Compensation (Details 7) (USD $)	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014
In Millions, except Share data, unless otherwise specified			Incentive Unit Award	Incentive Unit Award	Incentive Unit Award
				trading_day	Personnel Accruals
Share-Based Compensation	'	'	'	'	'
Vesting period	'	'	'	'3 years	'
Vesting rights percentage	'	'	'	33.33%	'
Number of share right to receive cash payment on vesting equal to fair market value is received per award	'	'	'	1	'
Period for determination of cash payment value	'	'	'	10	'
Unrecognized compensation cost	'	'	$2.90	$2.90	'
Weighted-average period for amortization of unrecognized compensation cost	'	'	'	'1 year 2 months 12 days	'
Compensation expense	'	'	0.6	2.2	'
Liability for unvested restricted share awards	$49.50	$45.80	'	'	$2.20

ShareBased_Compensation_Detail7

Share-Based Compensation (Details 8) (Incentive Unit Award, USD $)	9 Months Ended
	Sep. 30, 2014
Incentive Unit Award	'
Non-vested shares activity	'
Non-vested at the beginning of the period (in shares)	251,431
Granted (in shares)	4,320
Vested (in shares)	0
Forfeited (in shares)	-56,841
Non-vested at the end of the period (in shares)	198,910
Weighted-Average Grant-Date Fair Value	'
Non-vested at the beginning of the period (in dollars per share)	$22.62
Granted (in dollars per share)	$23.02
Vested (in dollars per share)	$0
Forfeited (in dollars per share)	$22.62
Non-vested at the end of the period (in dollars per share)	$22.63

Inventories_Details

Inventories (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Inventory Disclosure [Abstract]	'	'
Finished goods	$273.20	$268.20
Raw materials and precious metals	165	177
In-process inventories	33.6	36.9
Parts and supplies	45	44.5
Inventories	$516.80	$526.60

Property_Plant_and_Equipment_D

Property, Plant, and Equipment (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Property, Plant, and Equipment	'	'
Gross property, plant and equipment	$2,758.60	$2,606.30
Accumulated depreciation	849	741.9
Total property, plant and equipment, net	1,909.60	1,864.40
Land and improvements	'	'
Property, Plant, and Equipment	'	'
Gross property, plant and equipment	37.2	36.1
Buildings	'	'
Property, Plant, and Equipment	'	'
Gross property, plant and equipment	44.9	42.6
Machinery and equipment	'	'
Property, Plant, and Equipment	'	'
Gross property, plant and equipment	2,410.30	2,312.50
Automotive equipment	'	'
Property, Plant, and Equipment	'	'
Gross property, plant and equipment	20.6	19.2
Furniture and fixtures	'	'
Property, Plant, and Equipment	'	'
Gross property, plant and equipment	20	18.3
Leasehold improvements	'	'
Property, Plant, and Equipment	'	'
Gross property, plant and equipment	3.4	2.5
Aircraft	'	'
Property, Plant, and Equipment	'	'
Gross property, plant and equipment	2.3	2.3
Railcars	'	'
Property, Plant, and Equipment	'	'
Gross property, plant and equipment	7.9	7.9
Construction in progress	'	'
Property, Plant, and Equipment	'	'
Gross property, plant and equipment	$212	$164.90

Property_Plant_and_Equipment_D1

Property, Plant, and Equipment (Details 2) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'	'	'	'	'
Capitalized interest	$3	$0.80	$8.20	$2	'
Original carrying value of assets under capital lease obligations	$24.80	'	$24.80	'	$24.80

Cost_Classifications_Details

Cost Classifications (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Cost Classifications	'	'	'	'
Depreciation and amortization not included in cost of product sold	$1.70	$1.30	$4.70	$3.70
Depreciation and amortization not included in direct operating expenses	34.4	34	104.4	99.8
Depreciation and amortization not included in selling, general and administrative expenses	$1.70	$0.90	$4.60	$1.90

Income_Taxes_Details

Income Taxes (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Income Taxes	'	'	'	'	'
Due to parent	$15.80	'	$15.80	'	$0.10
Unrecognized tax benefits	55	'	55	'	'
Unrecognized tax benefits which, if recognized, would impact the company's effective tax rate	25.1	'	25.1	'	'
Unrecognized tax benefits related to state tax credits	14.2	'	14.2	'	'
Accrued interest	5.5	'	5.5	'	'
Effective tax rate (as a percent)	16.50%	27.40%	23.90%	28.40%	'
Effective tax rate at a combined federal and state income tax rate (as a percent)	'	'	39.60%	39.20%	'
AEPC	'	'	'	'	'
Income Taxes	'	'	'	'	'
Due to parent	15.8	'	15.8	'	'
Federal taxes paid to AEPC under the Tax Allocation Agreement	$22	95	$120.10	234	'

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Debt Instrument [Line Items]	'	'
Long-term debt	$673.90	$674.90
Capital lease obligations	48.9	49.9
6.5% Senior Notes due 2022	'	'
Debt Instrument [Line Items]	'	'
Long-term debt	500	500
Stated interest rate (as a percent)	6.50%	6.50%
CRNF credit facility	'	'
Debt Instrument [Line Items]	'	'
Long-term debt	$125	$125

LongTerm_Debt_Details_2

Long-Term Debt (Details 2) (USD $)

3 Months Ended

9 Months Ended

0 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Jan. 23, 2013

Sep. 30, 2013

Jan. 23, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Oct. 23, 2012

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Senior Secured Notes 10.875% Due 2017

Senior Secured Notes 10.875% Due 2017

Senior Secured Notes 10.875% Due 2017

6.5% Senior Notes due 2022

6.5% Senior Notes due 2022

6.5% Senior Notes due 2022

6.5% Senior Notes due 2022

Amended and Restated ABL Credit Facility

Amended and Restated ABL Credit Facility

CRNF credit facility

Revolving credit facility

CVR Refining, LP

CVR Refining, LP

CVR Refining, LP

Level 2

Refining LLC

Credit parties

CVR Refining, LP

CRNF

CRNF

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate principal amount

'

'

'

'

'

'

'

'

'

'

$500,000,000

'

'

'

'

Stated interest rate (as a percent)

'

'

'

'

'

'

'

6.50%

6.50%

'

6.50%

'

'

'

'

Estimated fair value

'

'

'

'

'

'

'

'

'

510,000,000

'

'

'

'

'

Borrowing capacity

'

'

'

'

'

'

'

'

'

'

'

400,000,000

'

125,000,000

25,000,000

Maximum borrowing capacity optional expansion

'

'

'

'

'

'

'

'

'

'

'

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%

'

'

'

Aggregate availability

'

'

'

'

'

'

'

'

'

'

'

'

372,700,000

'

'

Outstanding letters of credit

'

'

'

'

'

'

'

'

'

'

'

'

27,300,000

'

'

Borrowings outstanding

'

'

'

'

'

'

'

'

'

'

'

'

0

0

'

Uncommitted incremental facility

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50,000,000

Proceeds from IPO to be utilized for repurchase of debt

'

'

'

'

253,000,000

'

'

'

'

'

'

'

'

'

'

Face amount of debt repurchased

'

'

'

'

'

'

222,800,000

'

'

'

'

'

'

'

'

Prepayment premium

'

'

'

'

20,600,000

'

'

'

'

'

'

'

'

'

'

Interest paid upon settlement

'

'

'

'

9,500,000

'

'

'

'

'

'

'

'

'

'

Loss on extinguishment of debt

0

0

0

26,100,000

'

26,100,000

'

'

'

'

'

'

'

'

'

Write-off of previously deferred financing charges

'

'

'

'

'

3,700,000

'

'

'

'

'

'

'

'

'

Write-off of unamortized discount

'

'

'

'

'

$1,800,000

'

'

'

'

'

'

'

'

'

LongTerm_Debt_Details_3

Long-Term Debt (Details 3)	9 Months Ended
	Sep. 30, 2014
Capital Lease related to Excel Pipeline LLC	'
Debt Instrument [Line Items]	'
Remaining term of leases	'181 months
Capital Lease related to Magellan Pipeline Terminals, L.P.	'
Debt Instrument [Line Items]	'
Remaining term of leases	'180 months

Earnings_Per_Share_Details

Earnings Per Share (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Earnings Per Share [Abstract]	'	'	'	'
Net income attributable to CVR Energy stockholders	$7.90	$44	$218.30	$392.40
Weighted-average shares of common stock outstanding - Basic	86.8	86.8	86.8	86.8
Weighted-average shares of common stock outstanding - Diluted	86.8	86.8	86.8	86.8
Basic earnings per share (in dollars per share)	$0.09	$0.51	$2.51	$4.52
Diluted earnings per share (in dollars per share)	$0.09	$0.51	$2.51	$4.52

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	3 Months Ended			9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013	Sep. 30, 2014		Sep. 30, 2013
Operating Leases	'		'	'		'
Three Months Ending December 31, 2014	$2.40		'	$2.40		'
2015	8.1		'	8.1		'
2016	6.7		'	6.7		'
2017	4.4		'	4.4		'
2018	3.2		'	3.2		'
Thereafter	5.3		'	5.3		'
Operating leases	30.1		'	30.1		'
Unconditional Purchase Obligations	'		'	'		'
Three Months Ending December 31, 2014	65.9	[1]	'	65.9	[1]	'
2015	120.9	[1]	'	120.9	[1]	'
2016	114.1	[1]	'	114.1	[1]	'
2017	112	[1]	'	112	[1]	'
2018	112.1	[1]	'	112.1	[1]	'
Thereafter	902.5	[1]	'	902.5	[1]	'
Unconditional purchase obligations	1,427.50	[1]	'	1,427.50	[1]	'
Unrecorded purchase agreements	'		'	'		'
Lease expenses	2.4		2.4	6.9		7
Expenses related to long-term commitments	31.2		28.3	100		94.6
Petroleum transportation service agreement with TransCanada | CRRM	'		'	'		'
Unrecorded purchase agreements	'		'	'		'
Amount payable related to petroleum transportation service agreements	$929.80		'	$929.80		'
Term of agreement	'		'	'17 years		'
Minimum quantity of crude oil to be received per day (in barrels)	25,000		'	25,000		'
Period over which minimum quantity of crude oil is receivable	'		'	'20 years		'
[1]	This amount includes approximately $929.8 million payable ratably over seventeen years pursuant to petroleum transportation service agreements between Coffeyville Resources Refining & Marketing, LLC (“CRRM”) and each of TransCanada Keystone Pipeline Limited Partnership and TransCanada Keystone Pipeline, LP (together, “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.

Commitments_and_Contingencies_2

Commitments and Contingencies (Details 2) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

9 Months Ended

0 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 08, 2014

Sep. 08, 2014

sponsor

sponsor

EHS

EHS

EHS

EHS

EHS

EHS

EHS

Affiliate Pension Obligations

Affiliate Pension Obligations

New Vitol Agreement

Mr. Icahn's affiliates

Goldman, Sachs & Co. vs CVR

Deutsche Bank vs CVR

CRRM

CRRM

CRRM

CRRM

CRRM

CRRM

Loss Contingencies [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Renewal term of agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'1 year

'

'

'

Number of days for prior notice of nonrenewal

'

'

'

'

'

'

'

'

'

'

'

'

'

'180 days

'

'

'

Settlement amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$22.60

$22.70

Environmental accruals

'

'

'

'

1.2

1.5

'

'

'

'

'

'

'

'

'

'

'

Environmental costs recognized capitalized in the period

23.1

35.5

83.3

73.5

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost of renewable identification numbers

'

'

'

'

'

'

18.5

57.4

82.3

155

'

'

'

'

'

'

'

Biofuel blending obligation recorded in other current liabilities

'

'

'

'

'

'

36.3

'

36.3

'

17.4

'

'

'

'

'

'

Affiliate pension obligations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership percentage held by controlling stockholder

'

'

'

'

'

'

'

'

'

'

'

'

'

'

82.00%

'

'

Minimum ownership interest in CVR Energy by Mr. Icahn's affiliates (as a percent)

80.00%

'

80.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of sponsors of pension plans

2

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Underfunded pension obligation, if ACF and Federal-Mogul plans were voluntarily terminated

'

'

'

'

'

'

'

'

'

'

'

$442.60

$591.80

'

'

'

'

Coffeyville_Refinery_Incident_

Coffeyville Refinery Incident (Details) (CVR Refining, LP, Coffeyville Refinery Incident, Fire Isomerization Unit, USD $)	0 Months Ended	3 Months Ended	9 Months Ended
	Jul. 29, 2014	Sep. 30, 2014	Sep. 30, 2014	Jul. 29, 2014
	employee			employee
Unusual or Infrequent Item [Line Items]	'	'	'	'
Number of Employees Injured	'	'	'	4
Number of Employees Fatally Injured	1	'	'	'
Gross repair and other costs	'	$5,500,000	$5,500,000	'
Property Damage Insurance Deductible	5,000,000	'	'	'
Workers Compensation, Accident Deductible	500,000	'	'	'
Turnaround expense	'	5,500,000	5,500,000	'
Prepaid Expenses and Other Current Assets	'	'	'	'
Unusual or Infrequent Item [Line Items]	'	'	'	'
Insurance receivable	'	$500,000	$500,000	'

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)

3 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Other derivative agreement

Other derivative agreement

Interest rate swap

Interest rate swap

Biofuels blending obligation

Biofuels blending obligation

Level 1

Level 1

Level 1

Level 1

Level 1

Level 1

Level 1

Level 1

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Other derivative agreement

Other derivative agreement

Interest rate swap

Interest rate swap

Biofuels blending obligation

Biofuels blending obligation

Other derivative agreement

Other derivative agreement

Interest rate swap

Interest rate swap

Biofuels blending obligation

Biofuels blending obligation

Other derivative agreement

Other derivative agreement

Interest rate swap

Interest rate swap

Biofuels blending obligation

Biofuels blending obligation

Fair value measurements

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash equivalents

'

'

$69

$81

'

'

'

'

'

'

$69

$81

'

'

'

'

'

'

$0

$0

'

'

'

'

'

'

$0

$0

'

'

'

'

'

'

Other current assets (investments)

'

'

93.8

'

'

'

'

'

'

'

89.4

'

'

'

'

'

'

'

4.4

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

Other current assets (other derivative agreements)

'

'

'

'

53.2

0.9

'

'

'

'

'

'

0

0

'

'

'

'

'

'

53.2

0.9

'

'

'

'

'

'

0

0

'

'

'

'

Other long-term assets (other derivative agreements)

'

'

'

'

8.6

0.1

'

'

'

'

'

'

0

0

'

'

'

'

'

'

8.6

0.1

'

'

'

'

'

'

0

0

'

'

'

'

Total Assets

'

'

224.6

82

'

'

'

'

'

'

158.4

81

'

'

'

'

'

'

66.2

1

'

'

'

'

'

'

0

0

'

'

'

'

'

'

Other current liabilities

'

'

'

'

'

-15.3

-0.9

-0.9

'

'

'

'

'

0

0

0

'

'

'

'

'

-15.3

-0.9

-0.9

'

'

'

'

'

0

0

0

'

'

Other current liabilities (biofuel blending obligations)

'

'

'

'

'

'

'

'

-9.9

-16.2

'

'

'

'

'

'

0

0

'

'

'

'

'

'

-9.9

-16.2

'

'

'

'

'

'

0

0

Other long-term liabilities

'

'

'

'

'

-1.8

-0.3

-1

'

'

'

'

'

0

0

0

'

'

'

'

'

-1.8

-0.3

-1

'

'

'

'

'

0

0

0

'

'

Total Liabilities

'

'

-11.1

-35.2

'

'

'

'

'

'

0

0

'

'

'

'

'

'

-11.1

-35.2

'

'

'

'

'

'

0

0

'

'

'

'

'

'

Unrealized gain

13.2

13.2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate cost basis

$76.20

$76.20

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative_Financial_Instrumen2

Derivative Financial Instruments (Details) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Jul. 01, 2011

Jun. 30, 2011

Sep. 30, 2014

Sep. 30, 2014

CRNF

Commodity derivatives

Commodity derivatives

Commodity derivatives

Commodity derivatives

Commodity swap

Commodity swap

Commodity swap

Commodity swap

Interest rate swap

Interest rate swap

Interest rate swap

Interest rate swap

Interest rate swap

Interest rate swap

Interest rate swap

Interest rate swap

Not designated as hedges

Not designated as hedges

Designated as hedges

Designated as hedges

Designated as hedges

Designated as hedges

Designated as hedges

Term loan facility

CVR Refining, LP

CVR Refining, LP

CVR Refining, LP

CVR Refining, LP

CVR Refining, LP

CVR Refining, LP

CVR Refining, LP

CVR Refining, LP

CRNF

CRNF

CRNF

CRNF

Commodity swap

Commodity swap

Interest rate swap

Interest rate swap

Interest rate swap

Interest rate swap agreements entered into on June 30, 2011

Interest rate swap agreements entered into on July 1, 2011

CVR Refining, LP

CVR Refining, LP

CRNF

CRNF

CRNF

CRNF

CRNF

bbl

bbl

agreement

agreement

agreement

Derivative Financial Instruments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current period settlements on derivative contracts

$38,200,000

$33,900,000

$93,200,000

($3,900,000)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gain (loss) on derivatives, net

25,700,000

72,500,000

171,100,000

173,000,000

'

43,000

100,000

-300,000

-2,300,000

25,700,000

72,400,000

171,400,000

175,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of barrels

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,800,000

23,300,000

'

'

'

'

'

Unrealized gain (loss)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

61,800,000

'

'

'

'

'

'

Portion of net unrealized gain in current assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

53,200,000

'

'

'

'

'

'

Portion of net unrealized gain in non-current assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,600,000

'

'

'

'

'

'

Number of floating-to-fixed interest rate swap agreements

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

1

1

'

'

Borrowing capacity on credit facility

'

'

'

'

125,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate notional amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

62,500,000

'

'

'

'

Floating rate basis

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'three month LIBOR

'three month LIBOR

Fixed rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.94%

1.98%

Settlement period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'90 days

'90 days

Average fixed rate of interest (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.96%

'

'

'

'

Effective rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4.56%

'

'

'

'

Realized loss on the interest rate swap re-classed from AOCI into interest expense

'

'

'

'

'

'

'

'

'

'

'

'

'

-300,000

-300,000

-800,000

-800,000

'

'

'

'

'

'

'

'

'

'

'

Increase (decrease) in fair value of interest rate swap agreements

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0

($300,000)

($100,000)

($100,000)

'

'

'

'

'

'

'

Derivative_Financial_Instrumen3

Derivative Financial Instruments (Details 2) (USD $)	Sep. 30, 2014	Dec. 31, 2013
Noncurrent Liabilities	'	'
Offsetting liabilities	'	'
Gross Liabilities	'	$1,900,000
Gross Amounts Offset	'	-100,000
Net Liabilities Presented	'	1,800,000
Cash Collateral Not Offset	'	0
Net Amount	'	1,800,000
CVR Refining, LP | Current Assets	'	'
Offsetting assets	'	'
Gross Assets	53,200,000	4,300,000
Gross Amounts Offset	0	-3,400,000
Net Assets Presented	53,200,000	900,000
Cash Collateral Not Offset	0	0
Net Amount	53,200,000	900,000
CVR Refining, LP | Noncurrent Assets	'	'
Offsetting assets	'	'
Gross Assets	8,600,000	100,000
Gross Amounts Offset	0	0
Net Assets Presented	8,600,000	100,000
Cash Collateral Not Offset	0	0
Net Amount	8,600,000	100,000
CVR Refining, LP | Current Liabilities	'	'
Offsetting liabilities	'	'
Gross Liabilities	'	31,400,000
Gross Amounts Offset	'	-16,100,000
Net Liabilities Presented	'	15,300,000
Cash Collateral Not Offset	'	0
Net Amount	'	15,300,000
Interest Rate Swap [Member] | CVR Partners, LP	'	'
Offsetting liabilities	'	'
Gross Amounts Offset	0	0
Commodity swap | CVR Refining, LP | Current Assets	'	'
Offsetting assets	'	'
Gross Assets	53,200,000	4,300,000
Gross Amounts Offset	0	-3,400,000
Net Assets Presented	53,200,000	900,000
Cash Collateral Not Offset	0	0
Net Amount	53,200,000	900,000
Commodity swap | CVR Refining, LP | Noncurrent Assets	'	'
Offsetting assets	'	'
Gross Assets	8,600,000	100,000
Gross Amounts Offset	0	0
Net Assets Presented	8,600,000	100,000
Cash Collateral Not Offset	0	0
Net Amount	8,600,000	100,000
Commodity swap | CVR Refining, LP | Current Liabilities	'	'
Offsetting liabilities	'	'
Gross Liabilities	'	31,400,000
Gross Amounts Offset	'	-16,100,000
Net Liabilities Presented	'	15,300,000
Cash Collateral Not Offset	'	0
Net Amount	'	15,300,000
Commodity swap | CVR Refining, LP | Noncurrent Liabilities	'	'
Offsetting liabilities	'	'
Gross Liabilities	'	1,900,000
Gross Amounts Offset	'	-100,000
Net Liabilities Presented	'	1,800,000
Cash Collateral Not Offset	'	0
Net Amount	'	$1,800,000

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Jun. 30, 2014

Sep. 30, 2014

IEP Energy LLC

AEPC

AEPC

AEPC

AEPC

Insight Portfolio Group (formerly Icahn Sourcing, LLC)

Insight Portfolio Group (formerly Icahn Sourcing, LLC)

Insight Portfolio Group (formerly Icahn Sourcing, LLC)

Insight Portfolio Group (formerly Icahn Sourcing, LLC)

CVR Partners, LP

CVR Partners, LP

CVR Partners, LP

American Railcar Industries, Inc

American Railcar Industries, Inc

American Railcar Industries, Inc

railcar

railcar

railcar

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership percentage held by controlling stockholder

'

'

82.00%

'

'

'

'

'

'

'

'

'

'

'

Number of railcars purchased

'

'

'

'

'

'

'

'

'

'

'

'

50

'

Purchase of railcars

'

'

'

'

'

'

'

'

'

'

'

'

$6,700,000

'

Number of railcars received

'

'

'

'

'

'

'

'

'

'

'

3,300,000

'

3,300,000

Amount paid for delivered railcars

'

'

'

'

'

'

'

'

'

'

'

25

'

25

Expenses from transactions with related parties

'

'

'

'

'

'

'

'

'

'

'

50,000

'

50,000

Due to parent

15,800,000

100,000

'

15,800,000

'

15,800,000

'

'

'

'

'

'

'

'

Federal taxes paid to AEPC under the Tax Allocation Agreement

'

'

'

22,000,000

95,000,000

120,100,000

234,000,000

'

'

'

'

'

'

'

Payment to related party

'

'

'

'

'

'

'

$200,000

$0

$300,000

$100,000

'

'

'

Related_Party_Transactions_Det1

Related Party Transactions (Details 2) (USD $)	0 Months Ended	3 Months Ended					9 Months Ended
In Millions, except Share data, unless otherwise specified	Jul. 17, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Jul. 17, 2014
Related Party Transaction [Line Items]	'	'	'	'	'	'	'	'	'
Dividends	$173.70	'	$65.10	$65.10	$65.10	'	'	'	'
Payments of Dividends	'	'	'	'	'	'	369	1,172.20	'
Dividends declared per share (in dollars per share)	$2	$2.75	$0.75	$0.75	$0.75	$0.75	$4.25	$13.50	'
Per common share	'	'	'	'	'	'	$4.25	'	'
Shares outstanding	'	'	86,800,000	86,800,000	86,800,000	'	'	'	86,800,000
IEP Energy LLC	'	'	'	'	'	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'	'	'	'	'	'
Dividends	142.4	'	53.4	53.4	53.4	'	'	'	'
Payments of Dividends	'	'	'	'	'	'	302.6	'	'
Public Stockholders	'	'	'	'	'	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'	'	'	'	'	'
Dividends	31.3	'	11.7	11.7	11.7	'	'	'	'
Payments of Dividends	'	'	'	'	'	'	$66.40	'	'

Business_Segments_Details

Business Segments (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Segment Reporting [Abstract]	'	'	'	'
Number of reportable segments	'	'	2	'
Petroleum	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'
Intercompany sales	$1.90	$1.60	$6.50	$7
Intercompany cost of product sold (exclusive of depreciation and amortization)	0.1	0.8	6.9	4.7
Petroleum | Hydrogen	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'
Intercompany sales	0	0.3	0	0.6
Nitrogen Fertilizer	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'
Intercompany sales	0.1	0.8	6.9	4.7
Intercompany cost of product sold (exclusive of depreciation and amortization)	2.1	2.2	6.6	7.4
Cost of product sold related to the transfer of excess hydrogen	$0	$0.30	$0	$0.60

Business_Segments_Details_2

Business Segments (Details 2) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Segment Reporting Information [Line Items]	'	'	'	'	'
Net sales	$2,279.90	$1,977.10	$7,267.70	$6,549.80	'
Cost of product sold (exclusive of depreciation and amortization)	2,066.70	1,744.40	6,332.60	5,343.50	'
Direct operating expenses (exclusive of depreciation and amortization)	136.8	128.4	380.3	345.2	'
Depreciation and amortization	37.8	36.2	113.7	105.4	'
Operating income	6.8	40.4	354.9	670.7	'
Capital expenditures	56.5	69	171.4	183.6	'
Total assets	3,752.40	'	3,752.40	'	3,665.80
Goodwill	41	'	41	'	41
Operating Segments | Petroleum	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Net sales	2,215.20	1,910.50	7,056.90	6,322.60	'
Cost of product sold (exclusive of depreciation and amortization)	2,053.70	1,734.70	6,289.60	5,317	'
Direct operating expenses (exclusive of depreciation and amortization)	110.6	104.7	303	274.5	'
Depreciation and amortization	29.7	28.8	89.9	85.2	'
Operating income	3.9	23.4	320.4	588.1	'
Capital expenditures	48.9	60.7	154.2	140.8	'
Total assets	2,691.70	'	2,691.70	'	2,533.30
Goodwill	0	'	0	'	0
Operating Segments | Nitrogen Fertilizer	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Net sales	66.7	69.2	224.3	239.4	'
Cost of product sold (exclusive of depreciation and amortization)	15.4	13	56.6	39.2	'
Direct operating expenses (exclusive of depreciation and amortization)	26.1	23.7	77.2	70.7	'
Depreciation and amortization	6.8	6.6	20.3	18.5	'
Operating income	14.4	21.3	56.3	95.2	'
Capital expenditures	6	4	13.5	35.8	'
Total assets	562.1	'	562.1	'	593.5
Goodwill	41	'	41	'	41
Intersegment elimination	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Net sales	-2	-2.6	-13.5	-12.2	'
Cost of product sold (exclusive of depreciation and amortization)	-2.4	-3.3	-13.6	-12.7	'
Other	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Direct operating expenses (exclusive of depreciation and amortization)	0.1	0	0.1	0	'
Depreciation and amortization	1.3	0.8	3.5	1.7	'
Operating income	-11.5	-4.3	-21.8	-12.6	'
Capital expenditures	1.6	4.3	3.7	7	'
Total assets	498.6	'	498.6	'	539
Goodwill	$0	'	$0	'	$0

Subsequent_Events_Details

Subsequent Events (Details) (USD $)

0 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

In Millions, except Per Share data, unless otherwise specified

Jul. 17, 2014

Sep. 30, 2014

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Oct. 29, 2014

Oct. 29, 2014

Oct. 29, 2014

Oct. 29, 2014

IEP Energy LLC

Subsequent event

Subsequent event

Subsequent event

Subsequent event

CVR Partners, LP

CVR Refining, LP

IEP Energy LLC

Dividend

'

'

'

'

'

'

'

'

'

'

'

'

'

Dividends declared per share (in dollars per share)

$2

$2.75

$0.75

$0.75

$0.75

$0.75

$4.25

$13.50

'

$0.75

'

'

'

Dividends declared

'

'

'

'

'

'

$369

'

'

$65.10

'

'

$53.40

Ownership percentage held by controlling stockholder

'

'

'

'

'

'

'

'

82.00%

'

'

'

82.00%

Distribution

'

'

'

'

'

'

'

'

'

'

'

'

'

Declared distribution to limited partner (in dollars per share)

'

'

'

'

'

'

'

'

'

'

$0.27

$0.54

'

Declared distribution to limited partner

'

'

'

'

'

'

'

'

'

'

19.7

79.7

'

Expected proceeds from distribution

'

'

'

'

'

'

'

'

'

'

$10.50

$52.50

'