CVR Energy (CVI) 10-Q 30 Jul 15 2015 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2015	Jul. 28, 2015
Document and Entity Information
Entity Registrant Name	CVR ENERGY INC
Entity Central Index Key	1,376,139
Document Type	10-Q
Document Period End Date	Jun. 30, 2015
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	2,015
Document Fiscal Period Focus	Q2

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 937.7	$ 753.7
Accounts receivable, net of allowance for doubtful accounts of $0.5 and $0.4	179.8	136.7
Inventories	349.5	329.6
Prepaid expenses and other current assets	86.2	174.7
Income tax receivable	4.3	11.1
Deferred income taxes	2.4	6.3
Due from parent	0	44.5
Total current assets	1,559.9	1,456.6
Property, plant and equipment, net of accumulated depreciation	1,916.5	1,916
Intangible assets, net	0.2	0.2
Goodwill	41	41
Deferred financing costs, net	7.2	8.4
Other long-term assets	22.8	40.3
Total assets	3,547.6	3,462.5
Current liabilities:
Note payable and capital lease obligations	1.5	1.4
Current portion of long-term debt	125	0
Accounts payable	284.2	275
Personnel accruals	34.8	38.3
Accrued taxes other than income taxes	30.2	26.7
Due to parent	20.8	0
Deferred revenue	1.9	13.6
Other current liabilities	53.3	68.6
Total current liabilities	551.7	423.6
Long-term liabilities:
Long-term debt and capital lease obligations, net of current portion	547.7	673.5
Deferred income taxes	615.9	638.3
Other long-term liabilities	53	51.8
Total long-term liabilities	$ 1,216.6	$ 1,363.6
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	1,174.7	1,174.7
Retained deficit	(115.1)	(184.9)
Treasury stock, 98,610 shares at cost	(2.3)	(2.3)
Accumulated other comprehensive loss, net of tax	(0.2)	(0.3)
Total CVR stockholders' equity	1,058	988.1
Noncontrolling interest	721.3	687.2
Total equity	1,779.3	1,675.3
Total liabilities and equity	$ 3,547.6	$ 3,462.5

CONDENSED CONSOLIDATED BALANCE3

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Statement of Financial Position [Abstract]
Accounts receivable, allowance for doubtful accounts (in dollars)	$ 0.5	$ 0.4
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 STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Income Statement [Abstract]
Net sales	$ 1,624.2	$ 2,540.3	$ 3,013.1	$ 4,987.8
Operating costs and expenses:
Cost of product sold (exclusive of depreciation and amortization)	1,192.2	2,189	2,265.8	4,265.9
Direct operating expenses (exclusive of depreciation and amortization)	115.4	120.1	226.9	243.5
Flood insurance recovery	(27.3)	0	(27.3)	0
Selling, general and administrative expenses (exclusive of depreciation and amortization)	27.2	28	52.4	54.4
Depreciation and amortization	42.5	38.6	84.5	75.9
Total operating costs and expenses	1,350	2,375.7	2,602.3	4,639.7
Operating income	274.2	164.6	410.8	348.1
Other income (expense):
Interest expense and other financing costs	(11.9)	(9.3)	(24.6)	(19.4)
Interest income	0.3	0.2	0.4	0.4
Gain (loss) on derivatives, net	(12.6)	35.9	(64)	145.3
Other income (expense), net	0.2	(2.2)	36.3	(2.1)
Total other income (expense)	(24)	24.6	(51.9)	124.2
Income before income taxes	250.2	189.2	358.9	472.3
Income tax expense	58.1	45.2	82.1	114.6
Net income	192.1	144	276.8	357.7
Less: Net income attributable to noncontrolling interest	90.2	60.3	120.1	147.3
Net income attributable to CVR Energy stockholders	$ 101.9	$ 83.7	$ 156.7	$ 210.4
Basic earnings per share (in dollars per share)	$ 1.17	$ 0.96	$ 1.80	$ 2.42
Diluted earnings per share (in dollars per share)	1.17	0.96	1.80	2.42
Dividends declared per share (in dollars per share)	$ 0.50	$ 0.75	$ 1	$ 1.50
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 STATEME5

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Statement of Comprehensive Income [Abstract]
Net income	$ 192.1	$ 144	$ 276.8	$ 357.7
Other comprehensive income (loss):
Unrealized gain on available-for-sale securities, net of tax of $0, $0, $12.6 and $0	0	0	19.2	0
Net gain reclassified into income on sale of available-for-sale securities, net of tax of $0, $0, $(8.0) and $0 (Note 11)	0	0	(12.1)	0
Net gain reclassified into income on reclassification of available-for-sale securities to trading securities, net of tax of $0, $0, $(4.6) and $0 (Note 11)	0	0	(7.1)	0
Change in fair value of interest rate swap, net of tax of $0, $0, $0 and $(0.1)	0	(0.1)	(0.1)	(0.1)
Net loss reclassified into income on settlement of interest rate swap, net of tax of $0.1, $0.1, $0.1 and $0.1 (Note 12)	0.2	0.2	0.4	0.4
Total other comprehensive income	0.2	0.1	0.3	0.3
Comprehensive income	192.3	144.1	277.1	358
Less: Comprehensive income attributable to noncontrolling interest	90.4	60.4	120.3	147.5
Comprehensive income attributable to CVR Energy stockholders	$ 101.9	$ 83.7	$ 156.8	$ 210.5

CONDENSED CONSOLIDATED STATEME6

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Statement of Comprehensive Income [Abstract]
Unrealized gain on available-for-sale securities, tax	$ 0	$ 0	$ 12.6	$ 0
Net gain reclassified into income on sale of AFS securities, tax	0	0	(8)	0
Net gain reclassified into income on reclassification of available-for-sale securities to trading securities, tax	0	0	(4.6)	0
Change in fair value of interest rate swap, tax	0	0	0	(0.1)
Net loss reclassified into income on settlement of interest rate swap, tax	$ 0.1	$ 0.1	$ 0.1	$ 0.1

CONDENSED CONSOLIDATED STATEME7

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY - Jun. 30, 2015 - USD ($) $ in Millions	Total	CVR Partners, LP	CVR Refining, LP	Total CVR Stockholders' Equity	$0.01 Par Value Common Stock	Additional Paid-In Capital	Retained Deficit	Treasury Stock	Accumulated Other Comprehensive Loss	Noncontrolling Interest	Noncontrolling InterestCVR Partners, LP	Noncontrolling InterestCVR Refining, LP
Balance at Dec. 31, 2014	$ 1,675.3			$ 988.1	$ 0.9	$ 1,174.7	$ (184.9)	$ (2.3)	$ (0.3)	$ 687.2
Balance (in shares) at Dec. 31, 2014	86,800,000				86,929,660
Increase (Decrease) in Stockholders' Equity
Dividends paid to CVR Energy stockholders	$ (86.8)			(86.8)			(86.8)
Distributions to noncontrolling interest holders		$ (29.4)	$ (56.8)								$ (29.4)	$ (56.8)
Share-based compensation	(0.1)			(0.1)			(0.1)			0
Net income	276.8			156.7			156.7			120.1
Net gain on interest rate swaps, net of tax	0.3			0.1					0.1	0.2
Balance at Jun. 30, 2015	$ 1,779.3			1,058	$ 0.9	1,174.7	(115.1)	(2.3)	(0.2)	721.3
Balance (in shares) at Jun. 30, 2015					86,929,660
Balance (in shares) at Mar. 31, 2015	86,800,000
Increase (Decrease) in Stockholders' Equity
Net income	$ 192.1
Balance at Jun. 30, 2015	$ 1,779.3			$ 1,058	$ 0.9	$ 1,174.7	$ (115.1)	$ (2.3)	$ (0.2)	$ 721.3
Balance (in shares) at Jun. 30, 2015					86,929,660

CONDENSED CONSOLIDATED STATEME8

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY (Parenthetical) - $ / shares	Jun. 30, 2015	Dec. 31, 2014
Statement of Stockholders' Equity [Abstract]
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01

CONDENSED CONSOLIDATED STATEME9

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Cash flows from operating activities:
Net income	$ 276.8	$ 357.7
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	84.5	75.9
Allowance for doubtful accounts	0.1	(0.4)
Amortization of deferred financing costs	1.4	1.4
Deferred income taxes	(17.6)	(25.1)
Loss on disposition of assets	1.4	0.4
Share-based compensation	5.9	8.9
Gain on sale of available-for-sale securities	(20.1)	0
(Gain) loss on derivatives, net	64	(145.3)
Current period settlements on derivative contracts	(34.8)	55
Changes in assets and liabilities:
Accounts receivable	(43.7)	(6.6)
Inventories	(19.9)	(2.1)
Prepaid expenses and other current assets	34.2	6.3
Other long-term assets	(0.3)	(0.9)
Accounts payable	9.6	28.6
Accrued income taxes	6.8	11
Due to parent	65.3	27.9
Deferred revenue	(11.7)	(0.3)
Other current liabilities	(25.8)	13.1
Other long-term liabilities	0.3	0
Net cash provided by operating activities	376.4	405.5
Cash flows from investing activities:
Capital expenditures	(86.7)	(114.9)
Proceeds from sale of assets	0	0.2
Purchase of available-for-sale securities	0	(78.3)
Proceeds from sale of available-for-sale securities	68	0
Net cash used in investing activities	(18.7)	(193)
Cash flows from financing activities:
Payment of capital lease obligations	(0.7)	(0.7)
Dividends to CVR Energy's stockholders	(86.8)	(130.2)
Net cash used in financing activities	(173.7)	(55.9)
Net increase in cash and cash equivalents	184	156.6
Cash and cash equivalents, beginning of period	753.7	842.1
Cash and cash equivalents, end of period	937.7	998.7
Supplemental disclosures:
Cash paid for income taxes, net of refunds	27.7	100.7
Cash paid for interest net of capitalized interest of $1.2 and $5.2 in 2015 and 2014, respectively	23.1	17.9
Non-cash investing and financing activities:
Construction in process additions included in accounts payable	21.3	23.5
Change in accounts payable related to construction in process additions	(0.3)	(9.3)
CVR Refining, LP
Cash flows from financing activities:
Distributions to noncontrolling interest holders	(56.8)	(61.2)
CVR Partners, LP
Cash flows from financing activities:
Distributions to noncontrolling interest holders	(29.4)	(27.7)
Second Underwritten Offering | CVR Refining, LP
Cash flows from financing activities:
Proceeds from CVR Refining's June 2014 offering, net of offering costs	$ 0	$ 163.9

CONDENSED CONSOLIDATED STATEM10

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Statement of Cash Flows [Abstract]
Capitalized interest	$ 0.8	$ 2.9	$ 1.2	$ 5.2

Organization and History of the

Organization and History of the Company and Basis of Presentation	6 Months Ended
	Jun. 30, 2015
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 and markets 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, an affiliate of Icahn Enterprises L.P. ("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 June 30, 2015 , IEP and its affiliates owned approximately 82% of all outstanding shares. 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 whereby it sold 12,000,000 common units to the public (the "Secondary Offering"). Subsequent to the closing of the Secondary Offering and as of June 30, 2015 , 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 the initial public offering of its common units representing limited partner interests (the "Refining Partnership IPO"). The common units, which are listed on the NYSE, began trading on January 17, 2013 under the symbol "CVRR." On May 20, 2013, the Refining Partnership completed an underwritten offering (the "Underwritten Offering") by selling additional common units to the public. In connection with the Underwritten Offering, American Entertainment Properties Corporation ("AEPC"), an affiliate of IEP, also purchased common units in a privately negotiated transaction with a subsidiary of CVR, which was completed on May 29, 2013. Following the closing of the Underwritten Offering and sale of common units to AEPC and prior to June 30, 2014, public security holders held approximately 29% of the total Refining Partnership common units (including units owned by affiliates of 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 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 through July 23, 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 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 in connection with the underwriters' exercise of their remaining option to purchase additional common units. CVR Refining Holdings received net proceeds of approximately $9.7 million . Subsequent to the closing of the underwriters' option for the Second Underwritten Offering and as of June 30, 2015 , public security holders held approximately 34% of the total Refining Partnership common units (including units owned by affiliates of 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, 2014 audited consolidated financial statements and notes thereto included in CVR's Annual Report on Form 10-K for the year ended December 31, 2014 , which was filed with the SEC as of February 20, 2015 (the "2014 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 June 30, 2015 and December 31, 2014 , the results of operations and comprehensive income for the three and six month periods ended June 30, 2015 and 2014 , changes in equity for the six month period ended June 30, 2015 and cash flows of the Company for the six month periods ended June 30, 2015 and 2014 . 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, 2015 or any other interim or annual period.

Recent Accounting Pronouncement

Recent Accounting Pronouncements	6 Months Ended
	Jun. 30, 2015
Accounting Changes and Error Corrections [Abstract]
Recent Accounting Pronouncements	(2) Recent Accounting Pronouncements In May 2014, the Financial Accounting Standards Board ("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. On July 9, 2015, the FASB approved a one-year deferral of the effective date making the standard effective for interim and annual periods beginning after December 15, 2017. The FASB will continue to permit entities to adopt the standard on the original effective date if they choose. 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. In February 2015, the FASB issued ASU No. 2015-02, "Consolidations (Topic 810) - Amendments to the Consolidation Analysis." The new guidance makes amendments to the current consolidation guidance, including introducing a separate consolidation analysis specific to limited partnerships and other similar entities. Under this analysis, limited partnerships and other similar entities will be considered a variable interest entity ("VIE") unless the limited partners hold substantive kick-out rights or participating rights. The standard is effective for interim and annual periods beginning after December 15, 2015. The Company is currently evaluating the standard and the impact, if any, on its consolidated financial statements and footnote disclosures. In April 2015, the FASB issued ASU 2015-03, "Simplifying the Presentation of Debt Issuance Costs" ("ASU 2015-03") . The new standard requires that all costs incurred to issue debt be presented in the balance sheet as a direct deduction from the carrying value of the debt. The standard is effective for interim and annual periods beginning after December 31, 2015 and is required to be applied on a retrospective basis. Early adoption is permitted. The Company expects that the adoption of ASU 2015-03 will result in a reclassification of certain debt issuance costs on the Condensed Consolidated Balance Sheets.

Share-Based Compensation

Share-Based Compensation	6 Months Ended
	Jun. 30, 2015
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 June 30, 2015 , only restricted stock 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. Restricted Stock Units A summary of restricted stock units grant activity and changes during the six months ended June 30, 2015 is presented below: Shares Weighted-Average Grant-Date Non-vested at January 1, 2015 48,011 $ 45.89 Granted — — Vested (3,630 ) 32.44 Forfeited (3,671 ) 47.68 Non-vested at June 30, 2015 40,710 $ 46.93 Through the LTIP, shares of restricted common stock were previously granted to employees of the Company. These restricted shares are generally graded-vesting awards, which vest over a three -year period. Compensation expense is recognized on a straight-line basis over the vesting period of the respective tranche of the award. The IEP Acquisition and related Transaction Agreement dated April 18, 2012 between CVR and an affiliate of IEP (the "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 would 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 are 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 2012 and 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. 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, are remeasured at each subsequent reporting date until they vest. As of June 30, 2015 , there was approximately $0.4 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 June 30, 2015 and 2014 was approximately $(0.1) million and $0.9 million , respectively. Total compensation expense for the six months ended June 30, 2015 and 2014 was approximately $0.3 million and $1.5 million , respectively, related to the awards. As of June 30, 2015 and December 31, 2014 , the Company had a liability of $1.9 million and $1.7 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 Mr. Lipinski's performance unit awards were fully vested as of December 31, 2014 and paid as of March 31, 2015 with no remaining performance unit awards outstanding. Total compensation expense for the three and six months ended June 30, 2014 related to the performance awards was approximately $1.9 million and $3.6 million , respectively. Long-Term Incentive Plan – CVR Partners Phantom Units CVR Partners has a long-term incentive plan ("CVR Partners LTIP") that 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 . 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. Through the CVR Partners LTIP, phantom 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 2013 and 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. These awards are generally graded-vesting awards, which are expected to vest over three years with one-third of the award vesting each year. Compensation expense is recognized on a straight-line basis over the vesting period of the respective tranche of the award. 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 in accordance with the award agreement, 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, are remeasured at each subsequent reporting date until they vest. A summary of the phantom unit activity and changes under the CVR Partners LTIP during the six months ended June 30, 2015 is presented below: Phantom Units Weighted-Average Grant-Date Non-vested at January 1, 2015 243,946 $ 11.07 Granted — — Vested — — Forfeited (2,388 ) 10.99 Non-vested at June 30, 2015 241,558 $ 11.08 As of June 30, 2015 , there was approximately $2.1 million of total unrecognized compensation cost related to the awards under the CVR Partners LTIP to be recognized over a weighted-average period of 1.4 years . Total compensation expense for the three months ended June 30, 2015 and 2014 related to the awards under the CVR Partners LTIP was approximately $0.4 million and $0.2 million , respectively. Total compensation expense recorded for the six months ended June 30, 2015 and 2014 related to the awards under the CVR Partners LTIP was approximately $1.0 million and $0.6 million , respectively. As of June 30, 2015 and December 31, 2014 , the Nitrogen Fertilizer Partnership had a liability of $1.2 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 the Chief Executive Officer and President of its general partner that included performance-based phantom units and distribution equivalent rights. Compensation cost is being recognized over the performance cycles of 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 in accordance with the award agreement, 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 six months ended June 30, 2015 and 2014 related to the award was not material. Based on current estimates of performance thresholds for the remaining performance cycles, unrecognized compensation expense and the liability associated with the unvested phantom units at June 30, 2015 were also not material. Long-Term Incentive Plan – CVR Refining CVR Refining has a long-term incentive plan ("CVR Refining LTIP") that 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 . 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 for the benefit of the Refining Partnership. In 2013 and 2014, 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 generally graded-vesting awards, which are expected to vest over three years with one-third of the awards vesting each year. Compensation expense is recognized on a straight-line basis over the vesting period of the respective tranche of the award. 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 in accordance with the award agreement, 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, are remeasured at each subsequent reporting date until they vest. A summary of phantom unit activity and changes under the CVR Refining LTIP during the six months ended June 30, 2015 is presented below: Units Weighted-Average Grant-Date Fair Value Non-vested at January 1, 2015 403,947 $ 18.89 Granted — — Vested — — Forfeited (33,260 ) 19.13 Non-vested at June 30, 2015 370,687 $ 18.87 As of June 30, 2015 , there was approximately $4.5 million of total unrecognized compensation cost related to the awards under the CVR Refining LTIP to be recognized over a weighted-average period of 1.4 years . Total compensation expense recorded for the three months ended June 30, 2015 and 2014 related to the awards under the CVR Refining LTIP was approximately $0.6 million and $0.8 million , respectively. Total compensation expense recorded for the six months ended June 30, 2015 and 2014 related to the awards under the CVR Refining LTIP was approximately $2.0 million and $1.5 million , respectively. As of June 30, 2015 and December 31, 2014 , the Refining Partnership had a liability of $3.0 million and $1.0 million , respectively, for non-vested phantom unit awards and associated distribution equivalent rights, which is recorded in personnel accruals on the Condensed Consolidated Balance Sheets. In December 2014, the Company granted an award of 227,927 incentive units in the form of stock appreciation rights ("SARs") to an executive of CVR Energy. In April 2015, the award granted was cancelled and replaced by an award of notional units in the form of SARs by CVR Refining pursuant to the CVR Refining LTIP. The replacement award is structured on the same economic and other terms as the incentive unit award and did not result in a material impact. Each SAR vests over three years and entitles the executive to receive a cash payment in an amount equal to the excess of the fair market value of one unit of the Refining Partnership's common units for the first ten trading days in the month prior to vesting over the grant price of the SAR. The fair value will be adjusted to include all distributions declared and paid by the Refining Partnership during the vesting period. The fair value of each SAR is estimated at the end of each reporting period using the Black-Scholes option-pricing model. Assumptions utilized to value the award have been omitted due to immateriality of the award. Total compensation expense during the three and six months ended June 30, 2015 and the liability as of June 30, 2015 were not material. Incentive Unit Awards In 2013, 2014 and 2015, the Company granted awards of incentive units and distribution equivalent rights to certain employees of CRLLC, CVR Energy and CVR GP, LLC. The awards are generally graded vesting awards, which are expected to vest over three years with one-third of the award vesting each year. Compensation expense is recognized on a straight-line basis over the vesting period of the respective tranche of the award. 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 in accordance with the award agreement, 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, are remeasured at each subsequent reporting date until they vest. A summary of incentive unit activity and changes during the six months ended June 30, 2015 is presented below: Incentive Units Weighted-Average Grant-Date Fair Value Non-vested at January 1, 2015 435,515 $ 18.95 Granted 18,750 19.42 Vested — — Forfeited (13,649 ) 19.72 Non-vested at June 30, 2015 440,616 $ 18.95 As of June 30, 2015 , there was approximately $5.6 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 1.4 years . Total compensation expense for the three months ended June 30, 2015 and 2014 related to the awards was approximately $0.9 million and $0.8 million , respectively. Total compensation expense for the six months ended June 30, 2015 and 2014 related to the awards was approximately $2.4 million and $1.6 million , respectively. As of June 30, 2015 and December 31, 2014 , the Company had a liability of $3.3 million and $0.8 million , respectively, for non-vested incentive units and associated distribution equivalent rights, which is recorded in personnel accruals on the Condensed Consolidated Balance Sheets.

Inventories

Inventories	6 Months Ended
	Jun. 30, 2015
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: June 30, 2015 December 31, 2014 (in millions) Finished goods $ 158.2 $ 176.2 Raw materials and precious metals 124.1 88.0 In-process inventories 18.5 20.6 Parts and supplies 48.7 44.8 $ 349.5 $ 329.6

Property, Plant, and Equipment

Property, Plant, and Equipment	6 Months Ended
	Jun. 30, 2015
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: June 30, 2015 December 31, 2014 (in millions) Land and improvements $ 37.8 $ 37.4 Buildings 51.5 50.4 Machinery and equipment 2,617.2 2,581.2 Automotive equipment 23.4 22.1 Furniture and fixtures 19.9 19.0 Leasehold improvements 3.4 3.4 Aircraft 3.6 3.7 Railcars 14.9 14.5 Construction in progress 113.7 71.5 2,885.4 2,803.2 Accumulated depreciation 968.9 887.2 Total property, plant and equipment, net $ 1,916.5 $ 1,916.0 Capitalized interest recognized as interest expense for the three months ended June 30, 2015 and 2014 totaled approximately $0.8 million and $2.9 million , respectively. Capitalized interest recognized as a reduction in interest expense for the six months ended June 30, 2015 and 2014 totaled approximately $1.2 million and $5.2 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 June 30, 2015 and December 31, 2014 . Amortization of assets held under capital leases is included in depreciation expense.

Cost Classifications

Cost Classifications	6 Months Ended
	Jun. 30, 2015
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 $1.8 million and $1.5 million for the three months ended June 30, 2015 and 2014 , respectively. For the six months ended June 30, 2015 and 2014 , cost of product sold excludes depreciation and amortization of approximately $3.6 million and $3.0 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 $38.8 million and $35.6 million for the three months ended June 30, 2015 and 2014 , respectively. For the six months ended June 30, 2015 and 2014 , direct operating expenses exclude depreciation and amortization of approximately $77.3 million and $70.0 million , respectively. Selling, general and administrative expenses (exclusive of depreciation and amortization) consist primarily of legal expenses, treasury, accounting, marketing, human resources, information technology and maintaining the corporate and administrative office in Texas and the administrative office in Kansas. Selling, general and administrative expenses exclude depreciation and amortization of approximately $1.9 million and $1.5 million for the three months ended June 30, 2015 and 2014 , respectively. For the six months ended June 30, 2015 and 2014 , selling, general and administrative expense excludes depreciation and amortization of approximately $3.6 million and $2.9 million , respectively.

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2015
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 June 30, 2015 , the Company's Condensed Consolidated Balance Sheet reflected a liability of $20.8 million for federal income taxes due to AEPC under the Tax Allocation Agreement. During the three and six months ended June 30, 2015 and 2014 , the Company paid $27.5 million and $98.1 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 June 30, 2015 , the Company had unrecognized tax benefits of approximately $62.6 million , of which $30.1 million , if recognized, would impact the Company’s effective tax rate. Approximately $21.6 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. The Company has accrued interest of $8.5 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 June 30, 2015 , 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, 2014 and in various individual states for the tax years ended December 31, 2010 through December 31, 2014. The Company's effective tax rate for the three and six months ended June 30, 2015 was 23.2% and 22.9% , respectively, and the Company's effective tax rate for the three and six months ended June 30, 2014 was 23.9% and 24.3% , respectively, as compared to the Company's combined federal and state expected statutory tax rate of 39.6% for all periods. The Company's effective tax rate for the three and six months ended June 30, 2015 and 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.

Long-Term Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2015
Debt Disclosure [Abstract]
Long-Term Debt	(8) Long-Term Debt Long-term debt was as follows: June 30, 2015 December 31, 2014 (in millions) 6.5% Senior Notes due 2022 $ 500.0 $ 500.0 CRNF credit facility 125.0 125.0 Capital lease obligations 49.2 49.9 Total debt 674.2 674.9 Current portion of long-term debt and capital lease obligations (126.5 ) (1.4 ) Long-term debt, net of current portion $ 547.7 $ 673.5 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 June 30, 2015 , the Refining Partnership was in compliance with the covenants contained in the 2022 Notes. At June 30, 2015 , the estimated fair value of the 2022 Notes was approximately $500.0 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 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 ABL Credit 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 June 30, 2015 . As of June 30, 2015 , the Refining Partnership and its subsidiaries had availability under the Amended and Restated ABL Credit Facility of $322.7 million and had letters of credit outstanding of approximately $27.8 million . There were no borrowings outstanding under the Amended and Restated ABL Credit Facility as of June 30, 2015 . Availability under the Amended and Restated ABL Credit Facility was limited by borrowing base conditions as of June 30, 2015 . Nitrogen Fertilizer Partnership Credit Facility The Nitrogen Fertilizer Partnership 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 June 30, 2015 . There is no scheduled amortization. The credit facility matures in April 2016; therefore, the principal portion of the term loan is presented as current portion of long-term debt on the Condensed Consolidated Balance Sheets as of June 30, 2015 . The carrying value of the Nitrogen Fertilizer Partnership's debt approximates fair value. The Nitrogen Fertilizer Partnership is considering capital structure and refinancing options associated with the credit facility maturity. 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 incurrence of liens, disposal of assets, making restricted payments, making investments or acquisitions and entry 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 June 30, 2015 , Coffeyville Resources Nitrogen Fertilizers, LLC ("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 The Refining Partnership maintains two leases, accounted for as a capital lease and a finance obligation, related to Magellan Pipeline Terminals, L.P. and Excel Pipeline LLC. The underlying assets and related depreciation 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 172 months remaining through September 2029. The financing agreement relates to the Magellan Pipeline terminals, bulk terminal and loading facility. The lease has 171 months remaining and will expire in September 2029.

Earnings Per Share

Earnings Per Share	6 Months Ended
	Jun. 30, 2015
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 Six Months Ended 2015 2014 2015 2014 (in millions, except per share data) Net income attributable to CVR Energy stockholders $ 101.9 $ 83.7 $ 156.7 $ 210.4 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 $ 1.17 $ 0.96 $ 1.80 $ 2.42 Diluted earnings per share $ 1.17 $ 0.96 $ 1.80 $ 2.42 There were no dilutive awards outstanding during the three and six months ended June 30, 2015 and 2014 , as all unvested awards under the LTIP were liability-classified awards. See Note 3 ("Share-Based Compensation") .

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2015
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 Leases Unconditional Purchase Obligations (1) (in millions) Six Months Ending December 31, 2015 $ 4.4 $ 104.2 Year Ending December 31, 2016 7.9 126.7 2017 5.4 119.9 2018 3.8 116.7 2019 2.1 115.7 Thereafter 4.0 795.2 $ 27.6 $ 1,378.4 (1) This amount includes approximately $836.7 million payable ratably over sixteen 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"). The purchase obligation reflects the exchange rate between the Canadian dollar and the U.S. dollar as of June 30, 2015 , where applicable. 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 the three months ended June 30, 2015 and 2014 , lease expense totaled approximately $2.1 million and $2.3 million , respectively. For the six months ended June 30, 2015 and 2014 , lease expense totaled approximately $4.3 million and $4.5 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 June 30, 2015 and 2014 , total expense of approximately $34.3 million and $34.6 million , respectively, was incurred related to long-term commitments. For the six months ended June 30, 2015 and 2014 , total expense of approximately $66.5 million and $68.6 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 (as amended, 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 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 any Renewal Term. The Vitol Agreement currently extends through December 31, 2016. 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 2014 Form 10-K and in its Quarterly Report on Form 10-Q for the quarter ended March 31, 2015, which was filed with the SEC effective as of May 1, 2015 ("2015 Q1 Form 10-Q"). 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. Flood, Crude Oil Discharge and Insurance As previously disclosed in the 2014 Form 10-K and the 2015 Q1 Form 10-Q, CRRM filed a lawsuit against certain of its environmental insurance carriers requesting insurance coverage indemnification for the June/July 2007 flood and crude oil discharge losses at CRRM's Coffeyville refinery. During the second quarter of 2015, CRRM entered into a settlement agreement and release with the insurance carriers involved in the lawsuit, pursuant to which (i) CRRM received settlement proceeds of approximately $31.3 million , (ii) the parties mutually released each other from all claims relating to the flood and crude oil discharge and (iii) all pending appeals have been dismissed. Of the settlement proceeds received, $27.3 million were recorded as a flood insurance recovery in the Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2015. The remaining $4.0 million of settlement proceeds reduced CVR Refining's $4.0 million receivable related to this matter, which was included in other assets on the Condensed Consolidated Balance Sheets as of December 31, 2014. 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 either 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 the 2014 Form 10-K and the 2015 Q1 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. As previously disclosed in the 2014 Form 10-K, in January 2014, the EPA issued an inspection report to WRC related to a RCRA compliance evaluation inspection conducted in March 2013 at the Wynnewood refinery. In February 2014, the Oklahoma Department of Environmental Quality ("ODEQ") notified WRC that it concurred with the EPA's inspection findings and would be pursuing enforcement. WRC and ODEQ entered into a Consent Order in June 2015 resolving all alleged non-compliance associated with the RCRA compliance evaluation inspection. The Consent Order requires WRC to take certain corrective actions, including specified groundwater remediation and monitoring measures pursuant to a work plan to be approved by ODEQ. CVR Refining does not anticipate that the costs of complying with the Consent Order will be material. At June 30, 2015 , the Company's Condensed Consolidated Balance Sheet included total environmental accruals of $3.0 million , compared with $1.1 million at December 31, 2014 . 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 June 30, 2015 and 2014 , capital expenditures were approximately $7.4 million and $26.4 million , respectively. For the six months ended June 30, 2015 and 2014 , capital expenditures were approximately $18.3 million and $60.2 million , respectively. These expenditures were incurred for environmental compliance and efficiency of the operations. The cost of RINs for the three months ended June 30, 2015 and 2014 was approximately $37.5 million and $29.1 million , respectively. The cost of RINs for the six months ended June 30, 2015 and 2014 was approximately $74.1 million and $63.8 million , respectively. As of June 30, 2015 and December 31, 2014 , the petroleum business' biofuel blending obligation was approximately $33.2 million and $52.3 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 June 30, 2015 and December 31, 2014 . If the ACF and Federal-Mogul plans were voluntarily terminated, they would be underfunded by approximately $500.4 million and $473.8 million as of June 30, 2015 and December 31, 2014 , 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.

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2015
Fair Value Disclosures [Abstract]
Fair Value Measurements	(11) 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 June 30, 2015 and December 31, 2014 : June 30, 2015 Level 1 Level 2 Level 3 Total (in millions) Location and Description Cash equivalents $ 61.0 $ — $ — $ 61.0 Other current assets (investments) 0.3 — — 0.3 Other current assets (other derivative agreements) — 14.4 — 14.4 Other long-term assets (other derivative agreements) — 8.5 — 8.5 Total Assets $ 61.3 $ 22.9 $ — $ 84.2 Other current liabilities (other derivative agreements) — (4.8 ) — (4.8 ) Other current liabilities (interest rate swaps) — (0.6 ) — (0.6 ) Other current liabilities (biofuel blending obligations) — (13.8 ) — (13.8 ) Total Liabilities $ — $ (19.2 ) $ — $ (19.2 ) December 31, 2014 Level 1 Level 2 Level 3 Total (in millions) Location and Description Cash equivalents $ 69.0 $ — $ — $ 69.0 Other current assets (investments) 73.9 2.7 — 76.6 Other current assets (other derivative agreements) — 25.0 — 25.0 Other long-term assets (other derivative agreements) — 22.3 — 22.3 Total Assets $ 142.9 $ 50.0 $ — $ 192.9 Other current liabilities (interest rate swaps) — (0.8 ) — (0.8 ) Other current liabilities (biofuel blending obligation) — (49.6 ) — (49.6 ) Other long-term liabilities (interest rate swaps) — (0.2 ) — (0.2 ) Total Liabilities $ — $ (50.6 ) $ — $ (50.6 ) As of June 30, 2015 and December 31, 2014 , 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 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 reported at fair market value using quoted market prices. During the six months ended June 30, 2015 , the Company received proceeds of $68.0 million for the sale of a portion of its investment in available-for-sale securities. The aggregate cost basis for the available-for-sale securities sold was approximately $47.9 million . Upon the sale of the available-for-sale securities, the Company reclassified an unrealized gain of $20.1 million from accumulated other comprehensive income ("AOCI") and recognized a realized gain in other income in the Consolidated Statements of Operations for the six months ended June 30, 2015 . At the end of the first quarter of 2015, the Company's remaining available-for-sale securities with an aggregate cost basis of approximately $25.7 million were reclassified to trading securities based on management's ability and intent with respect to the securities. In connection with the transfer to trading securities, an unrealized gain previously recorded in AOCI of $11.7 million was reclassified to other income and is reflected in the Condensed Consolidated Statements of Operations for the six months ended June 30, 2015 . During the three months ended June 30, 2015, the trading securities were sold, and the Company received proceeds of $37.8 million and recognized an additional realized gain of $0.4 million in other income for the three and six months ended June 30, 2015 . The Company had no transfers of assets or liabilities between any of the above levels during the six months ended June 30, 2015 .

Derivative Financial Instrument

Derivative Financial Instruments	6 Months Ended
	Jun. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Financial Instruments	(12) Derivative Financial Instruments Gain (loss) on derivatives, net and current period settlements on derivative contracts were as follows: Three Months Ended Six Months Ended 2015 2014 2015 2014 (in millions) Current period settlements on derivative contracts $ (28.5 ) $ 33.9 $ (34.8 ) $ 55.0 Gain (loss) on derivatives, net (12.6 ) 35.9 (64.0 ) 145.3 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. The fair value of the open commodity positions as of June 30, 2015 was a net loss of $1.5 million included in other current liabilities. For the three months ended June 30, 2015 and 2014 , the Refining Partnership recognized net losses of $0.4 million and $0.2 million , respectively. For the six months ended June 30, 2015 and 2014 , the Refining Partnership recognized net losses of $1.4 million and $0.4 million , respectively. These recognized net 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 June 30, 2015 and December 31, 2014 , the Refining Partnership had open commodity hedging instruments consisting of 8.1 million barrels and 9.1 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 June 30, 2015 was a net unrealized gain of $19.6 million , of which $14.4 million was included in current assets , $8.5 million was included in non-current assets and $3.3 million was included in current liabilities. For the three months ended June 30, 2015 and 2014 , the Refining Partnership recognized a net loss of $12.2 million and a net gain of $36.1 million , respectively. For the six months ended June 30, 2015 and 2014 , the Refining Partnership recognized a net loss of $62.6 million and a net gain of $145.7 million , respectively. These recognized net gains and losses are recorded in gain (loss) on derivatives, net in the Condensed Consolidated Statements of Operations. Nitrogen Fertilizer Partnership Interest Rate Swaps CRNF has 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 agreements). Under the terms of the interest rate swap agreement entered into on June 30, 2011, CRNF receives a floating rate based on three month LIBOR and pays a fixed rate of 1.94% . Under the terms of the interest rate swap agreement entered into on July 1, 2011, CRNF receives a floating rate based on three month LIBOR and pays 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 June 30, 2015 , the effective rate of the term loan facility, net of impact of the interest rate swap agreements, was approximately 4.57% . 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. Any 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-classified 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 June 30, 2015 and 2014 , respectively. For the three months ended June 30, 2015 and 2014 , the Nitrogen Fertilizer Partnership recognized a decrease in fair value of the interest rate swap agreements of approximately $0 and $0.1 million , respectively, which was 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 $0.5 million for each of the six months ended June 30, 2015 and 2014 , respectively. For the six months ended June 30, 2015 and 2014 , the Nitrogen Fertilizer Partnership recognized a decrease in fair value of the interest rate swap agreements of $0.1 million and $0.2 million , respectively, which was 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 June 30, 2015 , 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 June 30, 2015 and December 31, 2014 . 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 June 30, 2015 are recorded as current assets, non-current assets and current liabilities in prepaid expenses and other current assets, other long-term assets and other current liabilities, respectively, in the Condensed Consolidated Balance Sheets as follows: As of June 30, 2015 Description Gross Current Assets Gross Amounts Offset Net Current Assets Presented Cash Collateral Not Offset Net Amount (in millions) Commodity Swaps $ 16.4 $ (2.0 ) $ 14.4 $ — $ 14.4 Total $ 16.4 $ (2.0 ) $ 14.4 $ — $ 14.4 As of June 30, 2015 Description Gross Non-Current Assets Gross Amounts Offset Net Non-Current Assets Presented Cash Collateral Not Offset Net Amount (in millions) Commodity Swaps $ 8.6 $ (0.1 ) $ 8.5 $ — $ 8.5 Total $ 8.6 $ (0.1 ) $ 8.5 $ — $ 8.5 As of June 30, 2015 Description Gross Gross Net Cash Net (in millions) Commodity Swaps $ 7.8 $ (4.5 ) $ 3.3 $ — $ 3.3 Other Derivative Activity 1.5 — 1.5 (1.5 ) — Total $ 9.3 $ (4.5 ) $ 4.8 $ (1.5 ) $ 3.3 The offsetting assets and liabilities for the Refining Partnership's derivatives as of December 31, 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 December 31, 2014 Description Gross Current Assets Gross Amounts Offset Net Current Assets Presented Cash Collateral Not Offset Net Amount (in millions) Commodity Swaps $ 25.3 $ (0.3 ) $ 25.0 $ — $ 25.0 Total $ 25.3 $ (0.3 ) $ 25.0 $ — $ 25.0 As of December 31, 2014 Description Gross Non-Current Assets Gross Amounts Offset Net Non-Current Assets Presented Cash Collateral Not Offset Net Amount (in millions) Commodity Swaps $ 22.3 $ — $ 22.3 $ — $ 22.3 Total $ 22.3 $ — $ 22.3 $ — $ 22.3

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2015
Related Party Transactions [Abstract]
Related Party Transactions	(13) 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 June 30, 2015 , IEP and its affiliates owned approximately 82% of all common shares outstanding. The following is a summary of dividends paid to the Company's stockholders, including IEP, for the respective quarters to which the distributions relate: December 31, 2014 March 31, 2015 Total Dividends Paid in 2015 (in millions, except per share data) Amount paid to IEP $ 35.6 $ 35.6 $ 71.2 Amounts paid to public stockholders 7.8 7.8 15.6 Total amount paid $ 43.4 $ 43.4 $ 86.8 Per common share $ 0.50 $ 0.50 $ 1.00 Shares outstanding 86.8 86.8 Tax Allocation Agreement CVR is a member of the consolidated federal tax group of AEPC, a wholly-owned subsidiary of IEP, and has entered into a Tax Allocation Agreement. Refer to Note 7 ("Income Taxes") for a discussion of related party transactions 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 $0.1 million and $0 , respectively, during the three months ended June 30, 2015 and 2014 . The Company paid Insight Portfolio Group approximately $0.1 million during each of the six months ended June 30, 2015 and 2014 . 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	6 Months Ended
	Jun. 30, 2015
Segment Reporting [Abstract]
Business Segments	(14) 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. Intercompany net sales included in petroleum net sales were approximately $2.1 million and $2.3 million for the three months ended June 30, 2015 and 2014 , respectively. Intercompany net sales included in petroleum net sales were approximately $4.2 million and $4.6 million for the six months ended June 30, 2015 and 2014 , 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 $2.0 million and $0.9 million for the three months ended June 30, 2015 and 2014 , respectively. For the six months ended June 30, 2015 and 2014 , the petroleum segment recorded intercompany cost of product sold (exclusive of depreciation and amortization) of approximately $8.5 million and $6.8 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 June 30, 2015 and 2014 , respectively. Intercompany cost of product sold (exclusive of depreciation and amortization) for the pet coke transfer described above was approximately $3.9 million and $4.5 million for the six months ended June 30, 2015 and 2014 , 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, when applicable. For the three months ended June 30, 2015 and 2014 , the net sales generated from intercompany hydrogen sales were approximately $2.0 million and $0.9 million , respectively. For the six months ended June 30, 2015 and 2014 , the net sales generated from intercompany hydrogen sales were $8.5 million and $6.8 million , respectively. 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 Six Months Ended 2015 2014 2015 2014 (in millions) Net sales Petroleum $ 1,547.5 $ 2,466.3 $ 2,852.0 $ 4,841.7 Nitrogen Fertilizer 80.8 77.2 173.9 157.5 Intersegment elimination (4.1 ) (3.2 ) (12.8 ) (11.4 ) Total $ 1,624.2 $ 2,540.3 $ 3,013.1 $ 4,987.8 Cost of product sold (exclusive of depreciation and amortization) Petroleum $ 1,180.9 $ 2,172.6 $ 2,237.1 $ 4,236.0 Nitrogen Fertilizer 15.4 19.4 41.2 41.1 Intersegment elimination (4.1 ) (3.0 ) (12.5 ) (11.2 ) Total $ 1,192.2 $ 2,189.0 $ 2,265.8 $ 4,265.9 Direct operating expenses (exclusive of depreciation and amortization) Petroleum $ 90.3 $ 93.2 $ 177.3 $ 192.4 Nitrogen Fertilizer 25.1 26.9 49.6 51.1 Other — — — — Total $ 115.4 $ 120.1 $ 226.9 $ 243.5 Depreciation and amortization Petroleum $ 34.2 $ 30.7 $ 68.2 $ 60.2 Nitrogen Fertilizer 7.0 6.8 13.8 13.5 Other 1.3 1.1 2.5 2.2 Total $ 42.5 $ 38.6 $ 84.5 $ 75.9 Operating income Petroleum $ 250.8 $ 151.9 $ 360.0 $ 316.5 Nitrogen Fertilizer 28.7 18.8 60.2 41.9 Other (5.3 ) (6.1 ) (9.4 ) (10.3 ) Total $ 274.2 $ 164.6 $ 410.8 $ 348.1 Capital expenditures Petroleum $ 36.4 $ 47.4 $ 78.1 $ 105.3 Nitrogen Fertilizer 3.4 4.1 6.0 7.5 Other 1.4 1.5 2.6 2.1 Total $ 41.2 $ 53.0 $ 86.7 $ 114.9 As of June 30, 2015 As of December 31, 2014 (in millions) Total assets Petroleum $ 2,516.3 $ 2,417.8 Nitrogen Fertilizer 560.0 578.8 Other 471.3 465.9 Total $ 3,547.6 $ 3,462.5 Goodwill Petroleum $ — $ — Nitrogen Fertilizer 41.0 41.0 Other — — Total $ 41.0 $ 41.0

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2015
Subsequent Events [Abstract]
Subsequent Events	(15) Subsequent Events Dividend On July 29, 2015 , the board of directors of the Company declared a cash dividend for the second quarter of 2015 to the Company's stockholders of $0.50 per share, or $43.4 million in aggregate. The dividend will be paid on August 17, 2015 to stockholders of record at the close of business on August 10, 2015 . IEP will receive $35.6 million in respect of its 82% ownership interest in the Company's shares. Nitrogen Fertilizer Partnership Distribution On July 29, 2015 , the board of directors of the Nitrogen Fertilizer Partnership's general partner declared a cash distribution for the second quarter of 2015 to the Nitrogen Fertilizer Partnership's unitholders of $0.39 per common unit, or $28.5 million in aggregate. The cash distribution will be paid on August 17, 2015 to unitholders of record at the close of business on August 10, 2015 . The Company will receive $15.2 million in respect of its Nitrogen Fertilizer Partnership common units. Refining Partnership Distribution On July 29, 2015 , the board of directors of the Refining Partnership's general partner declared a cash distribution for the second quarter of 2015 to the Refining Partnership's unitholders of $0.98 per common unit, or $144.6 million in aggregate. The cash distribution will be paid on August 17, 2015 to unitholders of record at the close of business on August 10, 2015 . The Company will receive $95.4 million in respect of its Refining Partnership common units.

Organization and History of t26

Organization and History of the Company and Basis of Presentation (Policies)	6 Months Ended
	Jun. 30, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
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, 2014 audited consolidated financial statements and notes thereto included in CVR's Annual Report on Form 10-K for the year ended December 31, 2014 , which was filed with the SEC as of February 20, 2015 (the "2014 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 June 30, 2015 and December 31, 2014 , the results of operations and comprehensive income for the three and six month periods ended June 30, 2015 and 2014 , changes in equity for the six month period ended June 30, 2015 and cash flows of the Company for the six month periods ended June 30, 2015 and 2014 . 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, 2015 or any other interim or annual period.
Recent Accounting Pronouncements	In May 2014, the Financial Accounting Standards Board ("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. On July 9, 2015, the FASB approved a one-year deferral of the effective date making the standard effective for interim and annual periods beginning after December 15, 2017. The FASB will continue to permit entities to adopt the standard on the original effective date if they choose. 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. In February 2015, the FASB issued ASU No. 2015-02, "Consolidations (Topic 810) - Amendments to the Consolidation Analysis." The new guidance makes amendments to the current consolidation guidance, including introducing a separate consolidation analysis specific to limited partnerships and other similar entities. Under this analysis, limited partnerships and other similar entities will be considered a variable interest entity ("VIE") unless the limited partners hold substantive kick-out rights or participating rights. The standard is effective for interim and annual periods beginning after December 15, 2015. The Company is currently evaluating the standard and the impact, if any, on its consolidated financial statements and footnote disclosures. In April 2015, the FASB issued ASU 2015-03, "Simplifying the Presentation of Debt Issuance Costs" ("ASU 2015-03") . The new standard requires that all costs incurred to issue debt be presented in the balance sheet as a direct deduction from the carrying value of the debt. The standard is effective for interim and annual periods beginning after December 31, 2015 and is required to be applied on a retrospective basis. Early adoption is permitted. The Company expects that the adoption of ASU 2015-03 will result in a reclassification of certain debt issuance costs on the Condensed Consolidated Balance Sheets.

Share-Based Compensation (Table

Share-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2015
Incentive Unit Award
Share-Based Compensation
Schedule of share-based compensation activity	A summary of incentive unit activity and changes during the six months ended June 30, 2015 is presented below: Incentive Units Weighted-Average Grant-Date Fair Value Non-vested at January 1, 2015 435,515 $ 18.95 Granted 18,750 19.42 Vested — — Forfeited (13,649 ) 19.72 Non-vested at June 30, 2015 440,616 $ 18.95
CVR Energy Long Term Incentive Plan
Share-Based Compensation
Schedule of share-based compensation activity	A summary of restricted stock units grant activity and changes during the six months ended June 30, 2015 is presented below: Shares Weighted-Average Grant-Date Non-vested at January 1, 2015 48,011 $ 45.89 Granted — — Vested (3,630 ) 32.44 Forfeited (3,671 ) 47.68 Non-vested at June 30, 2015 40,710 $ 46.93
CVR Partners Long Term Incentive Plan
Share-Based Compensation
Schedule of share-based compensation activity	A summary of the phantom unit activity and changes under the CVR Partners LTIP during the six months ended June 30, 2015 is presented below: Phantom Units Weighted-Average Grant-Date Non-vested at January 1, 2015 243,946 $ 11.07 Granted — — Vested — — Forfeited (2,388 ) 10.99 Non-vested at June 30, 2015 241,558 $ 11.08
CVR Refining Long Term Incentive Plan
Share-Based Compensation
Schedule of share-based compensation activity	A summary of phantom unit activity and changes under the CVR Refining LTIP during the six months ended June 30, 2015 is presented below: Units Weighted-Average Grant-Date Fair Value Non-vested at January 1, 2015 403,947 $ 18.89 Granted — — Vested — — Forfeited (33,260 ) 19.13 Non-vested at June 30, 2015 370,687 $ 18.87

Inventories (Tables)

Inventories (Tables)	6 Months Ended
	Jun. 30, 2015
Inventory Disclosure [Abstract]
Schedule of inventories	Inventories consisted of the following: June 30, 2015 December 31, 2014 (in millions) Finished goods $ 158.2 $ 176.2 Raw materials and precious metals 124.1 88.0 In-process inventories 18.5 20.6 Parts and supplies 48.7 44.8 $ 349.5 $ 329.6

Property, Plant, and Equipment

Property, Plant, and Equipment (Tables)	6 Months Ended
	Jun. 30, 2015
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: June 30, 2015 December 31, 2014 (in millions) Land and improvements $ 37.8 $ 37.4 Buildings 51.5 50.4 Machinery and equipment 2,617.2 2,581.2 Automotive equipment 23.4 22.1 Furniture and fixtures 19.9 19.0 Leasehold improvements 3.4 3.4 Aircraft 3.6 3.7 Railcars 14.9 14.5 Construction in progress 113.7 71.5 2,885.4 2,803.2 Accumulated depreciation 968.9 887.2 Total property, plant and equipment, net $ 1,916.5 $ 1,916.0

Long-Term Debt (Tables)

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2015
Debt Disclosure [Abstract]
Schedule of long-term debt	Long-term debt was as follows: June 30, 2015 December 31, 2014 (in millions) 6.5% Senior Notes due 2022 $ 500.0 $ 500.0 CRNF credit facility 125.0 125.0 Capital lease obligations 49.2 49.9 Total debt 674.2 674.9 Current portion of long-term debt and capital lease obligations (126.5 ) (1.4 ) Long-term debt, net of current portion $ 547.7 $ 673.5

Earnings Per Share (Tables)

Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2015
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 Six Months Ended 2015 2014 2015 2014 (in millions, except per share data) Net income attributable to CVR Energy stockholders $ 101.9 $ 83.7 $ 156.7 $ 210.4 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 $ 1.17 $ 0.96 $ 1.80 $ 2.42 Diluted earnings per share $ 1.17 $ 0.96 $ 1.80 $ 2.42

Commitments and Contingencies (

Commitments and Contingencies (Tables)	6 Months Ended
	Jun. 30, 2015
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 Leases Unconditional Purchase Obligations (1) (in millions) Six Months Ending December 31, 2015 $ 4.4 $ 104.2 Year Ending December 31, 2016 7.9 126.7 2017 5.4 119.9 2018 3.8 116.7 2019 2.1 115.7 Thereafter 4.0 795.2 $ 27.6 $ 1,378.4 (1) This amount includes approximately $836.7 million payable ratably over sixteen 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"). The purchase obligation reflects the exchange rate between the Canadian dollar and the U.S. dollar as of June 30, 2015 , where applicable. 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)	6 Months Ended
	Jun. 30, 2015
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 June 30, 2015 and December 31, 2014 : June 30, 2015 Level 1 Level 2 Level 3 Total (in millions) Location and Description Cash equivalents $ 61.0 $ — $ — $ 61.0 Other current assets (investments) 0.3 — — 0.3 Other current assets (other derivative agreements) — 14.4 — 14.4 Other long-term assets (other derivative agreements) — 8.5 — 8.5 Total Assets $ 61.3 $ 22.9 $ — $ 84.2 Other current liabilities (other derivative agreements) — (4.8 ) — (4.8 ) Other current liabilities (interest rate swaps) — (0.6 ) — (0.6 ) Other current liabilities (biofuel blending obligations) — (13.8 ) — (13.8 ) Total Liabilities $ — $ (19.2 ) $ — $ (19.2 ) December 31, 2014 Level 1 Level 2 Level 3 Total (in millions) Location and Description Cash equivalents $ 69.0 $ — $ — $ 69.0 Other current assets (investments) 73.9 2.7 — 76.6 Other current assets (other derivative agreements) — 25.0 — 25.0 Other long-term assets (other derivative agreements) — 22.3 — 22.3 Total Assets $ 142.9 $ 50.0 $ — $ 192.9 Other current liabilities (interest rate swaps) — (0.8 ) — (0.8 ) Other current liabilities (biofuel blending obligation) — (49.6 ) — (49.6 ) Other long-term liabilities (interest rate swaps) — (0.2 ) — (0.2 ) Total Liabilities $ — $ (50.6 ) $ — $ (50.6 )

Derivative Financial Instrume34

Derivative Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2015
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 Six Months Ended 2015 2014 2015 2014 (in millions) Current period settlements on derivative contracts $ (28.5 ) $ 33.9 $ (34.8 ) $ 55.0 Gain (loss) on derivatives, net (12.6 ) 35.9 (64.0 ) 145.3
Schedule of offsetting assets	The offsetting assets and liabilities for the Refining Partnership's derivatives as of June 30, 2015 are recorded as current assets, non-current assets and current liabilities in prepaid expenses and other current assets, other long-term assets and other current liabilities, respectively, in the Condensed Consolidated Balance Sheets as follows: As of June 30, 2015 Description Gross Current Assets Gross Amounts Offset Net Current Assets Presented Cash Collateral Not Offset Net Amount (in millions) Commodity Swaps $ 16.4 $ (2.0 ) $ 14.4 $ — $ 14.4 Total $ 16.4 $ (2.0 ) $ 14.4 $ — $ 14.4 As of June 30, 2015 Description Gross Non-Current Assets Gross Amounts Offset Net Non-Current Assets Presented Cash Collateral Not Offset Net Amount (in millions) Commodity Swaps $ 8.6 $ (0.1 ) $ 8.5 $ — $ 8.5 Total $ 8.6 $ (0.1 ) $ 8.5 $ — $ 8.5 The offsetting assets and liabilities for the Refining Partnership's derivatives as of December 31, 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 December 31, 2014 Description Gross Current Assets Gross Amounts Offset Net Current Assets Presented Cash Collateral Not Offset Net Amount (in millions) Commodity Swaps $ 25.3 $ (0.3 ) $ 25.0 $ — $ 25.0 Total $ 25.3 $ (0.3 ) $ 25.0 $ — $ 25.0 As of December 31, 2014 Description Gross Non-Current Assets Gross Amounts Offset Net Non-Current Assets Presented Cash Collateral Not Offset Net Amount (in millions) Commodity Swaps $ 22.3 $ — $ 22.3 $ — $ 22.3 Total $ 22.3 $ — $ 22.3 $ — $ 22.3
Schedule of offsetting liabilities	As of June 30, 2015 Description Gross Gross Net Cash Net (in millions) Commodity Swaps $ 7.8 $ (4.5 ) $ 3.3 $ — $ 3.3 Other Derivative Activity 1.5 — 1.5 (1.5 ) — Total $ 9.3 $ (4.5 ) $ 4.8 $ (1.5 ) $ 3.3

Related Party Transactions (Tab

Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2015
Related Party Transactions [Abstract]
Dividends Declared	The following is a summary of dividends paid to the Company's stockholders, including IEP, for the respective quarters to which the distributions relate: December 31, 2014 March 31, 2015 Total Dividends Paid in 2015 (in millions, except per share data) Amount paid to IEP $ 35.6 $ 35.6 $ 71.2 Amounts paid to public stockholders 7.8 7.8 15.6 Total amount paid $ 43.4 $ 43.4 $ 86.8 Per common share $ 0.50 $ 0.50 $ 1.00 Shares outstanding 86.8 86.8

Business Segments (Tables)

Business Segments (Tables)	6 Months Ended
	Jun. 30, 2015
Segment Reporting [Abstract]
Schedule of segment information	The following table summarizes certain operating results and capital expenditures information by segment: Three Months Ended Six Months Ended 2015 2014 2015 2014 (in millions) Net sales Petroleum $ 1,547.5 $ 2,466.3 $ 2,852.0 $ 4,841.7 Nitrogen Fertilizer 80.8 77.2 173.9 157.5 Intersegment elimination (4.1 ) (3.2 ) (12.8 ) (11.4 ) Total $ 1,624.2 $ 2,540.3 $ 3,013.1 $ 4,987.8 Cost of product sold (exclusive of depreciation and amortization) Petroleum $ 1,180.9 $ 2,172.6 $ 2,237.1 $ 4,236.0 Nitrogen Fertilizer 15.4 19.4 41.2 41.1 Intersegment elimination (4.1 ) (3.0 ) (12.5 ) (11.2 ) Total $ 1,192.2 $ 2,189.0 $ 2,265.8 $ 4,265.9 Direct operating expenses (exclusive of depreciation and amortization) Petroleum $ 90.3 $ 93.2 $ 177.3 $ 192.4 Nitrogen Fertilizer 25.1 26.9 49.6 51.1 Other — — — — Total $ 115.4 $ 120.1 $ 226.9 $ 243.5 Depreciation and amortization Petroleum $ 34.2 $ 30.7 $ 68.2 $ 60.2 Nitrogen Fertilizer 7.0 6.8 13.8 13.5 Other 1.3 1.1 2.5 2.2 Total $ 42.5 $ 38.6 $ 84.5 $ 75.9 Operating income Petroleum $ 250.8 $ 151.9 $ 360.0 $ 316.5 Nitrogen Fertilizer 28.7 18.8 60.2 41.9 Other (5.3 ) (6.1 ) (9.4 ) (10.3 ) Total $ 274.2 $ 164.6 $ 410.8 $ 348.1 Capital expenditures Petroleum $ 36.4 $ 47.4 $ 78.1 $ 105.3 Nitrogen Fertilizer 3.4 4.1 6.0 7.5 Other 1.4 1.5 2.6 2.1 Total $ 41.2 $ 53.0 $ 86.7 $ 114.9 As of June 30, 2015 As of December 31, 2014 (in millions) Total assets Petroleum $ 2,516.3 $ 2,417.8 Nitrogen Fertilizer 560.0 578.8 Other 471.3 465.9 Total $ 3,547.6 $ 3,462.5 Goodwill Petroleum $ — $ — Nitrogen Fertilizer 41.0 41.0 Other — — Total $ 41.0 $ 41.0

Organization and History of t37

Organization and History of the Company and Basis of Presentation (Details) $ / shares in Units, $ in Millions	Jul. 24, 2014USD ($)shares	Jun. 30, 2014USD ($)$ / sharesshares	May. 28, 2013shares	Jul. 23, 2014	Jun. 30, 2015segment	Jun. 30, 2015	Jun. 29, 2014	Jun. 30, 2015	May. 27, 2013
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Number of reportable segments | segment					2
Percentage of holders of the outstanding common units required to vote for removal of the general partner					66.67%	66.67%		66.67%
CVR Partners, LP
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of limited partner interest held by the public								47.00%	30.00%
CVR Partners, LP | Minimum
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of common units owned by limited partner					50.00%
CVR Partners, LP | Secondary Offering
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Number of partnership units sold in offering (in shares)			12,000,000
CVR GP, LLC
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of common units owned by limited partner								100.00%
CVR Refining, LP
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of limited partner interest held by the public				33.00%		34.00%	29.00%
CVR Refining, LP | Second Underwritten Offering
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Number of partnership units sold in offering (in shares)	589,100	6,500,000
Offering price per unit (in dollars per share) | $ / shares		$ 26.07
Proceeds from issuance of units | $	$ 14.9	$ 164.1
Units redeemed		6,500,000
CVR Refining GP, LLC
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of common units owned by limited partner						100.00%
IEP Energy LLC
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Ownership percentage held by controlling stockholder					82.00%
IEP Energy LLC | CVR Refining, LP
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Ownership interest held by IEP						4.00%	4.00%
Coffeyville Resources LLC | CVR Partners, LP
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of common units owned by CRLLC or CVR Refining Holdings								53.00%
CVR Refining Holdings LLC | Second Underwritten Offering
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Number of partnership units sold in offering (in shares)	385,900
Proceeds from issuance of units | $	$ 9.7
CVR Refining Holdings LLC | CVR Refining, LP
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of common units owned by CRLLC or CVR Refining Holdings				67.00%		66.00%	71.00%

Share-Based Compensation (Detai

Share-Based Compensation (Details 1) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Share-Based Compensation
Liability for unvested restricted share awards	$ 34.8		$ 34.8		$ 38.3
CVR Energy Long Term Incentive Plan
Share-Based Compensation
Common stock authorized for issuance (in shares)	7,500,000		7,500,000
CVR Energy Long Term Incentive Plan | Stock Options
Share-Based Compensation
Common stock authorized for issuance (in shares)	1,000,000		1,000,000
CVR Energy Long Term Incentive Plan | Restricted stock units
Share-Based Compensation
Vesting period			3 years
Offer price per share received as cash settlement on restricted stock awards vested in 2012	$ 30		$ 30
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	$ 0.4		$ 0.4
Weighted-average period for amortization of unrecognized compensation cost			6 months
Compensation expense	$ (0.1)	$ 0.9	$ 0.3	$ 1.5
Shares outstanding	40,710		40,710		48,011
CVR Energy Long Term Incentive Plan | Restricted stock units | Personnel Accruals
Share-Based Compensation
Liability for unvested restricted share awards	$ 1.9		$ 1.9		$ 1.7
CVR Energy Long Term Incentive Plan | Restricted stock units | Tranche One
Share-Based Compensation
Vesting rights percentage			33.33%
CVR Energy Long Term Incentive Plan | Restricted stock units | Tranche Two
Share-Based Compensation
Vesting rights percentage			33.33%
CVR Energy Long Term Incentive Plan | Restricted stock units | Tranche Three
Share-Based Compensation
Vesting rights percentage			33.33%
CVR Energy Long Term Incentive Plan | Performance Unit Awards
Share-Based Compensation
Compensation expense		$ 1.9		$ 3.6
Shares outstanding	0		0

Share-Based Compensation (Det39

Share-Based Compensation (Details 2) - CVR Energy Long Term Incentive Plan - Restricted stock units - $ / shares	6 Months Ended
	Jun. 30, 2015
Non-vested shares activity
Non-vested at the beginning of the period (in shares)	48,011
Granted (in shares)	0
Vested (in shares)	(3,630)
Forfeited (in shares)	(3,671)
Non-vested at the end of the period (in shares)	40,710
Weighted-Average Grant-Date Fair Value
Non-vested at the beginning of the period (in dollars per share)	$ 45.89
Granted (in dollars per share)	0
Vested (in dollars per share)	32.44
Forfeited (in dollars per share)	47.68
Non-vested at the end of the period (in dollars per share)	$ 46.93

Share-Based Compensation (Det40

Share-Based Compensation (Details 3) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Share-Based Compensation
Liability for unvested restricted share awards	$ 34.8		$ 34.8		$ 38.3
CVR Partners, LP | CVR Partners Long Term Incentive Plan
Share-Based Compensation
Common stock authorized for issuance (in shares)	5,000,000		5,000,000
Vesting period			3 years
Number of share right to receive cash payment on vesting equal to fair market value is received per award			1
CVR Partners, LP | CVR Partners Long Term Incentive Plan | Tranche One
Share-Based Compensation
Vesting rights percentage			33.33%
CVR Partners, LP | CVR Partners Long Term Incentive Plan | Tranche Two
Share-Based Compensation
Vesting rights percentage			33.33%
CVR Partners, LP | CVR Partners Long Term Incentive Plan | Tranche Three
Share-Based Compensation
Vesting rights percentage			33.33%
CVR Partners, LP | CVR Partners Long Term Incentive Plan | Phantom Unit and Common Units
Share-Based Compensation
Unrecognized compensation cost	$ 2.1		$ 2.1
Weighted-average period for amortization of unrecognized compensation cost			1 year 4 months 24 days
Compensation expense	0.4	$ 0.2	$ 1	$ 0.6
CVR Partners, LP | CVR Partners Long Term Incentive Plan | Phantom Unit and Common Units | Personnel Accruals
Share-Based Compensation
Liability for unvested restricted share awards	$ 1.2		$ 1.2		$ 0.2

Share-Based Compensation (Det41

Share-Based Compensation (Details 4) - CVR Partners, LP - CVR Partners Long Term Incentive Plan - Phantom Units - $ / shares	6 Months Ended
	Jun. 30, 2015
Non-vested shares activity
Non-vested at the beginning of the period (in shares)	243,946
Granted (in shares)	0
Vested (in shares)	0
Forfeited (in shares)	(2,388)
Non-vested at the end of the period (in shares)	241,558
Weighted-Average Grant-Date Fair Value
Non-vested at the beginning of the period (in dollars per share)	$ 11.07
Granted (in dollars per share)	0
Vested (in dollars per share)	0
Forfeited (in dollars per share)	10.99
Non-vested at the end of the period (in dollars per share)	$ 11.08

Share-Based Compensation (Det42

Share-Based Compensation (Details 5) $ in Millions	1 Months Ended	3 Months Ended		6 Months Ended
	Dec. 31, 2014USD ($)shares	Jun. 30, 2015USD ($)shares	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)trading_dayshares	Jun. 30, 2014USD ($)
Share-Based Compensation
Liability for unvested restricted share awards | $	$ 38.3	$ 34.8		$ 34.8
CVR Refining, LP | CVR Refining Long Term Incentive Plan
Share-Based Compensation
Common stock authorized for issuance (in shares)		11,070,000		11,070,000
Vesting period				3 years
Number of share right to receive cash payment on vesting equal to fair market value is received per award				1
CVR Refining, LP | CVR Refining Long Term Incentive Plan | Phantom Unit Plan
Share-Based Compensation
Unrecognized compensation cost | $		$ 4.5		$ 4.5
Weighted-average period for amortization of unrecognized compensation cost				1 year 4 months 24 days
Compensation expense | $		0.6	$ 0.8	$ 2	$ 1.5
Granted (in shares)				0
CVR Refining, LP | CVR Refining Long Term Incentive Plan | Phantom Unit Plan | Personnel Accruals
Share-Based Compensation
Liability for unvested restricted share awards | $	$ 1	$ 3		$ 3
Tranche One | CVR Refining, LP | CVR Refining Long Term Incentive Plan
Share-Based Compensation
Vesting rights percentage				33.33%
Tranche Two | CVR Refining, LP | CVR Refining Long Term Incentive Plan
Share-Based Compensation
Vesting rights percentage				33.33%
Tranche Three | CVR Refining, LP | CVR Refining Long Term Incentive Plan
Share-Based Compensation
Vesting rights percentage				33.33%
Executive Officer | CVR Refining, LP | CVR Refining Long Term Incentive Plan | Stock Appreciation Rights (SARs)
Share-Based Compensation
Vesting period				3 years
Number of share right to receive cash payment on vesting equal to fair market value is received per award				1
Granted (in shares)	227,927
Period for determination of cash payment value | trading_day				10

Share-Based Compensation (Det43

Share-Based Compensation (Details 6) - CVR Refining, LP - CVR Refining Long Term Incentive Plan - Phantom Unit Plan - $ / shares	6 Months Ended
	Jun. 30, 2015
Non-vested shares activity
Non-vested at the beginning of the period (in shares)	403,947
Granted (in shares)	0
Vested (in shares)	0
Forfeited (in shares)	(33,260)
Non-vested at the end of the period (in shares)	370,687
Weighted-Average Grant-Date Fair Value
Non-vested at the beginning of the period (in dollars per share)	$ 18.89
Granted (in dollars per share)	0
Vested (in dollars per share)	0
Forfeited (in dollars per share)	19.13
Non-vested at the end of the period (in dollars per share)	$ 18.87

Share-Based Compensation (Det44

Share-Based Compensation (Details 7) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Share-Based Compensation
Liability for unvested restricted share awards	$ 34.8		$ 34.8		$ 38.3
Incentive Unit Award
Share-Based Compensation
Vesting period			3 years
Number of share right to receive cash payment on vesting equal to fair market value is received per award			1
Unrecognized compensation cost	5.6		$ 5.6
Weighted-average period for amortization of unrecognized compensation cost			1 year 4 months 24 days
Compensation expense	0.9	$ 0.8	$ 2.4	$ 1.6
Incentive Unit Award | Personnel Accruals
Share-Based Compensation
Liability for unvested restricted share awards	$ 3.3		$ 3.3		$ 0.8
Tranche One | Incentive Unit Award
Share-Based Compensation
Vesting rights percentage			33.33%
Tranche Two | Incentive Unit Award
Share-Based Compensation
Vesting rights percentage			33.33%
Tranche Three | Incentive Unit Award
Share-Based Compensation
Vesting rights percentage			33.33%

Share-Based Compensation (Det45

Share-Based Compensation (Details 8) - Incentive Unit Award - $ / shares	6 Months Ended
	Jun. 30, 2015
Non-vested shares activity
Non-vested at the beginning of the period (in shares)	435,515
Granted (in shares)	18,750
Vested (in shares)	0
Forfeited (in shares)	(13,649)
Non-vested at the end of the period (in shares)	440,616
Weighted-Average Grant-Date Fair Value
Non-vested at the beginning of the period (in dollars per share)	$ 18.95
Granted (in dollars per share)	19.42
Vested (in dollars per share)	0
Forfeited (in dollars per share)	19.72
Non-vested at the end of the period (in dollars per share)	$ 18.95

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Inventory Disclosure [Abstract]
Finished goods	$ 158.2	$ 176.2
Raw materials and precious metals	124.1	88
In-process inventories	18.5	20.6
Parts and supplies	48.7	44.8
Inventories	$ 349.5	$ 329.6

Property, Plant, and Equipmen47

Property, Plant, and Equipment (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Property, Plant, and Equipment
Gross property, plant and equipment	$ 2,885.4		$ 2,885.4		$ 2,803.2
Accumulated depreciation	968.9		968.9		887.2
Total property, plant and equipment, net	1,916.5		1,916.5		1,916
Capitalized interest	0.8	$ 2.9	1.2	$ 5.2
Original carrying value of assets under capital lease obligations	24.8		24.8		24.8
Land and improvements
Property, Plant, and Equipment
Gross property, plant and equipment	37.8		37.8		37.4
Buildings
Property, Plant, and Equipment
Gross property, plant and equipment	51.5		51.5		50.4
Machinery and equipment
Property, Plant, and Equipment
Gross property, plant and equipment	2,617.2		2,617.2		2,581.2
Automotive equipment
Property, Plant, and Equipment
Gross property, plant and equipment	23.4		23.4		22.1
Furniture and fixtures
Property, Plant, and Equipment
Gross property, plant and equipment	19.9		19.9		19
Leasehold improvements
Property, Plant, and Equipment
Gross property, plant and equipment	3.4		3.4		3.4
Aircraft
Property, Plant, and Equipment
Gross property, plant and equipment	3.6		3.6		3.7
Railcars
Property, Plant, and Equipment
Gross property, plant and equipment	14.9		14.9		14.5
Construction in progress
Property, Plant, and Equipment
Gross property, plant and equipment	$ 113.7		$ 113.7		$ 71.5

Cost Classifications (Details)

Cost Classifications (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Cost Classifications
Depreciation and amortization not included in cost of product sold	$ 1.8	$ 1.5	$ 3.6	$ 3
Depreciation and amortization not included in direct operating expenses	38.8	35.6	77.3	70
Depreciation and amortization not included in selling, general and administrative expenses	$ 1.9	$ 1.5	$ 3.6	$ 2.9

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Income Taxes [Line Items]
Unrecognized tax benefits	$ 62.6		$ 62.6
Unrecognized tax benefits which, if recognized, would impact the company's effective tax rate	30.1		30.1
Unrecognized tax benefits related to state tax credits	21.6		21.6
Accrued interest	$ 8.5		$ 8.5
Effective tax rate (as a percent)	23.20%	23.90%	22.90%	24.30%
Effective tax rate at a combined federal and state income tax rate (as a percent)	39.60%	39.60%	39.60%	39.60%
AEPC
Income Taxes [Line Items]
Due to parent	$ 20.8		$ 20.8
Federal taxes paid to AEPC under the Tax Allocation Agreement	$ 27.5	$ 98.1	$ 27.5	$ 98.1

Long-Term Debt (Details)

Long-Term Debt (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Total debt	$ 674.2	$ 674.9
Current portion of long-term debt and capital lease obligations	(126.5)	(1.4)
Long-term debt, net of current portion	$ 547.7	$ 673.5
6.5% Senior Notes due 2022
Debt Instrument [Line Items]
Stated interest rate (as a percent)	6.50%	6.50%
Senior Notes | 6.5% Senior Notes due 2022
Debt Instrument [Line Items]
Total debt	$ 500	$ 500
Line of Credit | CRNF credit facility
Debt Instrument [Line Items]
Total debt	125	125
Capital Lease Obligations
Debt Instrument [Line Items]
Total debt	$ 49.2	$ 49.9

Long-Term Debt (Details 2)

Long-Term Debt (Details 2) - USD ($)	Jun. 30, 2015	Dec. 31, 2014	Oct. 23, 2012
6.5% Senior Notes due 2022
Debt Instrument [Line Items]
Stated interest rate (as a percent)	6.50%	6.50%
6.5% Senior Notes due 2022 | Refining LLC | Senior Notes
Debt Instrument [Line Items]
Aggregate principal amount			$ 500,000,000
Stated interest rate (as a percent)			6.50%
6.5% Senior Notes due 2022 | Refining LLC | Senior Notes | Level 2
Debt Instrument [Line Items]
Estimated fair value	$ 500,000,000
Amended and Restated ABL Credit Facility | Credit parties
Debt Instrument [Line Items]
Borrowing capacity	400,000,000
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%
Amended and Restated ABL Credit Facility | CVR Refining, LP
Debt Instrument [Line Items]
Aggregate availability	$ 322,700,000
Outstanding letters of credit	27,800,000
Borrowings outstanding	0
CRNF credit facility | Line of Credit
Debt Instrument [Line Items]
Borrowings outstanding	0
CRNF credit facility | CRNF | Line of Credit | Term Loan
Debt Instrument [Line Items]
Aggregate principal amount	125,000,000
CRNF credit facility | CRNF | Line of Credit | Revolving Credit Facility
Debt Instrument [Line Items]
Borrowing capacity	25,000,000
Uncommitted incremental facility	$ 50,000,000

Long-Term Debt (Details 3)

Long-Term Debt (Details 3) - 6 months ended Jun. 30, 2015 - lease	Total
Debt Instrument [Line Items]
Number of leases acquired	2
Capital Lease related to Excel Pipeline LLC
Debt Instrument [Line Items]
Remaining term of leases	172 months
Capital Lease related to Magellan Pipeline Terminals, L.P.
Debt Instrument [Line Items]
Remaining term of leases	171 months

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Earnings Per Share [Abstract]
Net income attributable to CVR Energy stockholders	$ 101.9	$ 83.7	$ 156.7	$ 210.4
Weighted-average shares of common stock outstanding - Basic (in shares)	86.8	86.8	86.8	86.8
Weighted-average shares of common stock outstanding - Diluted (in shares)	86.8	86.8	86.8	86.8
Basic earnings per share (in dollars per share)	$ 1.17	$ 0.96	$ 1.80	$ 2.42
Diluted earnings per share (in dollars per share)	$ 1.17	$ 0.96	$ 1.80	$ 2.42

Commitments and Contingencies54

Commitments and Contingencies (Details) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2015USD ($)bbl	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)bbl	Jun. 30, 2014USD ($)
Operating Leases
Six Months Ending December 31, 2015		$ 4.4		$ 4.4
2,016		7.9		7.9
2,017		5.4		5.4
2,018		3.8		3.8
2,019		2.1		2.1
Thereafter		4		4
Operating leases		27.6		27.6
Unconditional Purchase Obligations
Six Months Ending December 31, 2015	[1]	104.2		104.2
2,016	[1]	126.7		126.7
2,017	[1]	119.9		119.9
2,018	[1]	116.7		116.7
2,019	[1]	115.7		115.7
Thereafter	[1]	795.2		795.2
Unconditional purchase obligations	[1]	1,378.4		1,378.4
Unrecorded purchase agreements
Lease expenses		2.1	$ 2.3	4.3	$ 4.5
Expenses related to long-term commitments		34.3	$ 34.6	66.5	$ 68.6
Petroleum transportation service agreement with TransCanada | CRRM
Unrecorded purchase agreements
Amount payable related to petroleum transportation service agreements		$ 836.7		$ 836.7
Term of agreement				16 years
Minimum quantity of crude oil to be received per day (in barrels) | bbl		25,000		25,000
Period over which minimum quantity of crude oil is receivable				20 years
[1]	This amount includes approximately $836.7 million payable ratably over sixteen 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"). The purchase obligation reflects the exchange rate between the Canadian dollar and the U.S. dollar as of June 30, 2015, where applicable. 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 Contingencies55

Commitments and Contingencies (Details 2) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Gain Contingencies [Line Items]
Flood insurance recovery	$ 27.3	$ 0	$ 27.3	$ 0
CRRM Flood Insurance Litigation
Gain Contingencies [Line Items]
Proceeds from legal settlements	31.3
CVR Refining, LP | CRRM Flood Insurance Litigation
Gain Contingencies [Line Items]
Decrease in insurance settlements receivable	$ 4
CVR Refining, LP | Other Assets | CRRM Flood Insurance Litigation
Gain Contingencies [Line Items]
Insurance settlements receivable					$ 4

Commitments and Contingencies56

Commitments and Contingencies (Details 3) $ in Millions	Aug. 31, 2012	Jun. 30, 2015USD ($)sponsor	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)sponsor	Jun. 30, 2014USD ($)	Dec. 31, 2014USD ($)
Loss Contingencies [Line Items]
Environmental costs recognized capitalized in the period		$ 7.4	$ 26.4	$ 18.3	$ 60.2
Affiliate pension obligations
Minimum ownership interest in CVR Energy by Mr. Icahn's affiliates (as a percent)		80.00%		80.00%
Number of sponsors of pension plans | sponsor		2		2
Mr. Icahn's affiliates
Affiliate pension obligations
Ownership percentage held by controlling stockholder				82.00%
EHS
Loss Contingencies [Line Items]
Environmental accruals		$ 3		$ 3		$ 1.1
EHS | CRRM
Loss Contingencies [Line Items]
Cost of renewable identification numbers		37.5	$ 29.1	74.1	$ 63.8
Biofuel blending obligation recorded in other current liabilities		33.2		33.2		52.3
Affiliate Pension Obligations
Affiliate pension obligations
Underfunded pension obligation, if ACF and Federal-Mogul plans were voluntarily terminated		$ 500.4		$ 500.4		$ 473.8
New Vitol Agreement | CRRM
Loss Contingencies [Line Items]
Renewal term of agreement	1 year
Number of days for prior notice of nonrenewal	180 days

Fair Value Measurements (Detail

Fair Value Measurements (Details) - Recurring - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Fair value measurements
Cash equivalents	$ 61	$ 69
Other current assets (investments)	0.3	76.6
Total Assets	84.2	192.9
Total Liabilities	(19.2)	(50.6)
Commodity swaps
Fair value measurements
Other current assets (other derivative agreements)	14.4	25
Other long-term assets (other derivative agreements)	8.5	22.3
Commodity Swaps and Commodity Derivatives [Member]
Fair value measurements
Other current liabilities	(4.8)
Interest rate swaps
Fair value measurements
Other current liabilities	(0.6)	(0.8)
Other long-term liabilities		(0.2)
Biofuels blending obligation
Fair value measurements
Other current liabilities (biofuel blending obligations)	(13.8)	(49.6)
Level 1
Fair value measurements
Cash equivalents	61	69
Other current assets (investments)	0.3	73.9
Total Assets	61.3	142.9
Total Liabilities	0	0
Level 1 | Commodity swaps
Fair value measurements
Other current assets (other derivative agreements)	0	0
Other long-term assets (other derivative agreements)	0	0
Level 1 | Commodity Swaps and Commodity Derivatives [Member]
Fair value measurements
Other current liabilities	0
Level 1 | Interest rate swaps
Fair value measurements
Other current liabilities	0	0
Other long-term liabilities		0
Level 1 | Biofuels blending obligation
Fair value measurements
Other current liabilities (biofuel blending obligations)	0	0
Level 2
Fair value measurements
Cash equivalents	0	0
Other current assets (investments)	0	2.7
Total Assets	22.9	50
Total Liabilities	(19.2)	(50.6)
Level 2 | Commodity swaps
Fair value measurements
Other current assets (other derivative agreements)	14.4	25
Other long-term assets (other derivative agreements)	8.5	22.3
Level 2 | Commodity Swaps and Commodity Derivatives [Member]
Fair value measurements
Other current liabilities	(4.8)
Level 2 | Interest rate swaps
Fair value measurements
Other current liabilities	(0.6)	(0.8)
Other long-term liabilities		(0.2)
Level 2 | Biofuels blending obligation
Fair value measurements
Other current liabilities (biofuel blending obligations)	(13.8)	(49.6)
Level 3
Fair value measurements
Cash equivalents	0	0
Other current assets (investments)	0	0
Total Assets	0	0
Total Liabilities	0	0
Level 3 | Commodity swaps
Fair value measurements
Other current assets (other derivative agreements)	0	0
Other long-term assets (other derivative agreements)	0	0
Level 3 | Commodity Swaps and Commodity Derivatives [Member]
Fair value measurements
Other current liabilities	0
Level 3 | Interest rate swaps
Fair value measurements
Other current liabilities	0	0
Other long-term liabilities		0
Level 3 | Biofuels blending obligation
Fair value measurements
Other current liabilities (biofuel blending obligations)	$ 0	$ 0

Fair Value Measurements (Deta58

Fair Value Measurements (Details 2) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Mar. 31, 2015
Fair value measurements
Proceeds from sale of available-for-sale securities			$ 68	$ 0
Aggregate cost basis	$ 47.9		47.9
Other income (expense), net	0.2	$ (2.2)	36.3	$ (2.1)
Aggregate cost basis, AFS securities reclassified to trading securities					$ 25.7
Proceeds from sale of trading securities	37.8
Realized gain on trading securities	$ 0.4		0.4
Reclassification out of AOCI | Accumulated Net Unrealized Investment Gain (Loss)
Fair value measurements
Other income (expense), net			20.1
Reclassification out of AOCI | Accumulated Net Unrealized Investment Gain (Loss) Transfered to Trading Securities
Fair value measurements
Other income (expense), net			$ 11.7

Derivative Financial Instrume59

Derivative Financial Instruments (Details) bbl in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2015USD ($)agreement	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)agreementbbl	Jun. 30, 2014USD ($)	Dec. 31, 2014bbl
Derivative Financial Instruments
Current period settlements on derivative contracts	$ (28,500,000)	$ 33,900,000	$ (34,800,000)	$ 55,000,000
Gain (loss) on derivatives, net	(12,600,000)	35,900,000	(64,000,000)	145,300,000
Commodity derivatives
Derivative Financial Instruments
Derivative asset (liabilities)	(1,500,000)		(1,500,000)
Commodity derivatives | CVR Refining, LP
Derivative Financial Instruments
Gain (loss) on derivatives, net	(400,000)	(200,000)	(1,400,000)	(400,000)
Commodity swaps | CVR Refining, LP
Derivative Financial Instruments
Gain (loss) on derivatives, net	(12,200,000)	36,100,000	(62,600,000)	145,700,000
Commodity swaps | CVR Refining, LP | Not designated as hedges
Derivative Financial Instruments
Derivative asset (liabilities)	19,600,000		$ 19,600,000
Derivative, Nonmonetary Notional Amount, Volume | bbl			8.1		9.1
Portion of net unrealized gain in current assets	14,400,000		$ 14,400,000
Portion of net unrealized gain in non-current assets	8,500,000		8,500,000
Portion of net unrealized loss in current liabilities	(3,300,000)		(3,300,000)
Interest rate swaps
Derivative Financial Instruments
Realized loss on the interest rate swap re-classed from AOCI into interest expense	(300,000)	(300,000)	(500,000)	(500,000)
Interest rate swaps | CRNF
Derivative Financial Instruments
Increase (decrease) in fair value of interest rate swap agreements	$ 0	$ (100,000)	$ (100,000)	$ (200,000)
Interest rate swaps | CRNF | Designated as hedges
Derivative Financial Instruments
Number of floating-to-fixed interest rate swap agreements | agreement	2		2
Aggregate notional amount	$ 62,500,000		$ 62,500,000
Average fixed rate of interest (as a percent)	1.96%		1.96%
Effective rate (as a percent)	4.57%		4.57%
Interest rate swap agreements entered into on June 30, 2011 | CRNF | Designated as hedges
Derivative Financial Instruments
Fixed rate (as a percent)	1.94%		1.94%
Settlement period			90 days
Interest rate swap agreements entered into on July 1, 2011 | CRNF | Designated as hedges
Derivative Financial Instruments
Fixed rate (as a percent)	1.975%		1.975%
Settlement period			90 days
Term Loan | Line of Credit | CRNF credit facility | CRNF
Derivative Financial Instruments
Aggregate principal amount	$ 125,000,000		$ 125,000,000

Derivative Financial Instrume60

Derivative Financial Instruments (Details 2) - CVR Refining, LP - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Current Assets
Offsetting Assets [Line Items]
Gross Assets	$ 16.4	$ 25.3
Gross Amounts Offset	(2)	(0.3)
Net Assets Presented	14.4	25
Cash Collateral Not Offset	0	0
Net Amount	14.4	25
Noncurrent Assets
Offsetting Assets [Line Items]
Gross Assets	8.6	22.3
Gross Amounts Offset	(0.1)	0
Net Assets Presented	8.5	22.3
Cash Collateral Not Offset	0	0
Net Amount	8.5	22.3
Commodity swaps | Current Assets
Offsetting Assets [Line Items]
Gross Assets	16.4	25.3
Gross Amounts Offset	(2)	(0.3)
Net Assets Presented	14.4	25
Cash Collateral Not Offset	0	0
Net Amount	14.4	25
Commodity swaps | Noncurrent Assets
Offsetting Assets [Line Items]
Gross Assets	8.6	22.3
Gross Amounts Offset	(0.1)	0
Net Assets Presented	8.5	22.3
Cash Collateral Not Offset	0	0
Net Amount	$ 8.5	$ 22.3

Derivative Financial Instrume61

Derivative Financial Instruments (Details 3) - USD ($)	Jun. 30, 2015	Dec. 31, 2014
Current Liabilities | CVR Refining, LP
Offsetting Liabilities [Line Items]
Gross Liabilities	$ 9,300,000
Gross Amounts Offset	(4,500,000)
Net Liabilities Presented	4,800,000
Cash Collateral Not Offset	(1,500,000)
Net Amount	3,300,000
Interest rate swaps | CVR Partners, LP
Offsetting Liabilities [Line Items]
Gross Amounts Offset	0	$ 0
Commodity swaps | Current Liabilities | CVR Refining, LP
Offsetting Liabilities [Line Items]
Gross Liabilities	7,800,000
Gross Amounts Offset	(4,500,000)
Net Liabilities Presented	3,300,000
Cash Collateral Not Offset	0
Net Amount	3,300,000
Other Derivative Activity | Current Liabilities | CVR Refining, LP
Offsetting Liabilities [Line Items]
Gross Liabilities	1,500,000
Gross Amounts Offset	0
Net Liabilities Presented	1,500,000
Cash Collateral Not Offset	(1,500,000)
Net Amount	$ 0

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Related Party Transaction [Line Items]
Dividends		$ 43.4	$ 43.4
Dividends paid					$ 86.8	$ 130.2
Dividends declared per share (in dollars per share)	$ 0.50	$ 0.50	$ 0.50	$ 0.75	$ 1	$ 1.50
Dividends paid per share (in dollars per share)					$ 1
Shares outstanding (in shares)		86.8	86.8
IEP Energy LLC
Related Party Transaction [Line Items]
Ownership percentage held by controlling stockholder					82.00%
Dividends		$ 35.6	$ 35.6
Dividends paid					$ 71.2
Public Stockholders
Related Party Transaction [Line Items]
Dividends		$ 7.8	$ 7.8
Dividends paid					15.6
Insight Portfolio Group (formerly Icahn Sourcing, LLC)
Related Party Transaction [Line Items]
Payment to related party	$ 0.1			$ 0	$ 0.1	$ 0.1

Business Segments (Details)

Business Segments (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)segment	Jun. 30, 2014USD ($)
Segment Reporting [Abstract]
Number of reportable segments | segment			2
Segment Reporting Information [Line Items]
Net sales	$ 1,624.2	$ 2,540.3	$ 3,013.1	$ 4,987.8
Cost of product sold (exclusive of depreciation and amortization)	1,192.2	2,189	2,265.8	4,265.9
Intersegment elimination
Segment Reporting Information [Line Items]
Net sales	(4.1)	(3.2)	(12.8)	(11.4)
Cost of product sold (exclusive of depreciation and amortization)	(4.1)	(3)	(12.5)	(11.2)
Intersegment elimination | Petroleum
Segment Reporting Information [Line Items]
Net sales	2.1	2.3	4.2	4.6
Cost of product sold (exclusive of depreciation and amortization)	2	0.9	8.5	6.8
Intersegment elimination | Nitrogen Fertilizer
Segment Reporting Information [Line Items]
Net sales	2	0.9	8.5	6.8
Cost of product sold (exclusive of depreciation and amortization)	$ 2.1	$ 2.2	$ 3.9	$ 4.5

Business Segments (Details 2)

Business Segments (Details 2) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Segment Reporting Information [Line Items]
Net sales	$ 1,624.2	$ 2,540.3	$ 3,013.1	$ 4,987.8
Cost of product sold (exclusive of depreciation and amortization)	1,192.2	2,189	2,265.8	4,265.9
Direct operating expenses (exclusive of depreciation and amortization)	115.4	120.1	226.9	243.5
Depreciation and amortization	42.5	38.6	84.5	75.9
Operating income	274.2	164.6	410.8	348.1
Capital expenditures	41.2	53	86.7	114.9
Total assets	3,547.6		3,547.6		$ 3,462.5
Goodwill	41		41		41
Operating Segments | Petroleum
Segment Reporting Information [Line Items]
Net sales	1,547.5	2,466.3	2,852	4,841.7
Cost of product sold (exclusive of depreciation and amortization)	1,180.9	2,172.6	2,237.1	4,236
Direct operating expenses (exclusive of depreciation and amortization)	90.3	93.2	177.3	192.4
Depreciation and amortization	34.2	30.7	68.2	60.2
Operating income	250.8	151.9	360	316.5
Capital expenditures	36.4	47.4	78.1	105.3
Total assets	2,516.3		2,516.3		2,417.8
Goodwill	0		0		0
Operating Segments | Nitrogen Fertilizer
Segment Reporting Information [Line Items]
Net sales	80.8	77.2	173.9	157.5
Cost of product sold (exclusive of depreciation and amortization)	15.4	19.4	41.2	41.1
Direct operating expenses (exclusive of depreciation and amortization)	25.1	26.9	49.6	51.1
Depreciation and amortization	7	6.8	13.8	13.5
Operating income	28.7	18.8	60.2	41.9
Capital expenditures	3.4	4.1	6	7.5
Total assets	560		560		578.8
Goodwill	41		41		41
Intersegment elimination
Segment Reporting Information [Line Items]
Net sales	(4.1)	(3.2)	(12.8)	(11.4)
Cost of product sold (exclusive of depreciation and amortization)	(4.1)	(3)	(12.5)	(11.2)
Intersegment elimination | Petroleum
Segment Reporting Information [Line Items]
Net sales	2.1	2.3	4.2	4.6
Cost of product sold (exclusive of depreciation and amortization)	2	0.9	8.5	6.8
Intersegment elimination | Nitrogen Fertilizer
Segment Reporting Information [Line Items]
Net sales	2	0.9	8.5	6.8
Cost of product sold (exclusive of depreciation and amortization)	2.1	2.2	3.9	4.5
Other
Segment Reporting Information [Line Items]
Direct operating expenses (exclusive of depreciation and amortization)	0	0	0	0
Depreciation and amortization	1.3	1.1	2.5	2.2
Operating income	(5.3)	(6.1)	(9.4)	(10.3)
Capital expenditures	1.4	$ 1.5	2.6	$ 2.1
Total assets	471.3		471.3		465.9
Goodwill	$ 0		$ 0		$ 0

Subsequent Events (Details)

Subsequent Events (Details) - USD ($) $ / shares in Units, $ in Millions	Jul. 29, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Dividend
Dividends declared per share (in dollars per share)		$ 0.50	$ 0.50	$ 0.50	$ 0.75	$ 1	$ 1.50
Dividends declared						$ 86.8
IEP Energy LLC
Dividend
Ownership percentage held by controlling stockholder						82.00%
Subsequent event
Dividend
Dividends declared per share (in dollars per share)	$ 0.50
Dividends declared	$ 43.4
Subsequent event | CVR Partners, LP
Distribution
Declared distribution to limited partner (in dollars per share)	$ 0.39
Declared distribution to limited partner	$ 28.5
Expected proceeds from distribution	$ 15.2
Subsequent event | CVR Refining, LP
Distribution
Declared distribution to limited partner (in dollars per share)	$ 0.98
Declared distribution to limited partner	$ 144.6
Expected proceeds from distribution	95.4
Subsequent event | IEP Energy LLC
Dividend
Dividends declared	$ 35.6
Ownership percentage held by controlling stockholder	82.00%