View Filing Data

Document and Entity Information - USD ($)	12 Months Ended
Document and Entity Information - USD ($)	Dec. 31, 2012	Mar. 11, 2013	Jun. 29, 2012
Document and Entity Information
Entity Registrant Name	CVR ENERGY INC
Entity Central Index Key	0001376139
Document Type	10-K
Document Period End Date	Dec. 31, 2012
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Entity Public Float			$ 415,507,538
Entity Common Stock, Shares Outstanding		86,831,050
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	FY

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2012	Dec. 31, 2011
Current assets:
Cash and cash equivalents	$ 895,965	$ 388,328
Accounts receivable, net of allowance for doubtful accounts of $1,999 and $1,282, respectively	210,579	182,619
Inventories	528,070	636,221
Prepaid expenses and other current assets	54,486	117,509
Insurance receivable	1,260	1,939
Income tax receivable	4,134	30,167
Deferred income taxes	57,423
Due from parent	9,162
Total current assets	1,761,079	1,356,783
Property, plant, and equipment, net of accumulated depreciation	1,782,918	1,672,961
Intangible assets, net	284	312
Goodwill	40,969	40,969
Deferred financing costs, net	16,639	20,319
Insurance receivable	4,042	4,076
Other long-term assets	4,964	23,871
Total assets	3,610,895	3,119,291
Current liabilities:
Note payable and capital lease obligations	1,140	9,880
Accounts payable	440,113	466,559
Personnel accruals	51,154	20,849
Accrued taxes other than income taxes	36,693	35,147
Income taxes payable		2,400
Deferred income taxes		9,271
Deferred revenue	965	9,026
Other current liabilities	95,566	34,427
Total current liabilities	625,631	587,559
Long-term liabilities:
Long-term debt and capital lease obligations, net of current portion	897,078	853,903
Accrued environmental liabilities, net of current portion	1,597	1,459
Deferred income taxes	386,940	357,473
Other long-term liabilities	39,511	19,194
Total long-term liabilities	1,325,126	1,232,029
Commitments and contingencies
CVR stockholders' equity:
Common stock $0.01 par value per share, 350,000,000 shares authorized, 86,929,660 and 86,906,760 shares issued, respectively	869	869
Additional paid-in-capital	582,287	587,199
Retained earnings	945,460	566,855
Treasury stock, 98,610 as of December 31, 2012 and 2011, at cost	(2,303)	(2,303)
Accumulated other comprehensive loss, net of tax	(1,158)	(1,008)
Total CVR stockholders' equity	1,525,155	1,151,612
Noncontrolling interest	134,983	148,091
Total equity	1,660,138	1,299,703
Total liabilities and equity	$ 3,610,895	$ 3,119,291

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2012	Dec. 31, 2011
CONSOLIDATED BALANCE SHEETS
Accounts receivable, allowance for doubtful accounts (in dollars)	$ 1,999	$ 1,282
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	86,906,760
Treasury stock, shares	98,610	98,610

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
CONSOLIDATED STATEMENTS OF OPERATIONS
Net sales	$ 1,880,754	$ 2,409,624	$ 2,308,318	$ 1,968,631	$ 1,062,168	$ 1,351,964	$ 1,447,716	$ 1,167,265	$ 8,567,327	$ 5,029,113	$ 4,079,768
Operating costs and expenses:
Cost of product sold (exclusive of depreciation and amortization)	1,485,095	1,702,452	1,874,210	1,635,155	857,277	1,026,040	1,123,375	936,822	6,696,912	3,943,514	3,568,118
Direct operating expenses (exclusive of depreciation and amortization)	202,533	109,929	94,099	115,514	124,796	74,615	66,207	68,434	522,075	334,052	239,791
Insurance recovery - business interruption						(490)		(2,870)		(3,360)
Selling, general and administrative expenses (exclusive of depreciation and amortization)	35,641	30,390	72,047	45,342	28,973	17,584	18,171	33,262	183,420	97,990	92,034
Depreciation and amortization	32,594	33,109	32,190	32,112	24,242	22,025	22,043	22,011	130,005	90,321	86,761
Total operating costs and expenses	1,755,863	1,875,880	2,072,546	1,828,123	1,035,288	1,139,774	1,229,796	1,057,659	7,532,412	4,462,517	3,986,704
Operating income	124,891	533,744	235,772	140,508	26,880	212,190	217,920	109,606	1,034,915	566,596	93,064
Other income (expense):
Interest expense and other financing costs	(18,246)	(18,962)	(18,974)	(19,253)	(14,657)	(13,757)	(14,205)	(13,190)	(75,435)	(55,809)	(50,268)
Interest income	352	292	133	90	(89)	93	211	274	867	489	2,211
Realized gain (loss) on derivatives, net	(57,139)	(53,271)	(8,069)	(19,086)	11,116	66	484	(18,848)	(137,565)	(7,182)	(2,139)
Unrealized gain (loss) on derivatives, net	48,953	(115,699)	46,886	(128,167)	92,063	(9,991)	6,448	(3,258)	(148,027)	85,262	634
Loss on extinguishment of debt	(37,540)						(170)	(1,908)	(37,540)	(2,078)	(16,647)
Other income, net	166	(32)	709	117	124	243	246	231	960	844	1,218
Total other income (expense)	(63,454)	(187,672)	20,685	(166,299)	88,557	(23,346)	(6,986)	(36,699)	(396,740)	21,526	(64,991)
Income before income taxes	61,437	346,072	256,457	(25,791)	115,437	188,844	210,934	72,907	638,175	588,122	28,073
Income tax expense	16,613	127,618	91,099	(9,746)	37,103	68,603	76,738	27,119	225,584	209,563	13,783
Net income	44,824	218,454	165,358	(16,045)	78,334	120,241	134,196	45,788	412,591	378,559	14,290
Less: Net income attributable to noncontrolling interest	4,647	9,558	10,624	9,157	12,476	10,976	9,331		33,986	32,783
Net income attributable to CVR Energy Stockholders	$ 40,177	$ 208,896	$ 154,734	$ (25,202)	$ 65,858	$ 109,265	$ 124,865	$ 45,788	$ 378,605	$ 345,776	$ 14,290
Basic earnings per share (in dollars per share)	$ 0.46	$ 2.41	$ 1.78	$ (0.29)	$ 0.76	$ 1.26	$ 1.44	$ 0.53	$ 4.36	$ 4.00	$ 0.17
Diluted earnings per share (in dollars per share)	$ 0.46	$ 2.41	$ 1.75	$ (0.29)	$ 0.75	$ 1.25	$ 1.42	$ 0.52	$ 4.33	$ 3.94	$ 0.16
Weighted-average common shares outstanding:
Basic (in shares)	86,831,050	86,831,050	86,821,224	86,808,150	86,852,800	86,549,846	86,422,881	86,413,781	86,822,913	86,493,735	86,340,342
Diluted (in shares)	86,831,050	86,831,050	88,454,006	86,808,150	87,746,843	87,743,600	87,789,351	87,783,857	87,392,270	87,766,573	86,789,179

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
Net income	$ 412,591	$ 378,559	$ 14,290
Other comprehensive income (loss):
Unrealized gain (loss) on available-for-sale securities, net of tax of $5, $(1), and $2	7	(1)	2
Change in fair value of interest rate swap, net of tax of $(359), $(1,235) and $0	(963)	(1,899)
Reclass of gain/loss to income on settlement of interest rate swap, net of tax of $263, $109 and $0	696	167
Total other comprehensive income (loss)	(260)	(1,733)	2
Comprehensive income	412,331	376,826	14,292
Less: Comprehensive income attributable to noncontrolling interest	33,876	32,060
Comprehensive income attributable to CVR Energy Stockholders	$ 378,455	$ 344,766	$ 14,292

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
Unrealized gain (loss) on available-for-sale securities, tax	$ 5	$ (1)	$ 2
Change in fair value of interest rate swap, tax	(359)	(1,235)	0
Reclass of gain/loss to income on settlement of interest rate swap, tax	$ 263	$ 109	$ 0

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Thousands	Total	Total CVR Stockholders' Equity	$0.01 Par Value Common Stock	Additional Paid-In Capital	Retained Earnings	Treasury Stock	Accumulated Other Comprehensive Income (loss)	Noncontrolling Interest
Balance at Dec. 31, 2009	$ 664,415	$ 653,815	$ 863	$ 446,263	$ 206,789	$ (100)		$ 10,600
Balance (in shares) at Dec. 31, 2009			86,344,508
Increase (Decrease) in Stockholders' Equity
Share-based compensation	21,698	21,698		21,698
Excess tax benefit of share-based compensation	141	141		141
Issuance of common stock to Directors (in shares)			29,128
Issuance of stock from treasury				(231)		231
Purchase of treasury stock	(374)	(374)				(374)
Vesting of non-vested stock awards	1	1	$ 1
Vesting of non-vested stock awards (in shares)			62,036
Net income	14,290	14,290			14,290
Net unrealized gain (loss) on available-for-sale securities, net of tax	2	2					$ 2
Balance at Dec. 31, 2010	700,173	689,573	$ 864	467,871	221,079	(243)	2	10,600
Balance (in shares) at Dec. 31, 2010			86,435,672
Increase (Decrease) in Stockholders' Equity
Impact from the issuance of CVR Partners common units to the public	255,106	118,213		118,213				136,893
Purchase of Managing General Partnership Interest and incentive distribution rights	(26,001)	(15,401)		(15,401)				(10,600)
Distributions to noncontrolling interest holders	(21,630)							(21,630)
Share-based compensation	16,610	15,842		15,842				768
Excess tax benefit of share-based compensation	2,270	2,270		2,270
Issuance of common stock to Directors (in shares)			831
Issuance of stock from treasury				(1,475)		1,475
Purchase of treasury stock	(3,535)	(3,535)				(3,535)
Vesting of non-vested stock awards	5	5	$ 5
Vesting of non-vested stock awards (in shares)			470,257
Redemption of common units	(121)	(121)		(121)
Net income	378,559	345,776			345,776			32,783
Net unrealized gain (loss) on available-for-sale securities, net of tax	(1)	(1)					(1)
Net loss on interest rate swaps, net of tax	(1,732)	(1,009)					(1,009)	(723)
Balance at Dec. 31, 2011	1,299,703	1,151,612	$ 869	587,199	566,855	(2,303)	(1,008)	148,091
Balance (in shares) at Dec. 31, 2011			86,906,760
Increase (Decrease) in Stockholders' Equity
Distributions to noncontrolling interest holders	(48,814)							(48,814)
Share-based compensation	7,245	5,174		5,174				2,071
Modification and reclassification of equity share-based compensation award to liability based award	(9,924)	(9,924)		(9,924)
Modification and reclassification of subsidiary equity share-based compensation award to liability based award	(492)	(343)		(343)				(149)
Excess tax benefit of share-based compensation	(19)	(19)		(19)
Exercise of stock options	413	413		413
Exercise of stock options (in shares)			22,900
Redemption of common units	(305)	(213)		(213)				(92)
Net income	412,591	378,605			378,605			33,986
Net unrealized gain (loss) on available-for-sale securities, net of tax	7	7					7
Net loss on interest rate swaps, net of tax	(267)	(157)					(157)	(110)
Balance at Dec. 31, 2012	$ 1,660,138	$ 1,525,155	$ 869	$ 582,287	$ 945,460	$ (2,303)	$ (1,158)	$ 134,983
Balance (in shares) at Dec. 31, 2012			86,929,660

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Cash flows from operating activities:
Net income	$ 412,591	$ 378,559	$ 14,290
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	130,005	90,321	86,761
Allowance for doubtful accounts	717	561	(414)
Amortization of deferred financing costs	7,360	4,566	3,356
Amortization of original issue discount	513	512	356
Amortization of original issue premium	(2,848)	(148)
Deferred income taxes	(17,254)	62,688	(770)
Excess income tax benefit of share-based compensation	(19)	(2,270)	(141)
Loss on disposition of assets	1,556	3,452	3,536
Loss on extinguishment of debt	37,540	2,078	16,647
Share-based compensation	39,096	27,173	37,244
Unrealized (gain) loss on derivatives	148,027	(85,262)	(634)
Changes in assets and liabilities:
Accounts receivable	(28,132)	55,435	(34,026)
Inventories	108,021	(175,543)	27,666
Prepaid expenses and other current assets	(9,326)	(8,776)	(13,080)
Insurance receivable	(1,016)	(12,325)	(7,070)
Due from parent	(9,162)
Insurance proceeds for UAN reactor rupture			3,161
Business interruption insurance proceeds		3,360
Insurance proceeds on Coffeyville Refinery incident	703	4,000
Other long-term assets	342	(1,649)	105
Accounts payable	(54,445)	5,805	47,938
Accrued income taxes	23,633	(35,750)	28,841
Deferred revenue	(8,061)	(9,659)	8,396
Other current liabilities	(17,314)	(27,253)	3,588
Accrued environmental liabilities	138	(1,093)	(276)
Other long-term liabilities	(41)	(227)	(46)
Net cash provided by operating activities	762,624	278,555	225,428
Cash flows from investing activities:
Capital expenditures	(212,194)	(91,224)	(32,409)
Proceeds from sale of assets	467	57	37
Insurance proceeds for UAN reactor rupture	1,026	2,745	1,114
Acquisition of Gary-Williams		(585,987)
Net cash used in investing activities	(210,701)	(674,409)	(31,258)
Cash flows from financing activities:
Revolving debt payments			(60,000)
Revolving debt borrowings			60,000
Proceeds, gross of original issue premium on issuance of senior notes		206,000
Proceeds, net of original issue discount on issuance of senior notes			485,693
Proceeds, gross on issuance of CVR Refining's senior notes	500,000
Principal payments on long-term debt			(507,003)
Principal payments on senior secured notes	(478,679)	(2,700)
Payment of capital lease obligations	(1,054)	(4,897)	(193)
Payment of deferred financing costs	(12,793)	(15,133)	(8,775)
Repurchase of common stock		(3,535)	(215)
Excess tax benefit of share-based compensation	19	2,270	141
Deferred costs of CVR Partners' initial public offering			(674)
Deferred costs of CVR Refining's initial public offering	(3,073)
Purchase of managing general partner interest & incentive distribution rights		(26,001)
Proceeds from issuance of CVR Partners' long-term debt		125,000
Proceeds from CVR Partners initial public offering, net of offering costs		324,880
Distributions to noncontrolling interest holders	(48,814)	(21,630)
Exercise of stock options	413
Redemption of common units	(305)	(121)
Net cash provided by (used in) financing activities	(44,286)	584,133	(31,026)
Net increase in cash and cash equivalents	507,637	188,279	163,144
Cash and cash equivalents, beginning of period	388,328	200,049	36,905
Cash and cash equivalents, end of period	895,965	388,328	200,049
Supplemental disclosures
Cash paid for income taxes, net of refunds (received)	228,367	182,622	(14,285)
Cash paid for interest net of capitalized interest of $10,797, $3,877 and $1,827 for the years ended December 31, 2012, 2011 and 2010, respectively	73,886	45,230	45,352
Non-cash investing and financing activities:
Accrual of construction in progress additions	26,399	19,054	653
Assets acquired through capital lease			415
Reduction of proceeds for underwriting discount and financing costs	$ 7,500	$ 4,000	10,287
Receipt of marketable securities			$ 23

CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
CONSOLIDATED STATEMENTS OF CASH FLOWS
Capitalized interest	$ 10,797	$ 3,877	$ 1,827

Organization and History of the Company	12 Months Ended
Organization and History of the Company	Dec. 31, 2012
Organization and History of the Company
Organization and History of the Company	(1) Organization and History of the Company *Organization* The "Company" or "CVR" may be used to refer to CVR Energy, Inc. and, unless the context otherwise requires, its subsidiaries. Any references to the "Company" as of a date prior to October 16, 2007 (the date of the restructuring as further discussed in this Note) and subsequent to June 24, 2005 are to Coffeyville Acquisition LLC ("CALLC") and 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 ammonia and UAN. The Company's operations include two business segments: the petroleum segment and the nitrogen fertilizer segment. CALLC formed CVR Energy, Inc. as a wholly-owned subsidiary, incorporated in Delaware in September 2006, in order to effect an initial public offering. The initial public offering of CVR was consummated on October 26, 2007. In conjunction with the initial public offering, a restructuring occurred in which CVR became a direct or indirect owner of all of the subsidiaries of CALLC. Additionally, in connection with the initial public offering, CALLC was split into two entities: CALLC and Coffeyville Acquisition II LLC ("CALLC II"). CVR's common stock is listed on the NYSE under the symbol "CVI." As of December 31, 2010, approximately 40% of its outstanding shares were beneficially owned by GS Capital Partners V, L.P. and related entities ("GS" or "Goldman Sachs Funds") and Kelso Investment Associates VII, L.P. and related entities ("Kelso" or "Kelso Funds"). On February 8, 2011, GS and Kelso completed a registered public offering, whereby GS sold into the public market its remaining ownership interests in CVR and Kelso substantially reduced its interest in the Company. On May 26, 2011, Kelso completed a registered public offering, whereby Kelso sold into the public market its remaining ownership interest in CVR Energy. On May 7, 2012, Carl C. Icahn and certain of his affiliates (collectively, "Icahn") announced that they had acquired control of CVR pursuant to a tender offer for all of the Company's common stock. As of December 31, 2012, Icahn owned approximately 82% of all outstanding shares. Prior to Icahn's acquisition, the Company was owned 100% by the public. See further discussion in Note 3 ("Change of Control"). On December 15, 2011, CVR acquired all of the issued and outstanding shares of Gary-Williams Energy Corporation (subsequently converted to "WEC"). Assets acquired include a 70,000 bpd refinery in Wynnewood, Oklahoma and approximately 2.0 million barrels of company-owned storage tanks. See Note 4 ("Wynnewood Acquisition") for additional information regarding the Wynnewood Acquisition. *CVR Partners, LP* In conjunction with the consummation of CVR's initial public offering in 2007, CVR transferred Coffeyville Resources Nitrogen Fertilizers, LLC ("CRNF"), its nitrogen fertilizer business, to CVR Partners, which at the time was a newly created limited partnership, in exchange for a managing general partner interest ("managing GP interest"), a special general partner interest ("special GP interest," represented by special GP units) and a de minimis limited partner interest ("LP interest," represented by special LP units). CVR concurrently sold the managing GP interest, including the associated incentive distribution rights ("IDRs"), to Coffeyville Acquisition III LLC ("CALLC III"), an entity owned by its then controlling stockholders and senior management, for $10.6 million. On April 13, 2011, the Nitrogen Fertilizer Partnership completed its initial public offering of 22,080,000 common units (the "Nitrogen Fertilizer Partnership IPO") priced at $16.00 per unit. 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, the IDRs were purchased by the Nitrogen Fertilizer Partnership for $26.0 million and subsequently extinguished. In addition, the noncontrolling interest representing the managing GP interest was purchased by Coffeyville Resources, LLC ("CRLLC"), a subsidiary of CVR for a nominal amount. The consideration for the IDRs was paid to the owners of CALLC III, which included the Goldman Sachs Funds, the Kelso Funds and members of CVR senior management. In connection with the Nitrogen Fertilizer Partnership IPO, the Company recorded a noncontrolling interest for the common units sold into the public market which represented approximately a 30% interest in the Nitrogen Fertilizer Partnership at the time of the Nitrogen Fertilizer Partnership IPO. The Company's noncontrolling interest reflected on the consolidated balance sheet of CVR is impacted by the net income of, and distributions from the Nitrogen Fertilizer Partnership. At December 31, 2012, the Nitrogen Fertilizer Partnership had 73,065,143 common units outstanding, consisting of 22,145,143 common units owned by the public, representing approximately 30% of the total Nitrogen Fertilizer Partnership units and 50,920,000 common units owned by CRLLC, representing approximately 70% of the total Nitrogen Fertilizer Partnership 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 gross proceeds to the Nitrogen Fertilizer Partnership from the Nitrogen Fertilizer Partnership IPO were approximately $353.3 million, before giving effect to underwriting discounts and commissions and offering expenses. In connection with the Nitrogen Fertilizer Partnership IPO, the Nitrogen Fertilizer Partnership paid approximately $24.7 million in underwriting fees and incurred approximately $4.4 million of other offering costs. Approximately $5.7 million of the underwriting fee was paid to an affiliate of GS, which was acting as a joint book-running manager for the Nitrogen Fertilizer Partnership IPO. Until completion of CVR's February 2011 secondary offering, an affiliate of GS was a stockholder and related party of the Company. In connection with the Nitrogen Fertilizer Partnership IPO, the Nitrogen Fertilizer Partnership's limited partner interests were converted into common units, the Nitrogen Fertilizer Partnership's special general partner interests were converted into common units, and the Nitrogen Fertilizer Partnership's special general partner was merged with and into CRLLC, with CRLLC continuing as the surviving entity. In addition, as discussed above, the managing general partner sold its IDRs to the Nitrogen Fertilizer Partnership for $26.0 million, these interests were extinguished, and CALLC III sold the managing general partner to CRLLC for a nominal amount. As a result of the Nitrogen Fertilizer Partnership IPO, the Nitrogen Fertilizer Partnership has two types of partnership interests outstanding: • common units representing limited partner interests; and • a general partner interest, which is not entitled to any distributions, and which is held by the Nitrogen Fertilizer Partnership's general partner. The proceeds from the Nitrogen Fertilizer Partnership IPO were utilized as follows: • approximately $18.4 million was distributed to CRLLC to satisfy the Nitrogen Fertilizer Partnership's obligation to reimburse it for certain capital expenditures made on behalf of the nitrogen fertilizer business prior to October 24, 2007; • approximately $117.1 million was distributed to CRLLC through a special distribution in order to, among other things, fund the offer to purchase CRLLC's Old Notes required upon the consummation of the Nitrogen Fertilizer Partnership IPO; • $26.0 million was used by the Nitrogen Fertilizer Partnership to purchase and extinguish the IDR's owned by the general partner; • approximately $4.8 million was used to pay financing fees and associated legal and professional fees resulting from the Nitrogen Fertilizer Partnership's credit facility; and • the balance of the proceeds are being utilized by the Nitrogen Fertilizer Partnership for general partnership purposes, including the funding of the UAN expansion that will require an investment of approximately $130.0 million, excluding capitalized interest, of which approximately $106.1 million had been spent as of December 31, 2012. 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 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, CVR GP, LLC, 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 general partner is not elected by the common unitholders and is 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. On August 29, 2012, the Nitrogen Fertilizer Partnership's registration statement on Form S-3 was declared effective by the Securities and Exchange Commission ("SEC") enabling CVR Energy to offer and sell from time to time, in one or more public offerings or direct placements, up to 50,920,000 common units. *Formation and Initial Public Offering of CVR Refining, LP* In contemplation of an initial public offering, in September 2012, CRLLC formed CVR Refining Holdings, LLC ("CVR Refining Holdings"), which in turn formed CVR Refining GP, LLC. CVR Refining Holdings and CVR Refining GP, LLC formed the Refining Partnership, which issued them a 100% limited partnership interest and a non-economic general partner interest, respectively. CVR Refining Holdings formed CVR Refining, LLC ("Refining LLC") and CRLLC contributed its petroleum and logistics subsidiaries, as well as its equity interests in Coffeyville Finance Inc. ("Coffeyville Finance") to Refining LLC in October 2012. CVR Refining Holdings contributed Refining LLC to the Refining Partnership on December 31, 2012. On January 23, 2013, the Refining Partnership completed its initial public offering of its common units representing limited partner interests (the "Refining Partnership IPO"). See Note 22 ("Subsequent Events") for further discussion on Refining Partnership IPO.

- Definition

The entire disclosure for organization, consolidation and basis of presentation of financial statements disclosure.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 2-6
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Name Statement of Position (SOP)
-Publisher AICPA
-Number 94-6
-Paragraph 10
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Name FASB Interpretation (FIN)
-Publisher FASB
-Number 46R
-Paragraph 4, 14, 15
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6367646&loc=d3e18780-107790

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 10
-Section 45
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6359553&loc=d3e288-107754

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-URI http://asc.fasb.org/subtopic&trid=2197480

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6921930&loc=d3e5614-111684

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 915
-SubTopic 235
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6472506&loc=d3e38932-110933

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 852
-SubTopic 10
-URI http://asc.fasb.org/subtopic&trid=2209116

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 272
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6373374&loc=d3e70478-108055

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=6970148&loc=SL6228881-111685

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 10
-URI http://asc.fasb.org/subtopic&trid=2122150

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6359566&loc=d3e326-107755

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 720
-SubTopic 15
-URI http://asc.fasb.org/subtopic&trid=2122524

Reference 15: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 275
-SubTopic 10
-URI http://asc.fasb.org/subtopic&trid=2134480

Reference 16: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Staff Position (FSP)
-Number FAS140-4/FIN46(R)-8
-Paragraph 8, C1, C7
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2012

Summary of Significant Accounting Policies

Summary of Significant Accounting Policies

(2) Summary of Significant Accounting Policies

Principles of Consolidation

The accompanying CVR consolidated financial statements include the accounts of CVR Energy, Inc. and its majority-owned direct and indirect subsidiaries. All intercompany accounts and transactions have been eliminated in consolidation. The ownership interests of noncontrolling investors in its subsidiaries are recorded as noncontrolling interests.

Prior to the Nitrogen Fertilizer Partnership IPO, management had determined that the Nitrogen Fertilizer Partnership was a variable interest entity ("VIE") and as such evaluated the qualitative criteria under Accounting Standards Codification ("ASC") Topic 810-10 — Consolidations-Variable Interest Entities ("ASC 810-10"), to make a determination whether the Nitrogen Fertilizer Partnership should be consolidated on the Company's financial statements. ASC 810-10 requires the primary beneficiary of a variable interest entity's activities to consolidate the VIE. The primary beneficiary is identified as the enterprise that has a) the power to direct the activities of the VIE that most significantly impact the entity's economic performance and b) the obligation to absorb losses of the entity that could potentially be significant to the VIE or the right to receive benefits from the entity that could potentially be significant to the VIE. The standard requires an ongoing analysis to determine whether the variable interest gives rise to a controlling financial interest in the VIE. Based upon that evaluation, CVR's management had determined to consolidate the Nitrogen Fertilizer Partnership in CVR's consolidated financial statements for the periods presented prior to the Nitrogen Fertilizer Partnership IPO.

Subsequent to the Nitrogen Fertilizer Partnership IPO, the Nitrogen Fertilizer Partnership is no longer considered a VIE. The consolidation of the Nitrogen Fertilizer Partnership is based upon the fact that the general partner is owned by CRLLC, a wholly-owned subsidiary of CVR; and, therefore, CVR has the ability to control the activities of the Nitrogen Fertilizer Partnership. Additionally, 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. The limited rights of the common unitholders of the Nitrogen Fertilizer Partnership are demonstrated by the fact that the common unitholders have no right to elect the general partner or the general partner's directors on an annual or other continuing basis. The general partner can only be removed by a vote of the holders of at least 66²/3% of the outstanding common units, including any common units owned by the general partner and its affiliates (including CRLLC, a wholly-owned subsidiary of CVR) voting together as a single class. 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 officers of the general partner manage the day-to-day affairs of the business. The majority of the officers of the general partner are also officers of CVR. Based upon the general partner's role and rights as afforded by the partnership agreement and the limited rights afforded to the limited partners, the consolidated financial statements of CVR will include the assets, liabilities, cash flows, revenues and expenses of the Nitrogen Fertilizer Partnership.

Cash and Cash Equivalents

For purposes of the Consolidated Statements of Cash Flows, CVR considers all highly liquid money market accounts and debt instruments with original maturities of three months or less to be cash equivalents. Under the Company's cash management system, checks issued but not presented to banks frequently result in book overdraft balances for accounting purposes and are classified as accounts payable in the Consolidated Balance Sheet. The change in book overdrafts are reported as a component of operating cash flow for accounts payable as they do not represent bank overdrafts. The amount of these checks included in accounts payable as of December 31, 2012 and 2011 was $21.3 million and $13.4 million, respectively.

Accounts Receivable, net

CVR grants credit to its customers. Credit is extended based on an evaluation of a customer's financial condition; generally, collateral is not required. Accounts receivable are due on negotiated terms and are stated at amounts due from customers, net of an allowance for doubtful accounts. Accounts outstanding for longer than their contractual payment terms are considered past due. CVR determines its allowance for doubtful accounts by considering a number of factors, including the length of time trade accounts are past due, the customer's ability to pay its obligations to CVR, and the condition of the general economy and the industry as a whole. CVR writes off accounts receivable when they become uncollectible, and payments subsequently received on such receivables are credited to the allowance for doubtful accounts. Amounts collected on accounts receivable are included in net cash provided by operating activities in the Consolidated Statements of Cash Flows. At December 31, 2012 and 2011, no customers individually represented greater than 10% of the total accounts receivable balance. The largest concentration of credit for any one customer at December 31, 2012 and 2011 was approximately 9.8% and 9.4%, respectively, of the accounts receivable balance.

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. Inventories are valued at the lower of the first-in, first-out ("FIFO") cost, or market for fertilizer products, refined fuels and by-products for all periods presented. Refinery unfinished and finished products inventory values were determined using the ability-to-bear process, whereby raw materials and production costs are allocated to work-in-process and finished products based on their relative fair values. Other inventories, including other raw materials, spare parts, and supplies, are valued at the lower of moving-average cost, which approximates FIFO, or market. The cost of inventories includes inbound freight costs.

Prepaid Expenses and Other Current Assets

Prepaid expenses and other current assets consist of prepayments for crude oil deliveries to CVR's refineries for which title had not transferred, non-trade accounts receivable, current portions of prepaid insurance, deferred financing costs, derivative agreements and other general current assets.

Property, Plant, and Equipment

Additions to property, plant and equipment, including capitalized interest and certain costs allocable to construction and property purchases, are recorded at cost. Capitalized interest is added to any capital project over $1.0 million in cost which is expected to take more than six months to complete. Depreciation is computed using principally the straight-line method over the estimated useful lives of the various classes of depreciable assets. The lives used in computing depreciation for such assets are as follows:

Asset		Range of Useful Lives, in Years

Improvements to land		15 to 30
Buildings		20 to 30
Machinery and equipment		5 to 30
Automotive equipment		5 to 15
Furniture and fixtures		3 to 10
Railcars		25 to 40

Leasehold improvements and assets held under capital leases are depreciated or amortized on the straight-line method over the shorter of the contractual lease term or the estimated useful life of the asset. Expenditures for routine maintenance and repair costs are expensed when incurred. Such expenses are reported in direct operating expenses (exclusive of depreciation and amortization) in the Company's Consolidated Statements of Operations.

Goodwill and Intangible Assets

Goodwill represents the excess of the cost of an acquired entity over the fair value of the assets acquired less liabilities assumed. Intangible assets are assets that lack physical substance (excluding financial assets). Goodwill acquired in a business combination and intangible assets with indefinite useful lives are not amortized, and intangible assets with finite useful lives are amortized. Goodwill and intangible assets not subject to amortization are tested for impairment annually or more frequently if events or changes in circumstances indicate the asset might be impaired. CVR uses November 1 of each year as its annual valuation date for its goodwill impairment test. The Company performed its annual impairment review of goodwill for 2012, 2011 and 2010, which is attributable entirely to the nitrogen fertilizer segment and concluded there were no impairments. See Note 8 ("Goodwill") for further discussion.

Deferred Financing Costs, Underwriting and Original Issue Discount

Deferred financing costs associated with debt issuances are amortized to interest expense and other financing costs using the effective-interest method over the life of the debt. Additionally, the underwriting and original issue discount and premium related to debt issuances have been amortized to interest expense and other financing costs using the effective-interest method over the life of the debt. Deferred financing costs related to the Amended and Restated ABL Credit Facility and CRNF credit facility are amortized to interest expense and other financing costs using the straight-line method through the termination date of the respective facility.

Planned Major Maintenance Costs

The direct-expense method of accounting is used for planned major maintenance activities. Maintenance costs are recognized as expense when maintenance services are performed. Planned major maintenance activities for the nitrogen plant generally occur every two years. The required frequency of the maintenance varies by unit for the refineries, but generally is every four to five years.

The Coffeyville refinery completed the second phase of a two-phase turnaround project during the first quarter of 2012. The first phase was completed during the fourth quarter of 2011. Costs of approximately $21.2 million, $66.4 million and $1.2 million associated with the Coffeyville refinery's 2011/2012 turnaround were included in direct operating expenses (exclusive of depreciation and amortization) for the year ended December 31, 2012, 2011 and 2010, respectively. The Wynnewood refinery completed a turnaround in the fourth quarter of 2012. Costs of approximately $102.5 million were included in direct operating expenses (exclusive of depreciation and amortization) for the year ended December 31, 2012. During the year ended December 31, 2012 and 2010, the nitrogen fertilizer plant completed a scheduled major turnaround. Costs of approximately $4.8 million and $3.5 million, respectively, associated with the nitrogen fertilizer plant's turnaround were included in direct operating expenses (exclusive of depreciation and amortization) for the years ended December 31, 2012 and 2010.

Cost Classifications

Cost of product sold (exclusive of depreciation and amortization) includes cost of crude oil, other feedstocks, blendstocks, pet coke expense and freight and distribution expenses. Cost of product sold excludes depreciation and amortization of approximately $3.7 million, $2.5 million and $2.8 million for the years ended December 31, 2012, 2011 and 2010, 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 $124.1 million, $86.0 million and $81.8 million for the years ended December 31, 2012, 2011 and 2010, respectively.

Selling, general and administrative expenses (exclusive of depreciation and amortization) consist primarily of legal expenses, treasury, accounting, marketing, human resources and maintaining the corporate and administrative office in Texas and the administrative offices in Kansas and Oklahoma. Selling, general and administrative expenses exclude depreciation and amortization of approximately $2.2 million, $1.8 million and $2.1 million for the years ended December 31, 2012, 2011 and 2010, respectively.

Income Taxes

CVR accounts for income taxes utilizing the asset and liability approach. Under this method, deferred tax assets and liabilities are recognized for the anticipated future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis. Deferred amounts are measured using enacted tax rates expected to apply to taxable income in the year those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. See Note 11 ("Income Taxes") for further discussion.

Impairment of Long-Lived Assets

CVR accounts for long-lived assets in accordance with accounting standards issued by the Financial Accounting Standards Board ("FASB") regarding the treatment of the impairment or disposal of long-lived assets. As required by these standards, CVR reviews long-lived assets (excluding goodwill, intangible assets with indefinite lives, and deferred tax assets) for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to estimated undiscounted future net cash flows expected to be generated by the asset. If the carrying amount of an asset exceeds its estimated undiscounted future net cash flows, an impairment charge is recognized for the amount by which the carrying amount of the assets exceeds their fair value. Assets to be disposed of are reported at the lower of their carrying value or fair value less cost to sell.

Revenue Recognition

Revenues for products sold are recorded upon delivery of the products to customers, which is the point at which title is transferred, the customer has the assumed risk of loss, and when payment has been received or collection is reasonably assured. Deferred revenue represents customer prepayments under contracts to guarantee a price and supply of nitrogen fertilizer in quantities expected to be delivered in the next 12 months in the normal course of business. Excise and other taxes collected from customers and remitted to governmental authorities are not included in reported revenues.

Nonmonetary product exchanges and certain buy/sell crude oil transactions which are entered into in the normal course of business are included on a net cost basis in operating expenses on the Consolidated Statement of Operations.

The Company also engages in trading activities, whereby the Company enters into agreements to purchase and sell refined products with third parties. The Company acts as a principal in these transactions, taking title to the products in purchases from counterparties, and accepting the risks and rewards of ownership. The Company records revenue for the gross amount of the sales transactions, and records costs of purchases as an operating expense in the accompanying consolidated financial statements.

Shipping Costs

Pass-through finished goods delivery costs reimbursed by customers are reported in net sales, while an offsetting expense is included in cost of product sold (exclusive of depreciation and amortization).

Derivative Instruments and Fair Value of Financial Instruments

The Company uses futures contracts, options, and forward swap contracts primarily to reduce the exposure to changes in crude oil prices, finished goods product prices and interest rates and to provide economic hedges of inventory positions. These derivative instruments have not been designated as hedges for accounting purposes. Accordingly, these instruments are recorded in the Consolidated Balance Sheets at fair value, and each period's gain or loss is recorded as a component of gain (loss) on derivatives, net in accordance with standards issued by the FASB regarding the accounting for derivative instruments and hedging activities.

On June 30 and July 1, 2011, CRNF entered into 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. The aggregate notional amount covered under these agreements, which commenced on August 12, 2011 and expires on February 12, 2016, totals $62.5 million (split evenly between the two agreement dates). Under the terms of the interest rate swap agreement entered into on June 30, 2011, CRNF 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 will be 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 governed by the CRNF credit agreement. 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 accumulated other comprehensive income (loss) ("AOCI"), and will be reclassified into interest expense when the interest rate swap transaction affects earnings. The ineffective portion of the gain or loss will be recognized immediately in current interest expense.

Financial instruments consisting of cash and cash equivalents, accounts receivable, and accounts payable are carried at cost, which approximates fair value, as a result of the short-term nature of the instruments. See Note 12 ("Long-Term Debt") for further discussion of the extinguishment of the first priority credit facility long-term debt, issuance of First Lien Notes and Second Lien Notes, subsequent settlement of the First Lien Notes and issuance of the 2022 Notes. The First Lien Notes and Second Lien Notes were carried at the aggregate principal value less the unamortized original issue discount or premium. The 2022 Notes were issued at par value. See Note 12 ("Long-Term Debt") for the fair value of the debt securities.

Share-Based Compensation

CVR accounts for share-based compensation in accordance with standards issued by the FASB regarding the treatment of share-based compensation and historically utilized guidance regarding the accounting for share-based compensation granted to employees of an equity method investee in conjunction with allocated non-cash share-based compensation expense to CVR from CALLC, CALLC II and CALLC III. As a result of the sale of the shares of CVR stock owned by CALLC and CALLC II during the year ended December 31, 2011 and the sale of the general partner and IDRs in connection with the Nitrogen Fertilizer Partnership IPO, no further amounts will be allocated by CALLC, CALLC II or CALLC III.

Prior to the acquisition by Icahn and the related change of control, restricted shares, when granted, were valued at the closing market price of CVR Energy's common stock at the date of issuance and amortized to compensation expense on a straight-line basis over the vesting period of the stock. The change of control and related Transaction Agreement in May 2012 triggered a modification to outstanding awards under the LTIP. Pursuant to the Transaction Agreement, all restricted shares scheduled to vest in 2012 were converted to restricted stock units whereby the recipient received cash settlement of the offer price of $30.00 per share in cash plus one CCP upon vesting. Restricted shares scheduled to vest in 2013, 2014 and 2015 were converted to restricted stock units whereby the awards will be settled in cash upon vesting in an amount equal to the lesser of the offer price or the fair market value as determined at the most recent valuation date of December 31 of each year. For awards vesting subsequent to 2012, the awards will be remeasured at each subsequent reporting date until they vest. As a result of the modification of the awards, the classification changed from equity awards to liability awards.

In December 2012, restricted stock units were granted to certain employees of CVR. Each restricted stock unit represents the right to receive, upon vesting, a cash payment equal to (a) the fair market value of one share of the Company's common stock, plus (b) the cash value of all dividends declared and paid by the Company per share of the Company's common stock from the grant date to and including the vesting date. The awards, which are liability-classified, will be remeasured at each subsequent reporting date until they vest.

The Nitrogen Fertilizer Partnership grants certain awards out of its CVR Partners Long-Term Incentive Plan ("CVR Partners LTIP") to (1) employees of the Nitrogen Fertilizer Partnership and its subsidiaries, (2) employees of the general partner and (3) members of the board of directors of the general partner. In December 2012, the board of directors of the general partner of the Nitrogen Fertilizer Partnership approved an amendment to modify the terms of certain phantom unit awards previously granted to employees of the Nitrogen Fertilizer Partnership and its subsidiaries. Prior to the amendment, the phantom units, when granted, were valued at the closing market price of the Nitrogen Fertilizer Partnership's common units on the date of issuance and amortized to compensation expense on a straight-line basis over the vesting period of the units. The amendment triggered a modification to the awards by providing the phantom units would be settled in cash rather than common units of the Nitrogen Fertilizer Partnership. For awards vesting subsequent to amendment, the awards will be remeasured at each subsequent reporting date until they vest. As a result of the modification of the awards to employees of the Nitrogen Fertilizer Partnership, the classification changed from an equity-classified award to a liability-classified award.

Treasury Stock

The Company accounts for its treasury stock under the cost method. To date, all treasury stock purchased was for the purpose of satisfying minimum statutory tax withholdings due at the vesting of non-vested stock awards.

Environmental Matters

Liabilities related to future remediation costs of past environmental contamination of properties are recognized when the related costs are considered probable and can be reasonably estimated. Estimates of these costs are based upon currently available facts, internal and third party assessments of contamination, available remediation technology, site-specific costs, and currently enacted laws and regulations. In reporting environmental liabilities, no offset is made for potential recoveries. Loss contingency accruals, including those for environmental remediation, are subject to revision as further information develops or circumstances change and such accruals can take into account the legal liability of other parties. Environmental expenditures are capitalized at the time of the expenditure when such costs provide future economic benefits.

Use of Estimates

The consolidated financial statements have been prepared in conformity with U.S. generally accepted accounting principles, using management's best estimates and judgments where appropriate. These estimates and judgments affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ materially from these estimates and judgments.

Subsequent Events

The Company evaluated subsequent events, if any, that would require an adjustment to the Company's consolidated financial statements or require disclosure in the notes to the consolidated financial statements through the date of issuance of the consolidated financial statements. See Note 22 ("Subsequent Events") for further discussion.

New Accounting Pronouncements

In May 2011, the FASB issued Accounting Standards Update ("ASU") No. 2011-04, "Fair Value Measurements (Topic 820): Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and IFRS," ("ASU 2011-04"). ASU 2011-04 changed the wording used to describe many of the requirements in GAAP for measuring fair value and for disclosing information about fair value measurements to ensure consistency between GAAP and International Financial Reporting Standards ("IFRS"). ASU 2011-04 also expanded the disclosures for fair value measurements that are estimated using significant unobservable (Level 3) inputs. This new guidance was to be applied prospectively. The provisions of ASU 2011-04 were effective for interim and annual periods beginning after December 15, 2011. The Company adopted this ASU as of January 1, 2012. The adoption of this standard did not impact the consolidated financial statement footnote disclosures.

In June 2011, the FASB issued ASU No. 2011-05, "Comprehensive Income (ASC Topic 220): Presentation of Comprehensive Income," ("ASU 2011-05") which amends current comprehensive income guidance. This ASU eliminates the option to present the components of other comprehensive income as part of the statement of shareholders' equity. Instead, the Company must report comprehensive income in either a single continuous statement of comprehensive income which contains two sections, net income and other comprehensive income, or in two separate but consecutive statements. In December 2011, the FASB issued ASU No. 2011-12 which defers the requirement in ASU 2011-05 that companies present reclassification adjustments for each component of accumulated other comprehensive income in both net income and other comprehensive income on the face of the financial statements. Both amendments are effective for interim and annual periods beginning after December 15, 2011 and should be applied retrospectively. The Company adopted this standard as of January 1, 2012. The adoption of this standard expanded the Company's consolidated financial statements and related footnote disclosures.

In December 2011, the FASB issued ASU No. 2011-11, "Disclosures about Offsetting Assets and Liabilities" ("ASU 2011-11"). ASU 2011-11 retains the existing offsetting requirements and enhances the disclosure requirements to allow investors to better compare financial statements prepared under GAAP with those prepared under IFRS. On January 31, 2013, the FASB issued ASU No. 2013-04, "Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities" ("ASU 2013-04"). ASU 2013-04 limits the scope of the new balance sheet offsetting disclosures to derivatives, repurchase agreements and securities lending transactions. Both standards will be effective for interim and annual periods beginning January 1, 2013 and should be applied retrospectively. The Company believes these standards will expand its consolidated financial statement footnote disclosures.

In February 2013, the FASB issued ASU No. 2013-02, "Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income" ("ASU 2013-02"). ASU 2013-02 requires the Company to present information about reclassification adjustments from accumulated other comprehensive income in the financial statements in a single footnote or parenthetically on the face of the financial statements based on the source and the income statement line items affected by the reclassification. The standard will be effective for interim and annual periods beginning January 1, 2013 and should be applied prospectively. The Company believes the standard will expand its consolidated financial statement footnote disclosures.

Change of Control	12 Months Ended
Change of Control	Dec. 31, 2012
Change of Control
Change of Control	(3) Change of Control On April 18, 2012, IEP Energy LLC ("IEP Energy"), a majority owned subsidiary of Icahn Enterprises, L.P. ("Icahn Enterprises"), and certain other affiliates of Icahn Enterprises and Carl C. Icahn (collectively, the "IEP Parties"), entered into a Transaction Agreement (the "Transaction Agreement") with CVR, with respect to IEP Energy's tender offer (the "Offer") to purchase all of the issued and outstanding shares of CVR's common stock for a price of $30.00 per share in cash, without interest, less any applicable withholding taxes, plus one CCP, which represents the contractual right to receive an additional cash payment per share if a definitive agreement for the sale of CVR is executed on or prior to August 18, 2013 and such transaction closes. In May 2012, the IEP Parties announced that a majority of CVR's common stock had been acquired through the Offer. As a result of the shares tendered into the Offer and subsequent additional purchases, the IEP Parties owned approximately 82% of CVR's outstanding common stock at December 31, 2012. Pursuant to the Transaction Agreement, all restricted shares scheduled to vest in 2012 were converted to restricted stock units whereby the recipient received cash settlement of the offer price of $30.00 per share in cash plus one CCP upon vesting. Restricted shares scheduled to vest in 2013, 2014 and 2015 were converted to restricted stock units whereby the awards will be settled in cash upon vesting in an amount equal to the lesser of the offer price or the fair market value as determined at the most recent valuation date of December 31 of each year. Additional share-based compensation was incurred due to the modification of the awards and the fair value upon the date of modification. For awards vesting subsequent to 2012, the awards will be remeasured at each subsequent reporting date until they vest. See further discussion at Note 5 ("Share-Based Compensation").

Wynnewood Acquisition

12 Months Ended

Dec. 31, 2012

Wynnewood Acquisition

Wynnewood Acquisition

(4) Wynnewood Acquisition

On December 15, 2011, the Company completed the acquisition of all the issued and outstanding shares of WEC, including its two wholly-owned subsidiaries, (the "Wynnewood Acquisition"), for a preliminary purchase price of $592.3 million from The Gary-Williams Company, Inc. (the "Seller"). This consisted of $525.0 million in cash, plus approximately $65.8 million for working capital and approximately $1.5 million for a capital expenditure adjustment. The Wynnewood Acquisition was partially funded by proceeds received from the issuance of Additional First Lien Notes. See Note 12 ("Long-Term Debt") for further discussion of the issuance. The Wynnewood Acquisition was accounted for under the purchase method of accounting and, as such, the Company's results of operations on the Consolidated Statement of Operations for the year ended December 31, 2011 include WEC's revenues and loss before taxes of approximately $115.7 million and $2.3 million, respectively, for the period from December 16, 2011 through December 31, 2011.

WEC owned a 70,000 bpd refinery in Wynnewood, Oklahoma that includes approximately 2.0 million barrels of company-owned storage tanks. Located in the PADD II Group 3 distribution area, the Wynnewood refinery is a dual crude oil unit facility that processes a variety of crudes and produces high-value fuel products (including gasoline, ultra-low sulfur diesel, jet fuel and solvent) as well as liquefied petroleum gas and a variety of asphalts.

Purchase Price Allocation

Under the purchase method of accounting, the total preliminary purchase price was allocated to WEC's net tangible assets based on their fair values as of December 15, 2011. An independent appraisal of the net assets acquired was completed. The purchase price included a preliminary net working capital amount, which was finalized in the first quarter of 2012. At December 31, 2011, this difference was estimated at approximately $15.8 million and was recorded in prepaid expenses and other current assets in the Consolidated Balance Sheet.

In accordance with the Stock Purchase and Sale Agreement, (the "Purchase Agreement"), the Company provided a Post-Closing Statement to the Seller on February 13, 2012, which reflected the difference between the cash paid at closing for the estimated working capital as compared to the actual net working capital acquired. In March 2012, the preliminary purchase price was increased by $1.1 million, following settlement of the estimated cash paid for working capital in excess of actual working capital.

The following table, set forth below, displays the total final purchase price allocated to WEC's net tangible assets based on their fair values as of December 15, 2011 (in millions):


Cash and cash equivalents	$	6.3
Accounts receivable		159.0
Inventories		213.5
Prepaid expenses and other current assets		6.0
Property, plant and equipment		577.0
Accounts payable and accrued liabilities		(316.1	)
Long-term debt		(52.3	)

Total fair values of net assets acquired		593.4

Less: cash acquired		6.3

Total consideration transferred, net of cash acquired	$	587.1

Unaudited Pro Forma Financial Information

The summary pro forma condensed consolidated financial information presented below for the years ended December 31, 2010 and 2011 give effect to the Wynnewood Acquisition as if it had occurred at the beginning of the periods presented. The pro forma adjustments are based upon available information and certain assumptions that CVR believes are reasonable. The pro forma net income has been adjusted to reflect amortization and depreciation expense, interest expense, income tax expense and other accounting policy election differences, such as turnaround costs, as if those adjustments had been applied on January 1, 2010. The summary pro forma condensed consolidated financial information is for informational purposes only and does not purport to represent what the Company's consolidated results of operation actually would have been if the Wynnewood Acquisition had occurred at any date, and such data does not purport to project CVR's results of operations for any future period.

	Years Ended December 31,

	2011		2010
	(in millions) (unaudited)
Net sales	$	7,674.5	$	6,220.8
Net income		468.8		22.0

Acquisition Costs

For the years ended December 31, 2012 and 2011, CVR recognized approximately $11.0 million and $5.2 million, respectively, in transaction fees and integration expenses that are included in selling, general and administrative expense in the Consolidated Statement of Operations. In 2012, these costs primarily relate to accounting and other professional consulting fees incurred associated with post-closing transaction matters and continued integration of various processes, policies, technologies and systems of WEC. In 2011, these costs primarily relate to legal, accounting, initial purchaser discounts and commissions, and other professional fees incurred since the announcement of the Wynnewood Acquisition in November 2011. In addition, the Company entered into a commitment letter for a senior secured one-year bridge loan to ensure that financing would be available for the Wynnewood Acquisition in the event that the additional offering of First Lien Notes was not closed by the date of the Wynnewood Acquisition. The bridge loan was subsequently undrawn. A commitment fee and other third-party costs totaling $3.9 million are included in selling, general and administrative expenses associated with the undrawn bridge loan.

- Definition

The entire disclosure for a business combination (or series of individually immaterial business combinations) completed during the period, including background, timing, and recognized assets and liabilities. The disclosure may include leverage buyout transactions (as applicable).

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number 88-16
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141
-Paragraph 51, 52
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Appendix F
-Paragraph F4
-Subparagraph e

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Paragraph 67-73
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 30
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6911361&loc=d3e6927-128479

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=6972119&loc=d3e1490-128463

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 30
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=6911361&loc=d3e7008-128479

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=6972119&loc=d3e1500-128463

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 20
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6910749&loc=d3e4926-128472

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 20
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6910749&loc=d3e4922-128472

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 30
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6911361&loc=d3e6996-128479

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 10
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=6972119&loc=d3e1524-128463

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6972119&loc=d3e1392-128463

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 30
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6911361&loc=d3e7000-128479

Reference 15: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 20
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6910749&loc=d3e4845-128472

Reference 16: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 20
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=6910749&loc=d3e4934-128472

Reference 17: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=6972119&loc=d3e1497-128463

Reference 18: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6972119&loc=d3e1486-128463

Reference 19: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6972119&loc=d3e1383-128463

+ Details

Share-Based Compensation

12 Months Ended

Dec. 31, 2012

Share-Based Compensation

Share-Based Compensation

(5) Share-Based Compensation

Prior to CVR's initial public offering, CVR's subsidiaries were held and operated by CALLC, a limited liability company. Management of CVR held an equity interest in CALLC. CALLC issued non-voting override units to certain management members who held common units of CALLC. There were no required capital contributions for the override operating units. In connection with CVR's initial public offering in October 2007, CALLC was split into two entities: CALLC and CALLC II. In connection with this split, management's equity interest in CALLC, including both their common units and non-voting override units, was split so that half of management's equity interest was in CALLC and half was in CALLC II. In addition, in connection with the transfer of the managing general partner of the Nitrogen Fertilizer Partnership to CALLC III in October 2007, CALLC III issued non-voting override units to certain management members of CALLC III.

For the years ended December 31, 2011 and 2010, CVR, CALLC, CALLC II accounted for share-based compensation in accordance with standards issued by the FASB regarding the treatment of share-based compensation, as well as guidance regarding the accounting for share-based compensation granted to employees of an equity method investee. CVR was allocated non-cash share-based compensation expense from CALLC, CALLC II and CALLC III.

In February 2011, CALLC and CALLC II sold into the public market 11,759,023 shares and 15,113,254 shares, respectively, of CVR's common stock, pursuant to a registered public offering. In May 2011, CALLC sold into the public market its remaining shares of CVR's common stock, pursuant to a registered public offering.

As a result, CALLC and CALLC II ceased to be stockholders of the Company. Subsequent to CALLC II's divestiture of its ownership interest in the Company in February 2011 and CALLC's divestiture of its ownership interest in the Company in May 2011, no additional share-based compensation expense was incurred with respect to override units and phantom units. The final fair values of the override units of CALLC and CALLC II were derived based upon the values resulting from the proceeds received associated with each entity's respective divestiture of its ownership in CVR. These values were utilized to determine the related compensation expense for the unvested units.

The final fair value of the CALLC III override units was derived based upon the proceeds received by CVR GP, LLC upon the purchase of the IDR's by the Nitrogen Fertilizer Partnership. These proceeds were subsequently distributed to the owners of CALLC III, which included the override unitholders. This value was utilized to determine the related compensation expense for the unvested units. No additional share-based compensation was incurred with respect to override units of CALLC III subsequent to June 30, 2011 due to the complete distribution of the value prior to July 1, 2011.

The following table provides key information for the share-based compensation plans related to the override units of CALLC, CALLC II, and CALLC III.

						*Compensation Expense for the Year Ended December 31,

	Benchmark Value (per Unit)		Original Awards Issued			*Compensation Expense for the Year Ended December 31,
Award Type	Benchmark Value (per Unit)		Original Awards Issued		Grant Date	2011		2010
						(in thousands)
Override Operating Units	$	11.31		919,630	June 2005	$	—	$	338
Override Operating Units	$	34.72		72,492	December 2006		—		13
Override Value Units(a)	$	11.31		1,839,265	June 2005		4,960		17,586
Override Value Units(b)	$	34.72		144,966	December 2006		451		581
Override Units(c)	$	10.00		642,219	February 2008		184		772

					Total	$	5,595	$	19,290

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

Due to the divestiture of all ownership in CVR by CALLC and CALLC II and due to the purchase of IDRs from the general partner and the distribution to CALLC III, there is no associated unrecognized compensation expense as of December 31, 2012.

Valuation Assumptions

Significant assumptions used in the valuation of the Override Value Units (a) and (b) were as follows:

	(a) Override Value Units December 31,			(b) Override Value Units December 31,

	2010			2010
Estimated forfeiture rate		None			None
Derived service period		6 years			6 years
CVR Energy's closing stock price	$	15.18		$	15.18
Estimated fair value (per unit)	$	22.39		$	6.56
Marketability and minority interest discounts		20.0	%		20.0	%
Volatility		43.0	%		43.0	%

(c) Override Units — Using a probability-weighted expected return method that utilized CALLC III's cash flow projections which includes expected future earnings and the anticipated timing of IDRs, the estimated grant date fair value of the override units was approximately $3,000. As a non-contributing investor, CVR Energy also recognized income equal to the amount that its interest in the investee's net book value has increased (that is its percentage share of the contributed capital recognized by the investee) as a result of the disproportionate funding of the compensation cost. Of the 642,219 units issued, 109,720 were immediately vested upon issuance and the remaining units were subject to a forfeiture schedule. Significant assumptions used in the valuation were as follows:

		December 31,

		2010
Estimated forfeiture rate		None
Derived Service Period		Forfeiture schedule
Estimated fair value (per unit)		$2.60
Marketability and minority interest discounts		10.0%
Volatility		47.6%

Phantom Unit Plans

CVR, through CRLLC, had two Phantom Unit Appreciation Plans (the "Phantom Unit Plans") whereby directors, employees, and service providers were eligible to be awarded phantom points at the discretion of CVR's board of directors or its compensation committee. Holders of service phantom points received distributions when CALLC and CALLC II holders of override operating units received distributions. Holders of performance phantom points received distributions when CALLC and CALLC II holders of override value units receive distributions. In November 2010, through a registered offering of CVR common stock, CALLC and CALLC II sold into the public market common shares of CVR. As a result of this offering, the Company made a payment to phantom unit holders totaling approximately $3.6 million. As described above, in February 2011, CALLC and CALLC II completed a sale of CVR common stock into the public market pursuant to a registered public offering. As a result of this offering, the Company made a payment to phantom unitholders of approximately $20.1 million in the first quarter of 2011. As described above, in May 2011, CALLC completed an additional sale of CVR common stock into the public market pursuant to a registered public offering. As a result of this offering, the Company made a payment to phantom unitholders of approximately $9.2 million in the second quarter of 2011.

There was no compensation expense for the year ended December 31, 2012 related to the Phantom Unit Plans. Compensation expense for the years ended December 31, 2011 and 2010 related to the Phantom Unit Plans was approximately $10.6 million and $15.5 million, respectively. The Phantom Unit Plans were terminated in December 2012. Due to the divestiture of all ownership of CVR by CALLC and CALLC II and the associated payments to the holders of service and phantom performance points, there is no unrecognized compensation expense at December 31, 2012.

Using the Company's closing stock price at December 31, 2010, to determine the Company's equity value, through an independent valuation process, the service phantom interest and performance phantom interest were valued as follows:

	December 31, 2010

Service Phantom interest (per point)	$	14.64
Performance Phantom interest (per point)	$	21.25

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 December 31, 2012, only restricted shares of CVR common stock, restricted stock units and stock options had been granted under the LTIP. Individuals who are eligible to receive awards and grants under the LTIP include the Company's employees, officers, consultants, advisors and directors. A summary of the principal features of the LTIP is provided below.

Shares Available for Issuance. The LTIP authorizes 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. Whenever any outstanding award granted under the LTIP expires, is canceled, is settled in cash or is otherwise terminated for any reason without having been exercised or payment having been made in respect of the entire award, the number of shares available for issuance under the LTIP is increased by the number of shares previously allocable to the expired, canceled, settled or otherwise terminated portion of the award. As of December 31, 2012, 6,787,341 shares of common stock were available for issuance under the LTIP.

Restricted Shares

A summary of restricted stock and restricted stock units (collectively "restricted shares") grant activity and changes during the years ended December 31, 2012, 2011 and 2010 is presented below:

			Weighted- Average Grant-Date Fair Value		Aggregate Intrinsic Value

					(in thousands)
Non-vested at December 31, 2009	177,060		$	6.59	$	1,215

Granted	1,307,378			11.42
Vested	(113,457	)		9.79
Forfeited	(1,799	)		4.14

Non-vested at December 31, 2010	1,369,182		$	10.94	$	20,784

Granted	826,959			18.79
Vested	(557,355	)		11.83
Forfeited	(4,632	)		8.67

Non-vested at December 31, 2011	1,634,154		$	14.61	$	30,608

Granted	318,508			43.66
Vested	(740,811	)		13.59
Forfeited	(66,240	)		16.54

Non-vested at December 31, 2012	1,145,611		$	23.24	$	55,894

Through the LTIP, restricted shares have been granted to employees of the Company. Prior to the change of control as discussed in Note 3, the restricted shares, when granted, were historically valued at the closing market price of CVR's common stock on the date of issuance and amortized to compensation expense on a straight-line basis over the vesting period of the stock. These restricted shares generally vest over a three-year period.

The change of control and related Transaction Agreement discussed in Note 3 triggered a modification to outstanding awards under the LTIP. Pursuant to the Transaction Agreement, all restricted shares scheduled to vest in 2012 were converted to restricted stock units whereby the recipient received cash settlement of the offer price of $30.00 per share in cash plus one CCP upon vesting. Restricted shares scheduled to vest in 2013, 2014 and 2015 were converted to restricted stock units whereby the awards will be settled in cash upon vesting in an amount equal to the lesser of the offer price or the fair market value as determined at the most recent valuation date of December 31 of each year. Additional share-based compensation of approximately $12.4 million was incurred to revalue the awards upon modification. For awards vesting subsequent to 2012, the awards will be remeasured at each subsequent reporting date until they vest. As a result of the modification of the awards, the classification changed from equity awards to liability awards.

In December 2012, restricted stock units were granted to certain employees of CVR. The non-vested restricted stock units are expected to vest over three years on the basis of one-third of the award each year with the exception of awards granted to certain executive officers that vest over one year. Each restricted stock unit represents the right to receive, upon vesting, a cash payment equal to (a) the fair market value of one share of the Company's common stock, plus (b) the cash value of all dividends declared and paid by the Company per share of the Company's common stock from the grant date to and including the vesting date. The awards, which are liability-classified, will be remeasured at each subsequent reporting date until they vest.

Additionally, the Company approved a discretionary award of up to 62,920 restricted stock units to Mr. Lipinski, Chief Executive Officer and President of the Company, on or before December 31, 2013. This discretionary award remains subject to the review and recommendation of the Compensation Committee and approval of the board of directors of the Company, and is conditioned on Mr. Lipinski continuing to be employed by the Company through December 31, 2013. As such, no expense related to this discretionary award was recorded during the year ended December 31 2012. To the extent awarded, the discretionary award will vest immediately, and include dividend equivalent rights for the time period commencing on December 28, 2012 through the date of the award.

As of December 31, 2012, there was approximately $19.9 million of total unrecognized compensation cost related to non-vested restricted shares to be recognized over a weighted-average period of approximately one year. The aggregate fair value at the grant date of the shares that vested during the year ended December 31, 2012 was approximately $10.1 million. As of December 31, 2012, 2011 and 2010, unvested restricted shares outstanding had an aggregate fair value at grant date of approximately $26.6 million, $23.9 million and $15.0 million, respectively. Total compensation expense for the years ended December 31, 2012, 2011 and 2010 was approximately $36.9 million, $9.8 million and $2.4 million, respectively, related to the LTIP.

As of December 31, 2012, the Company has a liability of $19.5 million for unvested restricted share awards, which is recorded in personnel accruals on the Consolidated Balance Sheet. For the year ended December 31, 2012, the Company paid cash of $22.2 million to settle liability-classified awards upon vesting. No cash was paid to settle restricted share awards in 2011 and 2010.

Stock Options

Activity and price information regarding CVR's stock options granted are summarized as follows:

			Weighted- Average Exercise Price

Outstanding, December 31, 2009	32,350		$	19.08	8.21

Granted	—			—
Exercised	—			—
Forfeited	(3,149	)		21.61
Expired	(6,301	)		21.61

Outstanding, December 31, 2010	22,900		$	18.03	8.35

Granted	—			—
Exercised	—			—
Forfeited	—			—
Expired	—			—

Outstanding, December 31, 2011	22,900		$	18.03	7.35

Granted	—			—
Exercised	(22,900	)
Forfeited	—			—
Expired	—			—

Outstanding, December 31, 2012	—			—	—

There were no grants of stock options in 2012, 2011 and 2010. In May 2012, all outstanding stock options equaling an equivalent of 22,900 common shares were exercised. No unexercised stock options remain as of December 31, 2012. Total compensation expense for the years ended December 31, 2012, 2011 and 2010, related to the stock options was $0, $8,000 and $9,000, respectively.

Long-Term Incentive Plan — CVR Partners

In April 2011, the board of directors of its general partner adopted the CVR Partners, LP Long-Term Incentive Plan ("CVR Partners LTIP"). Individuals who are eligible to receive awards under the CVR Partners LTIP include (1) employees of the Nitrogen Fertilizer Partnership and its subsidiaries, (2) employees of its general partner, and (3) members of the board of directors of its general partner. The CVR Partners LTIP provides for the grant of options, unit appreciation rights, distribution equivalent rights, restricted units, phantom units and other unit-based awards, each in respect of common units. The maximum number of common units issuable under the CVR Partners' LTIP is 5,000,000.

Through the CVR Partners LTIP, phantom and common units have been awarded to employees of the Nitrogen Fertilizer Partnership and its general partner and to members of the board of directors of its general partner. In December 2012, the board of directors of its general partner of the Nitrogen Fertilizer Partnership approved an amendment to modify the terms of certain phantom unit awards previously granted to employees of the Nitrogen Fertilizer Partnership and its subsidiaries. Prior the amendment, the phantom units, when granted, were valued at the closing market price of the Nitrogen Fertilizer Partnership's common units on the date of issuance and amortized to compensation expense on a straight-line basis over the vesting period of the units. These units generally vest over a three-year period.

The amendment triggered a modification to the awards by providing the employee the phantom units would be settled in cash rather than common units of the Nitrogen Fertilizer Partnership. Additional share-based compensation incurred to revalue the unvested units upon modification was not material. For awards vesting subsequent to amendment, the awards will be remeasured at each subsequent reporting date until they vest. As a result of the modification of the awards to employees of the Nitrogen Fertilizer Partnership, the classification changed from an equity-classified award to a liability-classified award.

A summary of common units and phantom units (collectively "units") activity and changes under the CVR Partners LTIP during the years ended December 31, 2012 and 2011 is presented below:

			Weighted- Average Grant-Date Fair Value		Aggregate Intrinsic Value

					(in thousands)
Non-vested at April 13, 2011	—		$	—	$	—

Granted	200,647			22.34
Vested	(36,076	)		19.36
Forfeited	—			—

Non-vested at December 31, 2011	164,571		$	22.99	$	4,085

Granted	95,370			24.53
Vested	(58,129	)		23.08
Forfeited	—			—

Non-vested at December 31, 2012	201,812		$	23.70	$	5,094

As of December 31, 2012, there were 4,748,893 common units available for issuance under the CVR Partners LTIP.

Unrecognized compensation expense associated with the unvested phantom units as of December 31, 2012 was approximately $3.6 million and is expected to be recognized over a weighted-average period of 1.6 years. Compensation expense recorded for the years ended December 31, 2012 and 2011 related to the awards under the CVR Partners LTIP was approximately $2.2 million and $1.2 million, respectively. Compensation expense related to the awards issued to employees and members of the board of directors of its general partner under the CVR Partners LTIP has been recorded in selling, general and administrative expenses (exclusive of depreciation and amortization).

As of December 31, 2012, the Company has a liability of $0.2 million for unvested phantom unit awards related to employees of the Nitrogen Fertilizer Partnership and its subsidiaries for the CVR Partners LTIP, which is recorded in personnel accruals on the Consolidated Balance Sheet. For the year ended December 31, 2012, the Nitrogen Fertilizer Partnership paid cash of $0.3 million to settle liability-classified awards upon vesting.

- Definition

The entire disclosure for compensation-related costs for equity-based compensation, which may include disclosure of policies, compensation plan details, allocation of equity compensation, incentive distributions, equity-based arrangements to obtain goods and services, deferred compensation arrangements, employee stock ownership plan details and employee stock purchase plan details.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 123R
-Paragraph 64, 65, A240
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Statement of Position (SOP)
-Number 93-6
-Paragraph 53
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 14

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 50
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6406099&loc=d3e25284-112666

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6415400&loc=d3e5047-113901

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6415400&loc=d3e5070-113901

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=6415400&loc=d3e5444-113901

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 40
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6418621&loc=d3e17540-113929

+ Details

Inventories

12 Months Ended

Dec. 31, 2012

Inventories

Inventories

(6) Inventories

Inventories consisted of the following:

	December 31,

	2012		2011
	(in thousands)
Finished goods	$	275,169	$	323,315
Raw materials and precious metals		164,287		157,931
In-process inventories		42,767		115,372
Parts and supplies		45,847		39,603

	$	528,070	$	636,221

Property, Plant, and Equipment

12 Months Ended

Dec. 31, 2012

Property, Plant, and Equipment

Property, Plant, and Equipment

(7) Property, Plant, and Equipment

A summary of costs for property, plant, and equipment is as follows:

	December 31,

	2012		2011
	(in thousands)
Land and improvements	$	30,992	$	26,136
Buildings		40,617		37,289
Machinery and equipment		2,089,545		1,967,269
Automotive equipment		14,969		10,217
Furniture and fixtures		13,658		12,349
Leasehold improvements		2,483		1,445
Railcars		2,496		2,496
Construction in progress		189,291		94,085

		2,384,051		2,151,286
Accumulated depreciation		601,133		478,325

	$	1,782,918	$	1,672,961

Capitalized interest recognized as a reduction in interest expense for the years ended December 31, 2012, 2011 and 2010 totaled approximately $10.8 million, $3.9 million and $1.8 million, respectively. Land, building and equipment that are under a capital lease obligation had an original carrying value of approximately $25.1 million, $24.9 million and $5.2 million as of December 31, 2012, 2011 and 2010. Amortization of assets held under capital leases is included in depreciation expense.

- Definition

The entire disclosure for long-lived, physical assets that are used in the normal conduct of business to produce goods and services and not intended for resale. Examples include land, buildings, machinery and equipment, and other types of furniture and equipment including, but not limited to, office equipment, furniture and fixtures, and computer equipment and software. This disclosure may include property plant and equipment accounting policies and methodology, a schedule of property, plant and equipment gross, additions, deletions, transfers and other changes, depreciation, depletion and amortization expense, net, accumulated depreciation, depletion and amortization expense and useful lives, income statement disclosures, assets held for sale and public utility disclosures.

+ References + Details

Goodwill	12 Months Ended
Goodwill	Dec. 31, 2012
Goodwill.
Goodwill	(8) Goodwill Goodwill and other intangible assets accounting standards provide that goodwill and other intangible assets with indefinite lives are not amortized but instead are tested for impairment on an annual basis. In accordance with these standards, CVR completed its annual test for impairment of goodwill as of November 1 each year. CVR's annual review was performed only at the nitrogen fertilizer segment, as this is the only reporting unit that has goodwill recorded. For the years ended December 31, 2012, 2011 and 2010, the annual test of impairment indicated that the goodwill, attributable to the nitrogen fertilizer segment, was not impaired. As of December 31, 2012 and 2011, goodwill included on the Consolidated Balance Sheets totaled approximately $41.0 million. In testing goodwill for impairment, the Company applied the guidance in ASU 2011-08, which allows an alternative in certain situations that simplifies the impairment testing of goodwill. This guidance allows an entity the option to first perform a qualitative evaluation to determine whether it is necessary to perform the quantitative two-step goodwill impairment analysis. The nitrogen fertilizer segment began the qualitative assessment by analyzing the key drivers and other external factors that impact the business in an attempt to determine if any significant events, transactions or other factors had occurred, or were expected to occur, that would impair earnings or competitiveness; therefore impairing the fair value of the nitrogen fertilizer segment. The key drivers that were considered in the evaluation of the nitrogen fertilizer segment's fair value included: • general economic conditions; • fertilizer pricing; • input costs; and • customer outlook. After assessing the totality of events and circumstances, it was determined that it was not more likely than not that the fair value of the nitrogen fertilizer segment was less than the carrying value, and so it was not necessary to perform the two-step valuation.

Note Payable and Capital Lease Obligations	12 Months Ended
Note Payable and Capital Lease Obligations	Dec. 31, 2012
Note Payable and Capital Lease Obligations
Note Payable and Capital Lease Obligations	(9) Note Payable and Capital Lease Obligations The Company entered into an insurance premium finance agreement in November 2011 to finance a portion of the purchase of its 2011/2012 property insurance policies. The original balance of the note provided by the Company under such agreement was $9.9 million. The Company began to repay this note in equal installments commencing December 1, 2011. As of December 31, 2011, the Company owed approximately $8.8 million related to this note. There were no amounts outstanding as of December 31, 2012. From time to time the Company enters lease agreements for purposes of acquiring assets used in the normal course of business. The majority of the Company's leases are accounted for as operating leases. As a result of the Wynnewood Acquisition, the Company assumed two leases accounted for as capital leases related to the Magellan Pipeline Terminals, L.P. and Excel Pipeline LLC. The two arrangements have remaining terms of 201 and 202 months, respectively. As of December 31, 2012, the outstanding obligation associated with these arrangements totaled approximately $52.3 million, of which $51.2 million is included in long-term liabilities and $1.1 million is included in current liabilities in the Consolidated Balance Sheet. See Note 12 ("Long-Term Debt") for additional information.

Insurance Claims	12 Months Ended
Insurance Claims	Dec. 31, 2012
Insurance Claims
Insurance Claims	(10) Insurance Claims *Nitrogen Fertilizer Incident* On September 30, 2010, the nitrogen fertilizer plant experienced an interruption in operations due to a rupture of a high-pressure UAN vessel. Total costs due to the incident were approximately $11.7 million for repairs and maintenance and other associated costs; approximately $0.3 million, $0.9 million, and $10.5 million of these costs were recognized during the years ended December 31, 2012, 2011 and 2010, respectively, of which approximately $4.9 million were capitalized. The remaining amounts are included in direct operating expenses (exclusive of depreciation and amortization). Approximately $8.0 million of insurance proceeds were received under the property damage insurance claim related to this incident. Approximately $1.0 million, $2.7 million and $4.3 million of these proceeds were received during the years ended December 31, 2012, 2011 and 2010, respectively. The recording of the insurance proceeds resulted in a reduction of direct operating expenses (exclusive of depreciation and amortization) when received. Total proceeds received for insurance indemnity under the business interruption insurance policy related to the incident were approximately $3.4 million, which was reported in the year ended December 31, 2011. Business interruption insurance proceeds were included in the Consolidated Statements of Operations under Insurance recovery-business interruption. As of December 31, 2012, all property damage and business interruption claims had been fully settled with all claims closed. *Coffeyville Refinery Incidents* On December 28, 2010 the Coffeyville crude oil refinery experienced an equipment malfunction and small fire in connection with its fluid catalytic cracking unit ("FCCU"), which led to reduced crude oil throughput. The refinery returned to full operations on January 26, 2011. This interruption adversely impacted the production of refined products for the petroleum business in the first quarter of 2011. Total gross repair and other costs recorded related to the incident as of December 31, 2011 were approximately $8.0 million. No costs were recorded in 2012. The Company maintains property damage insurance policies which have an associated deductible of $2.5 million. As of December 31, 2012 and 2011, the Company had received $4.0 million in insurance proceeds. As of December 31, 2012 and 2011, the Company had recorded an insurance receivable related to the incident of approximately $1.3 million and $1.2 million, respectively. The insurance receivable is included in other current assets in the Consolidated Balance Sheet. The recording of the insurance proceeds and receivable resulted in a reduction of direct operating expenses (exclusive of depreciation and amortization). In February 2013, all insurance claims associated with the FCCU incident were fully settled and closed. Substantially all repair costs incurred in excess of the associated $2.5 million deductible were recovered by insurance. The Coffeyville crude oil refinery experienced a small fire at its continuous catalytic reformer ("CCR") in May 2011. Total gross repair and other costs related to the incident that were recorded during the year ended December 31, 2011 approximated $3.2 million. No costs were recorded in 2012. The Company anticipates that substantially all of the costs in excess of the $2.5 million deductible should be covered by insurance under its property damage insurance policy. Approximately $0.7 million of insurance proceeds were received for the year-ended December 31, 2012. As of December 31, 2011, the Company had recorded an insurance receivable of approximately $0.7 million. The insurance receivable is included in other current assets in the Consolidated Balance Sheet. The recording of the insurance receivable resulted in a reduction of direct operating expenses (exclusive of depreciation and amortization). As of December 31, 2012, all insurance claims associated with the fire at the CCR have been fully settled and closed. Substantially all repair costs incurred in excess of the associated $2.5 million deductible were recovered by insurance.

Income Taxes

12 Months Ended

Dec. 31, 2012

Income Taxes

Income Taxes

(11) Income Taxes

On May 19, 2012, CVR became a member of the consolidated federal tax group of American Entertainment Properties Corporation ("AEPC"), a wholly-owned subsidiary of Icahn Enterprises, 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 December 31, 2012, the Company has an overpayment of approximately $9.2 million for federal income taxes due to AEPC under the Tax Allocation Agreement, to be applied as a credit against the Company's estimated tax to be paid during the first quarter of 2013. This amount is recorded as due from affiliate in the Consolidated Balance Sheet. During the year ended December 31, 2012, the Company paid $150.7 million to AEPC under the Tax Allocation Agreement.

Income tax expense (benefit) is comprised of the following:

	Year Ended December 31,

	2012			2011		2010
	(in thousands)
Current
Federal	$	237,349		$	141,305	$	13,434
State		25,369			7,972		1,262

Total current		262,718			149,277		14,696

Deferred
Federal		(39,857	)		40,350		808
State		2,723			19,936		(1,721	)

Total deferred		(37,134	)		60,286		(913	)

Total income tax expense	$	225,584		$	209,563	$	13,783

The following is a reconciliation of total income tax expense (benefit) to income tax expense (benefit) computed by applying the statutory federal income tax rate (35%) to pretax income (loss):

	Year Ended December 31,

	2012			2011			2010
	(in thousands)
Tax computed at federal statutory rate	$	223,361		$	205,843		$	9,826
State income taxes, net of federal tax benefit		23,910			20,600			1,923
State tax incentives, net of federal tax expense		(5,355	)		(3,174	)		(2,382	)
Domestic production activities deduction		(16,467	)		(10,562	)		(2,025	)
Non-deductible share-based compensation		7,256			2,000			6,747
Non-deductible transaction costs		4,208			—			—
IRS interest (income)/expense, net		93			34			(814	)
Noncontrolling interest		(11,895	)		(11,474	)		—
Partnership basis adjustment		—			4,174			—
Other, net		473			2,122			508

Total income tax expense	$	225,584		$	209,563		$	13,783

The Company earns Kansas High Performance Incentive Program ("HPIP") credits for qualified business facility investment within the state of Kansas. CVR recognized a net income tax benefit of approximately $4.5 million, $3.2 million and $2.4 million on a credit of approximately $6.9 million, $4.9 million and $3.7 million for the years ended December 31, 2012, 2011 and 2010, respectively. The Company earns Oklahoma Investment credits for qualified manufacturing facility investment within the state of Oklahoma. CVR recognized a net income tax benefit of approximately $0.9 million on a credit of approximately $1.3 million for the year ended December 31, 2012.

The income tax effect of temporary differences that give rise to significant portions of the deferred income tax assets and deferred income tax liabilities at December 31, 2012 and 2011 are as follows:

	Year Ended December 31,

	2012			2011
	(in thousands)
Deferred income tax assets:
Allowance for doubtful accounts	$	751		$	475
Personnel accruals		12,925			6,437
Inventories		3,606			2,097
Unrealized derivative losses, net		26,206			—
Accrued expenses		2,080			101
State tax credit carryforward, net of federal expense		14,425			17,682
Contingent liabilities		10,845			—
Deferred financing		—			76
Other		2,050			2,695

Total gross deferred income tax assets		72,888			29,563

Deferred income tax liabilities:
Unrealized derivative gains, net		—			(31,990	)
Property, plant, and equipment		(282,219	)		(224,452	)
Investment in CVR Partners		(109,701	)		(134,920	)
Deferred financing		(1,046	)		—
Prepaid expenses		(9,439	)		(4,945	)

Total gross deferred income tax liabilities		(402,405	)		(396,307	)

Net deferred income tax liabilities	$	(329,517	)	$	(366,744	)

At December 31, 2012, CVR has Kansas state income tax credits of approximately $9.8 million, which are available to reduce future Kansas state regular income taxes. These credits, if not used, will expire in 2027 to 2028. Additionally, CVR has Oklahoma state income tax credits of approximately $3.8 million which are available to reduce future Oklahoma state regular income taxes. These credits have an indefinite life.

In assessing the realizability of deferred tax assets including credit carryforwards, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. Management considers the scheduled reversal of deferred tax liabilities, projected future taxable income, and tax planning strategies in making this assessment. Although realization is not assured, management believes that it is more likely than not that all of the deferred tax assets will be realized and thus, no valuation allowance was provided as of December 31, 2012 and 2011.

A reconciliation of the unrecognized tax benefits for the years ended December 31, 2012, 2011 and 2010 is as follows:

	Year Ended December 31,

	2012			2011		2010
	(in thousands)
Balance beginning of year	$	17,712		$	245	$	—
Increase based on prior year tax positions		4,755			—		245
Decrease based on prior year tax positions		(30	)		—		—
Increases and decrease in current year tax positions		14,705			17,467		—
Settlements		—			—		—
Reductions related to expirations of statute of limitations		(193	)		—		—

Balance end of year	$	36,949		$	17,712	$	245

Included in the balance of unrecognized tax benefits as of December 31, 2012 are $10.4 million of tax benefits that, if recognized, would affect the effective tax rate. The balance of unrecognized tax benefits as of December 2011 and 2010 include no amounts that, if recognized, would affect the effective tax rate.

CVR recognizes interest expense (income) and penalties on uncertain tax positions and income tax deficiencies (refunds) in income tax expense. CVR recognized interest expense of $0.5 million and penalties of $0.2 million during 2012. As of December 31, 2012, CVR has recognized a liability for interest of $0.5 million and penalties of approximately $0.2 million. CVR recognized in 2011 approximately $0.1 million of federal and state interest expense and penalties and in total, as of December 31, 2011, had recognized no liability for interest or penalties. CVR recognized interest income in 2010 of approximately $1.3 million related to 2005 and 2006 amended returns to carryback 2007 losses and in total, as of December 31, 2010, had recognized no liability for interest or penalties

CVR believes that it is reasonably possible that a decrease of up to $1.5 million in unrecognized tax benefits related to state exposures may be necessary within the coming year.

At December 31, 2012, the Company's tax filings are generally open to examination in the United States for the tax years ended December 31, 2009 through December 31, 2011 and in various individual states for the tax years ended December 31, 2008 through December 31, 2011.

- Definition

The entire disclosure for income taxes. Disclosures may include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph h
-Article 4

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 136, 172
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 43, 44, 45, 46, 47, 48, 49
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 15
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32718-109319

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 9
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(h))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32537-109319

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32559-109319

+ Details

Long-Term Debt

12 Months Ended

Dec. 31, 2012

Long-Term Debt

Long-Term Debt

(12) Long-Term Debt

Long-term debt was as follows:

	December 31,

	2012		2011
	(in thousands)
9.0% First Lien Senior Secured Notes, due 2015, net of unamortized premium of $9,003(1) as of December 31, 2011	$	—	$	456,053
10.875% Second Lien Senior Secured Notes, due 2017, net of unamortized discount of $1,840 and $2,159 as of December 31, 2012 and December 31, 2011, respectively(2)		220,910		220,591
6.5% Second Lien Senior Secured Notes, due 2022		500,000		—
CRNF credit facility		125,000		125,000
Capital lease obligations		51,168		52,259

Long-term debt	$	897,078	$	853,903

(1): Net unamortized premium of $9.0 million represents an unamortized discount of $0.9 million on the original First Lien Notes and a $9.9 million unamortized premium on the additional First Lien Notes issued in December 2011.
(2): All of the Second Lien Notes due 2017 were repaid as of February 2013.

Senior Secured Notes

On April 6, 2010, CRLLC and its then wholly-owned subsidiary, Coffeyville Finance completed a private offering of $275.0 million aggregate principal amount of 9.0% First Lien Senior Secured Notes due 2015 (the "First Lien Notes") and $225.0 million aggregate principal amount of 10.875% Second Lien Senior Secured Notes due 2017 (the "Second Lien Notes" and together with the First Lien Notes, the "Old Notes"). The First Lien Notes were issued at 99.511% of their principal amount and the Second Lien Notes were issued at 98.811% of their principal amount. The associated original issue discount of the Old Notes was amortized to interest expense and other financing costs over the respective terms of the Old Notes. CRLLC received total net proceeds from the offering of approximately $485.7 million, net of underwriter fees of $10.0 million and original issue discount of approximately $4.0 million and certain third-party fees of $287,000. In addition, CRLLC incurred additional third-party fees and expenses, totaling $3.6 million associated with the offering. Of the underwriters fees and third-party costs, approximately $76,000 and $30,000, respectively were immediately expensed and the remaining approximately $9.9 million and $3.9 million were deferred and amortized as interest expense using the effective-interest method. CRLLC applied the net proceeds to prepay all of the outstanding balance of its tranche D term loan under its first priority credit facility in an amount equal to approximately $453.3 million and to pay related fees and expenses. In accordance with the terms of its first priority credit facility, CRLLC paid a 2.0% premium totaling approximately $9.1 million to the lenders of the tranche D term loan upon the prepayment of the outstanding balance. This amount was recorded as a loss on extinguishment of debt during the second quarter of 2010. This premium was in addition to the 2.0% premium totaling $0.5 million paid in the first quarter of 2010 for voluntary unscheduled prepayments of $25.0 million on CRLLC's tranche D term loan. This premium was recognized as a loss on extinguishment of debt in the first quarter of 2010. As a result of the extinguishment, CRLLC wrote off $5.4 million of previously deferred financing costs.

On December 30, 2010, CRLLC made a voluntary unscheduled principal payment of approximately $27.5 million on the First Lien Notes that resulted in a premium payment of 3.0% and a partial write-off of previously deferred financing costs and unamortized original issue discount totaling approximately $1.6 million, which was recognized as a loss on extinguishment of debt in the Consolidated Statements of Operations for the year ended December 31, 2010. On May 16, 2011, CRLLC repurchased $2.7 million of the First Lien Notes at a purchase price of 103.0% of the outstanding principal amount. In connection with the repurchase, CRLLC wrote off a portion of previously deferred financing costs and unamortized original issue discount of approximately $89,000 which is recorded as a loss on extinguishment of debt for the year ended December 31, 2011. CRLLC also recorded additional losses on extinguishment of debt of $81,000 in connection with premiums paid for the repurchase.

On December 15, 2011, CRLLC and Coffeyville Finance issued an additional $200.0 million aggregate principal amount of 9.0% First Lien Senior Secured Notes due 2015 ("Additional First Lien Notes"). The Additional First Lien Notes were sold at an issue price of 105.0%, plus accrued interest from October 1, 2011 of $3.7 million. The associated original issue premium of $10.0 million for the Additional First Lien Notes has been amortized to interest expense and other financing costs over the term of the Additional First Lien Notes. The Additional First Lien Notes were offered in connection with CRLLC's acquisition of WEC. Proceeds of the Additional First Lien Notes were used to partially fund the Wynnewood Acquisition. On November 2, 2011, CRLLC entered into a commitment letter with certain lenders regarding a senior secured one year bridge loan ("the bridge loan"). CRLLC entered into the commitment letter in connection with ensuring that financing would be available for the Wynnewood Acquisition in the event that the offering of the Additional First Lien Notes was not closed by the date of closing of the Wynnewood Acquisition. Due to the closing of the issuance of the Additional First Lien Notes, the bridge loan was terminated. At the closing of the issuance of the Additional First Lien Notes and the Wynnewood Acquisition, a commitment fee was paid to the lenders who provided the commitment. Other third-party costs were incurred. All costs associated with the undrawn bridge loan were fully expensed. In conjunction with the issuance of the Additional First Lien Notes, CRLLC expanded the existing ABL credit facility (see "ABL Credit Facility" below for further discussion of the expansion and associated accounting treatment) and incurred a commitment fee and other third-party costs associated with the expansion.

CRLLC received total net proceeds from the offering of approximately $202.8 million, net of an underwriting discount of $4.0 million, bridge loan commitment and other associated fees of $3.3 million, an ABL commitment fee of $2.6 million, an Additional First Lien Notes structuring fee of $0.2 million, and certain third-party fees of $0.8 million. The related original issue premium and other debt issuance costs related to the Additional First Lien Notes were amortized over the remaining term of the First Lien Notes. Fees and third-party costs totaling $3.9 million related to the undrawn bridge loan were expensed for the year ended December 31, 2011 and are included in selling, general and administrative expenses (exclusive of depreciation and amortization) on the Consolidated Statements of Operations. Fees and third-party costs associated with the ABL credit facility expansion are being amortized over the remaining term of the facility.

The First Lien Notes were scheduled to mature on April 1, 2015, unless earlier redeemed or repurchased by the Issuers. See further discussion below related to the tender and redemption of all the outstanding First Lien Notes in the fourth quarter of 2012. The Second Lien Notes were scheduled to mature on April 1, 2017, unless earlier redeemed or repurchased by the issuers. The indenture governing the Second Lien Notes was satisfied and discharged on January 23, 2013. See Note 22 ("Subsequent Events").

Senior Notes Tender Offer

The completion of the initial public offering of the Nitrogen Fertilizer Partnership in April 2011 triggered a Fertilizer Business Event (as defined in the indentures governing the Notes). As a result, the issuers were required to offer to purchase a portion of the Old Notes from holders at a purchase price equal to 103.0% of the principal amount plus accrued and unpaid interest. A Fertilizer Business Event Offer was made on April 14, 2011 to purchase up to $100.0 million of the First Lien Notes and the Second Lien Notes in the second quarter of 2011. Approximately $2.7 million of the Old Notes were repurchased, including approximately $0.5 million of First Lien Notes and $2.2 million of Second Lien Notes.

The change of control discussed in Note 3 required CVR to make an offer to repurchase all of the Issuers' outstanding Old Notes; and on June 4, 2012, the Issuers offered to purchase all or any part of the Old Notes, at a cash purchase price of 101% of the aggregate principal amount of the Old Notes, plus accrued and unpaid interest, if any. The offer expired on July 5, 2012 with none of the outstanding Old Notes tendered.

2022 Senior Secured Notes

On October 23, 2012, Refining LLC and Coffeyville Finance completed a private offering of $500.0 million aggregate principal amount of 6.5% Second Lien Senior Secured Notes due 2022 (the "2022 Notes"). The 2022 Notes were issued at par. Refining LLC received approximately $492.5 million of cash proceeds, net of the underwriting fees, but before deducting other third-party fees and expenses associated with the offering. The 2022 Notes are secured by substantially the same assets that secured the outstanding Second Lien Notes, subject to exceptions, until such time that the outstanding Second Lien Notes were satisfied and discharged in full, which occurred on January 23, 2013.

A portion of the net proceeds from the offering of the 2022 Notes approximating $348.1 million were used to purchase approximately $323.0 million of the First Lien Notes pursuant to a tender offer and to settle accrued interest of approximately $1.8 million through October 23, 2012 and to pay related fees and expenses. Tendered notes were purchased at a premium of approximately $23.2 million in aggregate amount. CRLLC used the remaining proceeds from the offering to fund a completed and settled redemption of the remaining $124.1 million of outstanding First Lien Notes and to settle accrued interest of approximately $1.6 million through November 23, 2012. Redeemed notes were purchased at a premium of approximately $8.4 million in aggregate amount.

Previously deferred financing charges and unamortized original issuance premium related to the First Lien Notes totaled approximately $8.1 million and $6.3 million, respectively. As a result of these transactions, a loss on extinguishment of debt of $33.4 million was recorded in the Consolidated Statement of Operations in the fourth quarter of 2012, which includes the total premiums paid of $31.6 million and write-of off previously deferred financing charges of $8.1 million, partially offset by the write-off of the unamortized original issuance premium of $6.3 million.

The debt issuance costs of the 2022 Notes totaled approximately $8.7 million and will be amortized over the term of the 2022 Notes as interest expense using the effective-interest amortization method.

The 2022 Notes mature on November 1, 2022, unless earlier redeemed or repurchased by the issuers. Interest is payable on the 2022 Notes semi-annually on May 1 and November 1 of each year, commencing on May 1, 2013.

Included in other current liabilities on the Consolidated Balance Sheet is accrued interest payable totaling approximately $12.2 million and $16.1 million for the years ended December 31, 2012 and 2011, respectively, related to the Old Notes and 2022 Notes. Of the balance at December 31, 2011, $3.7 million represents cash received from the Additional First Lien Notes offering for accrued interest for the period October 1, 2011 through December 15, 2011. At December 31, 2012, the estimated fair value of the Second Lien Notes and 2022 Notes was approximately $243.0 million and $497.5 million, respectively. These estimates of fair value are Level 2 as they were determined by quotations obtained from a broker-dealer who makes a market in these and similar securities. The 2022 Notes are guaranteed by the Refining Partnership, Refining LLC and its existing domestic subsidiaries. Prior to the satisfaction and discharge of the Second Lien Notes, which occurred on January 23, 2013, the 2022 Notes were also guaranteed by CRLLC. CVR Energy, the Nitrogen Fertilizer Partnership and CRNF are not guarantors.

Asset-Backed (ABL) Credit Facility

On February 22, 2011, CRLLC entered into a $250.0 million asset-backed revolving credit agreement ("ABL credit facility") with a group of lenders including Deutsche Bank Trust Company Americas as collateral and administrative agent. The ABL credit facility was scheduled to mature in August 2015 and replaced the $150.0 million first priority credit facility which was terminated. The ABL credit facility was used to finance ongoing working capital, capital expenditures, letters of credit issuance and general needs of the Company and includes among other things, a letter of credit sublimit equal to 90% of the total facility commitment and a feature which permits an increase in borrowings of up to $250.0 million (in the aggregate), subject to additional lender commitments. On December 15, 2011, CRLLC entered into an incremental commitment agreement to increase the borrowings under the ABL credit facility to $400.0 million in the aggregate in connection with the Additional First Lien Notes issuance as discussed above. Terms of the ABL credit facility did not change as a result of the additional availability. On December 20, 2012, the ABL credit facility was amended and restated as further discussed below. There were no borrowings outstanding under the ABL credit facility as of December 31, 2011.

Borrowings under the facility bore interest based on a pricing grid determined by the previous quarter's excess availability. The pricing for borrowings under the ABL credit facility could range from LIBOR plus a margin of 2.75% to LIBOR plus 3.0% or the prime rate plus 1.75% to prime rate plus 2.0% for Base Rate Loans. Availability under the ABL credit facility was determined by a borrowing base formula supported primarily by cash and cash equivalents, certain accounts receivable and inventory.

In connection with the ABL credit facility, CRLLC incurred lender and other third-party costs of approximately $9.1 million for the year ended December 31, 2011. These costs were deferred and amortized to interest expense and other financing costs using a straight-line method over the term of the facility. In connection with termination of the first priority credit facility, a portion of the unamortized deferred financing costs associated with this facility, totaling approximately $1.9 million, was written off in the first quarter of 2011. In accordance with guidance provided by the FASB regarding the modification of revolving debt arrangements, the remaining approximately $0.8 million of unamortized deferred financing costs associated with the first priority credit facility were amortized over the term of the ABL credit facility.

In connection with the closing of the Nitrogen Fertilizer Partnership's initial public offering in April 2011, the Nitrogen Fertilizer Partnership and CRNF were released as guarantors of the ABL credit facility.

In connection with the change in control described in Note 3 above, CRLLC, Deutsche Bank Trust Company Americas, as Administrative Agent and Collateral Agent, the lenders and the other parties thereto, entered into a First Amendment to Credit Agreement effective as of May 7, 2012 (the "ABL First Amendment"), pursuant to which the parties agreed to exclude Icahn's acquisition of Shares from the definition of change of control as provided in the ABL credit facility. Absent the ABL First Amendment, the change in control of CVR described above would have triggered an event of default pursuant to the ABL credit facility.

Amended and Restated Asset Backed (ABL) Credit Facility

On December 20, 2012, CRLLC, CVR Refining, Refining LLC and each of the operating subsidiaries of Refining LLC (collectively, the "Credit Parties") entered into an amended and restated ABL credit agreement (the "Amended and Restated ABL Credit Facility") with a group of lenders and Wells Fargo Bank, National Association ("Wells Fargo"), as administrative agent and collateral agent. The Amended and Restated ABL Credit Facility replaced the ABL credit facility described above and is scheduled to mature on December 20, 2017. Under the amended and restated facility, the Refining Partnership assumed the Company's position as borrower and the Company's obligations under the facility upon the closing of the Refining Partnership's IPO on January 23, 2013, as further discussed in Note 22 ("Subsequent Events").

The Amended and Restated ABL Credit Facility is a senior secured asset based revolving credit facility in an aggregate principal amount of up to $400.0 million with an incremental facility, which permits an increase in borrowings of up to $200.0 million subject to additional lender commitments and certain other conditions. The proceeds of the loans may be used for capital expenditures and working capital and general corporate purposes of the Credit Parties and their subsidiaries. The Amended and Restated ABL Credit Facility provides for loans and letters of credit in an amount up to the aggregate availability under the facility, subject to meeting certain borrowing base conditions, with sub-limits of 10% of the total facility commitment for swingline loans and 90% of the total facility commitment for letters of credit.

Borrowings under the Amended and Restated ABL Credit Facility bear interest at either a base rate or LIBOR plus an applicable margin. The applicable margin is (i) (a) 1.75% for LIBOR borrowings and (b) 0.75% for prime rate borrowings, in each case if quarterly average excess availability exceeds 50% of the lesser of the borrowing base and the total commitments and (ii) (a) 2.00% for LIBOR borrowings and (b) 1.00% for prime rate borrowings, in each case if quarterly average excess availability is less than or equal to 50% of the lesser of the borrowing base and the total commitments. The Amended and Restated ABL Credit Facility also requires the payment of customary fees, including an unused line fee of (i) 0.40% if the daily average amount of loans and letters of credit outstanding is less than 50% of the lesser of the borrowing base and the total commitments and (ii) 0.30% if the daily average amount of loans and letters of credit outstanding is equal to or greater than 50% of the lesser of the borrowing base and the total commitments. The Refining Partnership will also be required to pay customary letter of credit fees equal to, for standby letters of credit, the applicable margin on LIBOR loans on the maximum amount available to be drawn under and, for commercial letters of credit, the applicable margin on LIBOR loans less 0.50% on the maximum amount available to be drawn under, and customary facing fees equal to 0.125% of the face amount of, each letter of credit.

The Amended and Restated ABL Credit Facility also contains customary covenants for a financing of this type that limit the ability of the Credit Parties and their respective subsidiaries to, among other things, incur liens, engage in a consolidation, merger, purchase or sale of assets, pay dividends, incur indebtedness, make advances, investment and loans, enter into affiliate transactions, issue equity interests, or create subsidiaries and unrestricted subsidiaries. The amended and restated facility also contains a fixed charge coverage ratio financial covenant, as defined under the facility. The Credit Parties were in compliance with the covenants of the Amended and Restated ABL Credit Facility as of December 31, 2012.

In connection with the Amended and Restated ABL Credit Facility, CRLLC and its subsidiaries incurred lender and other third-party costs of approximately $2.1 million for the year ended December 31, 2012. These costs will be deferred and amortized to interest expense and other financing costs using a straight-line method over the term of the amended facility. In connection with amendment of the ABL credit facility, a portion of the unamortized deferred financing costs associated with the ABL Credit Facility, totaling approximately $4.1 million, were written off in the fourth quarter of 2012. This expense is reflected on the Consolidated Statement of Operations as a loss on extinguishment of debt for the year ended December 31, 2012. In accordance with guidance provided by the FASB regarding the modification of revolving debt arrangements, the remaining approximately $2.8 million of unamortized deferred financing costs associated with the ABL credit facility will continue to be amortized over the term of the Amended and Restated ABL Credit Facility.

As of December 31, 2012, CRLLC and its subsidiaries had availability under the Amended and Restated ABL Credit Facility of $372.3 million and had letters of credit outstanding of approximately $27.7 million. There were no borrowings outstanding under the Amended and Restated ABL Credit Facility as of December 31, 2012.

Nitrogen Fertilizer Partnership Credit Facility

On April 13, 2011, CRNF, as borrower, and the Nitrogen Fertilizer Partnership, as guarantor, entered into a new credit facility with a group of lenders including Goldman Sachs Lending Partners LLC, as administrative and collateral agent. The credit facility includes a term loan facility of $125.0 million and a revolving credit facility of $25.0 million, which was undrawn as of December 31, 2012, with an uncommitted incremental facility of up to $50.0 million. No amounts were outstanding under the revolving credit facility at December 31, 2012. There is no scheduled amortization of the credit facility, which matures in April 2016. The carrying value of the Nitrogen Fertilizer Partnership's debt approximates fair value. The Nitrogen Fertilizer Partnership, upon the closing of the credit facility, made a special distribution of approximately $87.2 million to CRLLC, in order to, among other things, fund the offer to purchase CRLLC's senior secured notes required upon consummation of the Nitrogen Fertilizer Partnership IPO. The credit facility is used to finance on-going working capital, capital expenditures, letters of credit issuances and general needs of CRNF.

Borrowings under the credit facility bear interest based on a pricing grid determined by the trailing four quarter leverage ratio. The initial pricing for Eurodollar rate loans under the credit facility is the Eurodollar rate plus a margin of 3.50% or, for base rate loans, the prime rate plus 2.50%. Under its terms, the lenders under the credit facility were granted a perfected, first priority security interest (subject to certain customary exceptions) in substantially all of the assets of CRNF and the Nitrogen Fertilizer Partnership.

The credit facility requires the Nitrogen Fertilizer Partnership to maintain a minimum interest coverage ratio and a maximum leverage ratio and contains customary covenants for a financing of this type that limit, subject to certain exceptions, the incurrence of additional indebtedness or guarantees, the creation of liens on assets, the ability to dispose of assets, the ability to make restricted payments, investments and acquisitions, sale-leaseback transactions and 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 December 31, 2012, CRNF was in compliance with the covenants of the credit facility.

In connection with the credit facility, the Nitrogen Fertilizer Partnership incurred lender and other third-party costs of approximately $4.8 million for the year ended December 31, 2011. The costs associated with the credit facility have been deferred and are being amortized over the term of the credit facility as interest expense using the effective-interest amortization method for the term loan facility and the straight-line method for the revolving credit facility.

Deferred Financing Costs

For the years ended December 31, 2012, 2011 and 2010, amortization of deferred financing costs reported as interest expense and other financing costs totaled approximately $5.0 million, $4.9 million and $3.7 million, respectively.

Estimated amortization of deferred financing costs is as follows:

Year Ending December 31,	Deferred Financing

	(in thousands)
2013	$	3,687
2014		3,687
2015		3,687
2016		2,995
2017		2,047
Thereafter		4,215

	$	20,318

Capital Lease Obligations

As a result of the Wynnewood Acquisition, the Company acquired certain lease assets and assumed related capital lease obligations related to the Magellan Pipeline Terminals, L.P. and Excel Pipeline LLC. See Note 4 ("Wynnewood Acquisition") for further discussion. The underlying assets and related depreciation were included in property, plant and equipment. The capital lease relates to a sales-lease back agreement with Sunoco Pipeline, L.P. for its membership interest in the Excel Pipeline. The lease has 202 months remaining through September 2029. See Note 15 ("Commitments and Contingencies") for further discussion. The financing agreement relates to the Magellan Pipeline terminals, bulk terminal and loading facility. The lease has 201 months remaining and will expire in September 2029.

Future payments required under capital lease at December 31, 2012 are as follows:

	Capital Lease

	(in thousands)
2013	$	6,269
2014		6,311
2015		6,355
2016		6,411
2017		6,444
2018 and thereafter		76,756

Total future payments		108,546
Less: amount representing interest		56,287

Present value of future minimum payments		52,259
Less: current portion		1,091

Long-term portion	$	51,168

Earnings Per Share

12 Months Ended

Dec. 31, 2012

Earnings Per Share

Earnings Per Share

(13) Earnings Per Share

The computations of the basic and diluted earnings per share for the year ended December 31, 2012, 2011 and 2010 are as follows:

	For the Year Ended December 31,

	2012		2011		2010
	(in thousands, except share data)
Net income attributable to CVR Energy stockholders	$	378,605	$	345,776	$	14,290
Weighted-average number of shares of common stock outstanding		86,822,913		86,493,735		86,340,342
Effect of dilutive securities:
Non-vested restricted shares		567,166		1,268,471		448,837
Stock options		2,191		4,367		—

Weighted-average number of shares of common stock outstanding assuming dilution		87,392,270		87,766,573		86,789,179

Basic earnings per share	$	4.36	$	4.00	$	0.17
Diluted earnings per share	$	4.33	$	3.94	$	0.16

Outstanding stock options totaling 18,533 and 22,900 common shares were excluded from the diluted earnings per share calculation for the years ended December 31, 2011 and 2010, respectively, as they were antidilutive. No stock options were excluded from the diluted earnings per share calculation for the year ended December 31, 2012.

Benefit Plans	12 Months Ended
Benefit Plans	Dec. 31, 2012
Benefit Plans
Benefit Plans	(14) Benefit Plans As of December 31, 2012, CVR sponsored three defined-contribution 401(k) plans (the "Plans") for all employees. Participants in the Plans may elect to contribute up to 50% of their annual salaries and up to 100% of their annual income sharing. CVR matches up to 100% of the first 6% of the participant's contribution for the nonunion plan, 100% of the first 6% of the participant's contribution for the CVR union plan, and 80% on the first 5% of the participant's contributions plus a 3% employer contribution each pay period for the Wynnewood union plan. All Plans are administered by CVR and contributions for the union plans were determined in accordance with provisions of negotiated labor contracts. Participants in all Plans are immediately vested in their individual contributions. All Plans have a three year vesting schedule for CVR's matching funds and contain a provision to count service with any predecessor organization. CVR's contributions under the Plans were approximately $4.5 million, $2.3 million and $2.2 million for the years ended December 31, 2012, 2011 and 2010, respectively. The Wynnewood Union 401(k) Plan became effective with the Wynnewood Acquisition on December 16, 2011. Participants include all Wynnewood union employees. Wynnewood non-union employees are participants in the CVR 401(k) Plan. Beginning April 1, 2013, the Wynnewood Union 401(k) Plan will be merged into the CVR union plan, thereby decreasing the number of defined-contribution 401(k) plans from three to two. The CVR union plan retains its match of 100% of the first 6% of the participant's contribution. There were no changes to the nonunion plan.

Commitments and Contingencies

12 Months Ended

Dec. 31, 2012

Commitments and Contingencies

Commitments and Contingencies

(15) Commitments and Contingencies

The minimum required payments for CVR's operating lease agreements and unconditional purchase obligations are as follows:

Year Ending December 31,	Operating Leases		Unconditional Purchase Obligations(1)

	(in thousands)
2013	$	9,968	$	123,388
2014		7,804		110,011
2015		6,392		99,095
2016		5,545		92,053
2017		3,192		90,770
Thereafter		6,465		930,749

	$	39,366	$	1,446,066

(1): This amount includes approximately $1,007.8 million payable ratably over eighteen years pursuant to petroleum transportation service agreements between CRRM and TransCanada Keystone Pipeline, LP ("TransCanada"). Under the agreements, CRRM receives transportation of at least 25,000 barrels per day of crude oil with a delivery point at Cushing, Oklahoma for a term of twenty years on TransCanada's Keystone pipeline system. CRRM began receiving crude oil under the agreements in the first quarter of 2011.

CVR leases various equipment, including rail cars, and real properties under long-term operating leases expiring at various dates. For the years ended December 31, 2012, 2011 and 2010, lease expense totaled approximately $7.7 million, $5.1 million and $5.1 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. See below for further discussion and related expense of material long-term commitments.

CRNF has an agreement with the City of Coffeyville (the "City") pursuant to which it must make a series of future payments for the supply, generation and transmission of electricity and City margin based upon agreed upon rates. This agreement has an expiration of July 1, 2019. Effective August 2008 and through July 2010, the City began charging a higher rate for electricity than what had been agreed to in the contract. CRNF filed a lawsuit to have the contract enforced as written and to recover other damages. CRNF paid the higher rates under protest and subject to the lawsuit in order to obtain the electricity. In August 2010, the lawsuit was settled and CRNF received a return of funds totaling approximately $4.8 million. This return of funds was recorded in direct operating expenses (exclusive of depreciation and amortization) in the Consolidated Statements of Operations during the third quarter of 2010. In connection with the settlement, the electrical services agreement was amended.

CRRM has a Pipeline Construction, Operation and Transportation Commitment Agreement with Plains Pipeline, L.P. ("Plains Pipeline") pursuant to which Plains Pipeline constructed a crude oil pipeline from Cushing, Oklahoma to Caney, Kansas. The term of the agreement expires on March 1, 2025. Pursuant to the agreement, CRRM transports approximately 80,000 barrels per day of its crude oil requirements for the Coffeyville refinery at a fixed charge per barrel for the first five years of the agreement and for the remaining fifteen years of the agreement, CRRM must transport all of its non-gathered crude oil up to the capacity of the Plains Pipeline. The rate is subject to a Federal Energy Regulatory Commission ("FERC") tariff and is subject to change on an annual basis per the agreement. Lease expense associated with this agreement and included in cost of product sold (exclusive of depreciation and amortization) for the years ended December 31, 2012, 2011 and 2010, totaled approximately $12.5 million, $9.8 million and $11.4 million, respectively.

During 2005, CRRM entered into a Pipeage Contract with Mid-America Pipeline Company ("MAPL") pursuant to which CRRM agreed to ship a minimum quantity of NGLs on an inbound pipeline operated by MAPL between Conway, Kansas and Coffeyville, Kansas. Pursuant to the contract, CRRM is obligated to ship 2.0 million barrels ("Minimum Commitment") of NGLs per year at a fixed rate per barrel. All barrels above the Minimum Commitment are at a different fixed rate per barrel. The rates are subject to a tariff approved by the Kansas Corporation Commission ("KCC") and are subject to change throughout the term of this contract as ordered by the KCC. In 2012, CRRM and MAPL entered into new one-year pipeage contracts in connection with settlement of a dispute, as discussed in further detail below in the Litigation section. Lease expense associated with MAPL and included in cost of product sold (exclusive of depreciation and amortization) for the years ended December 31, 2012, 2011 and 2010, totaled approximately $3.5 million, $1.3 million and $2.4 million, respectively.

During 2004, CRRM entered into a Transportation Services Agreement with CCPS Transportation, LLC ("CCPS") pursuant to which CCPS reconfigured an existing pipeline ("Spearhead Pipeline") to transport Canadian sourced crude oil to Cushing, Oklahoma. The agreement expires March 1, 2016. Pursuant to the agreement and pursuant to options for increased capacity which CRRM has exercised, CRRM is obligated to pay an incentive tariff, which is a fixed rate per barrel for a minimum of 10,000 barrels per day. Lease expense associated with this agreement included in cost of product sold (exclusive of depreciation and amortization) for the years ended December 31, 2012, 2011 and 2010, totaled approximately $6.1 million, $8.4 million and $16.6 million, respectively.

During 2004, CRRM entered into a Terminalling Agreement with Plains Marketing, LP ("Plains") whereby CRRM has the exclusive storage rights for working storage, blending, and terminalling services at several Plains tanks in Cushing, Oklahoma. During 2007, CRRM entered into an Amended and Restated Terminalling Agreement with Plains that replaced the 2004 agreement. Pursuant to the Amended and Restated Terminalling Agreement, CRRM is obligated to pay fees on a minimum throughput volume commitment of 29.2 million barrels per year. Fees are subject to change annually based on changes in the Consumer Price Index ("CPI-U") and the Producer Price Index ("PPI-NG"). Expenses associated with this agreement, included in cost of product sold (exclusive of depreciation and amortization) for the years ended December 31, 2012, 2011 and 2010, totaled approximately $2.6 million, $2.4 million and $2.5 million, respectively. The original term of the Amended and Restated Terminalling Agreement expires December 31, 2014, but is subject to annual automatic extensions of one year beginning two years and one day following the effective date of the agreement, and successively every year thereafter unless either party elects not to extend the agreement. Concurrently with the above-described Amended and Restated Terminalling Agreement, CRRM entered into a separate Terminalling Agreement with Plains whereby CRRM has obtained additional exclusive storage rights for working storage and terminalling services at several Plains tanks in Cushing, Oklahoma. CRRM is obligated to pay Plains fees based on the storage capacity of the tanks involved, and such fees are subject to change annually based on changes in the Producer Price Index ("PPI-FG" and "PPI-NG"). Expenses associated with this Terminalling Agreement totaled approximately $3.4 million, $3.3 million and $3.1 million for 2012, 2011 and 2010, respectively. Select tanks covered by this agreement have been designated as delivery points for crude oil.

During 2005, CRNF entered into the Amended and Restated On-Site Product Supply Agreement with The BOC Group, Inc. (as predecessor in interest to Linde LLC). Pursuant to the agreement, which expires in 2020, CRNF is required to take as available and pay approximately $300,000 per month, which amount is subject to annual inflation adjustments, for the supply of oxygen and nitrogen to the fertilizer operation. Expenses associated with this agreement included in direct operating expenses (exclusive of depreciation and amortization) for the years ended December 31, 2012, 2011 and 2010, totaled approximately $4.3 million, $4.2 million and $4.7 million, respectively.

During 2006, CRRM entered into a Lease Storage Agreement with Enterprise Crude Pipeline LLC ("Enterprise") (as successor in interest to TEPPCO Crude Pipeline, L.P.) whereby CRRM leases tank capacity at Enterprise's Cushing tank farm in Cushing, Oklahoma. In September 2006, CRRM exercised its option to increase the shell capacity leased at the facility subject to this agreement. Pursuant to the agreement, CRRM is obligated to pay a monthly per barrel fee regardless of the number of barrels of crude oil actually stored at the leased facilities. Expenses associated with this agreement included in cost of product sold (exclusive of depreciation and amortization) for the years ended December 31, 2012, 2011 and 2010, totaled approximately $2.4 million, $1.8 million and $1.3 million, respectively. CRRM and Enterprise entered into a new five-year lease agreement for the above-described tank capacity effective March 1, 2011.

On October 10, 2008, the Company, through its wholly-owned subsidiaries entered into ten year agreements with Magellan Pipeline Company LP ("Magellan") that will allow for the transportation of an additional 20,000 barrels per day of refined fuels from the Company's Coffeyville, Kansas refinery and the storage of refined fuels on the Magellan system. CRRM commenced usage of the capacity lease in December 2009 and the storage of refined fuels commenced in April 2010. Expenses associated with this agreement included in cost of product sold (exclusive of depreciation and amortization) for the years ended December 31, 2012, 2011 and 2010, totaled $2.1 million, $0.7 million and $0.6 million, respectively.

On December 15, 2011, the Company consummated the Wynnewood Acquisition, which resulted in the assumption of certain agreements. The Company assumed a throughput and deficiency agreement with Excel Pipeline LLC that expires in 2020. Under the agreement, the Company is obligated to pay a tariff fee on the minimum daily volume of crude oil or else pay for any deficiencies. Expenses associated with the throughput and deficiency agreement totaled approximately $3.6 million for the year ended December 31, 2012.

CVR Partners entered into a pet coke supply agreement with HollyFrontier Corporation which became effective on March 1, 2012. The initial term ends in December 2013 and the agreement is subject to renewal. Expenses related to the pet coke supply agreement totaled approximately $6.0 million for the year ended December 31, 2012, which was recorded in cost of product sold (exclusive of depreciation and amortization).

Crude Oil Supply Agreement

On August 31, 2012, CRRM, and Vitol Inc. ("Vitol"), entered into an Amended and Restated Crude Oil Supply Agreement (the "Vitol Agreement"). The Vitol Agreement amends and restates the Crude Oil Supply Agreement between CRRM and Vitol dated March 30, 2011, as amended (the "Previous Supply Agreement"). Under the agreement, Vitol supplies the petroleum business with crude oil and intermediation logistics, which helps to reduce the Refining Partnership's inventory position and mitigate crude oil pricing risk.

The Vitol Agreement has an initial term commencing on August 31, 2012 and extending through December 31, 2014 (the "Initial Term"). Following the Initial Term, the Vitol Agreement will automatically renew for successive one-year terms (each such term, a "Renewal Term") unless either party provides the other with notice of nonrenewal at least 180 days prior to expiration of the Initial Term or any Renewal Term. Notwithstanding the foregoing, CRRM has an option to terminate the Vitol Agreement effective December 31, 2013 by providing written notice of termination to Vitol on or before May 1, 2013.

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 within the next year due to uncertainties inherent in litigation and settlement negotiations. In the opinion of management, the ultimate resolution of any other litigation matters is not expected to have a material adverse effect on the accompanying consolidated financial statements. There can be no assurance that management's beliefs or opinions with respect to liability for potential litigation matters are accurate.

Samson Resources Company, Samson Lone Star, LLC and Samson Contour Energy E&P, LLC (together, "Samson") filed fifteen lawsuits in federal and state courts in Oklahoma and two lawsuits in state courts in New Mexico against CRRM and other defendants between March 2009 and July 2009. In addition, in May 2010, separate groups of plaintiffs (the "Anstine and Arrow cases") filed two lawsuits against CRRM and other defendants in state court in Oklahoma and Kansas. All of the lawsuits filed in state court were removed to federal court. All of the lawsuits (except for the New Mexico suits, which remained in federal court in New Mexico) were then transferred to the Bankruptcy Court for the United States District Court for the District of Delaware, where the SemGroup bankruptcy resides. In March 2011, CRRM was dismissed without prejudice from the New Mexico suits. All of the lawsuits allege that Samson or other respective plaintiffs sold crude oil to a group of companies, which generally are known as SemCrude or SemGroup (collectively, "Sem"), which later declared bankruptcy and that Sem has not paid such plaintiffs for all of the crude oil purchased from Sem. The Samson lawsuits further allege that Sem sold some of the crude oil purchased from Samson to J. Aron & Company ("J. Aron") and that J. Aron sold some of this crude oil to CRRM. All of the lawsuits seek the same remedy, the imposition of a trust, an accounting and the return of crude oil or the proceeds therefrom. The amount of the plaintiffs' alleged claims is unknown since the price and amount of crude oil sold by the plaintiffs and eventually received by CRRM through Sem and J. Aron, if any, is unknown. CRRM timely paid for all crude oil purchased from J. Aron. On January 26, 2011, CRRM and J. Aron entered into an agreement whereby J. Aron agreed to indemnify and defend CRRM from any damage, out-of-pocket expense or loss in connection with any crude oil involved in the lawsuits which CRRM purchased through J. Aron, and J. Aron agreed to reimburse CRRM's prior attorney fees and out-of-pocket expenses in connection with the lawsuits. The indemnification agreement does not provide reimbursement for any damages that CRRM may be liable for in connection with any purchases it made directly from Sem. Samson and CRRM entered a stipulation of dismissal with respect to all of the Samson cases and the Samson cases were dismissed with prejudice on February 8, 2012. In February 2013, CRRM agreed to a settlement in the Anstine and Arrow cases. The settlement will not have a material adverse effect on the consolidated financial statements.

On June 21, 2012, Goldman, Sachs & Co. ("GS") filed suit against CVR in state court in New York, alleging that CVR failed to pay GS approximately $18.5 million in fees allegedly due to GS by CVR pursuant to an engagement letter dated March 21, 2012, which according to the allegations set forth in the complaint, provided that GS was engaged by CVR to assist CVR and the CVR board of directors in connection with a tender offer for CVR's stock, made by Carl C. Icahn and certain of his affiliates. CVR believes it has meritorious defenses and intends to vigorously defend against the suit. This amount has been fully accrued as of December 31, 2012.

On August 10, 2012, Deutsche Bank ("DB") filed suit against CVR in state court in New York, alleging that CVR failed to pay DB approximately $18.5 million in fees allegedly due to DB by CVR pursuant to an engagement letter dated March 23, 2012, which according to the allegations set forth in the complaint, provided that DB was engaged by CVR to assist CVR and the CVR board of directors in connection with a tender offer for CVR's stock made by Carl C. Icahn and certain of his affiliates. CVR believes it has meritorious defenses and intends to vigorously defend against the suit. This amount has been fully accrued as of December 31, 2012.

On December 17, 2012, Gary Community Investment Company, F/K/A The Gary-Williams Company and GWEC Holding Company, Inc. (referred to herein collectively as "Gary-Williams") filed a lawsuit in the Supreme Court of New York, New York County (Gary Community Investment Co. v. CVR Energy, Inc., No. 654401/12) against CVR and CRLLC (referred to collectively for purposes of this paragraph as "CVR"). The action arises out of claims relating to CVR's purchase of the Wynnewood, Oklahoma refinery pursuant to the Purchase and Sale Agreement entered into by the parties on November 2, 2011 (the "Purchase Agreement"). Specifically, CVR provided notice to Gary-Williams that it sought indemnification for various breaches of the Purchase Agreement and subsequently made a claim notice for payment of the entire escrow property pursuant to the Escrow Agreement by an among Gary-Williams, CRLLC, and the escrow agent, dated as of December 15, 2011. Gary-Williams, in its lawsuit, alleges that CVR breached the Purchase Agreement and the Escrow Agreement, and is seeking a declaratory judgment that CVR's claims are without any legal basis, damages in an unspecified amount, and release of the full amount of the escrow property to Gary-Williams.

CRNF received a ten year property tax abatement from Montgomery County, Kansas in connection with the construction of the nitrogen fertilizer plant that expired on December 31, 2007. In connection with the expiration of the abatement, the county reassessed CRNF's nitrogen fertilizer plant and classified the nitrogen fertilizer plant as almost entirely real property instead of almost entirely personal property. The reassessment resulted in an increase in CRNF's annual property tax expense by an average of approximately $10.7 million per year for the years ended December 31, 2008 and December 31, 2009, $11.7 million for the year ended December 31, 2010, $11.4 million for the year ended December 31, 2011, and $11.3 million for the year ended December 31, 2012. CRNF did not agree with the county's classification of its nitrogen fertilizer plant and protested the classification and resulting valuation for each of those years to the Kansas Court of Tax Appeals, or COTA. However, CRNF has fully accrued and paid the property taxes the county claims are owed for the years ended December 31, 2011, 2010, 2009 and 2008 and has estimated and accrued for property tax for the year ended December 31, 2012. The first payment in respect to CRNF's 2012 property taxes was paid in December 2012 and the second payment will be made in May 2013. This property tax expense is reflected as a direct operating expense in the financial results. In February, 2011, CRNF tried the 2008 case to COTA and in January 2012, COTA issued its decision holding that CRNF's fertilizer plant was almost entirely real property instead of almost entirely personal property. CRNF disagreed with the ruling and filed a petition for reconsideration with COTA (which was denied) and then filed an appeal to the Kansas Court of Appeals. CRNF also protested the valuation of the CRNF fertilizer plant for tax years 2009 through 2012, which cases remained pending before COTA. On February 25, 2013, Montgomery County and CRNF agreed to a settlement for tax years 2009 through 2012 which generally provides that the nitrogen fertilizer plant will be appraised at a total value of $35.0 million for tax years 2013 through 2016 which will lower CRNF's property taxes by about $10.5 million per year based on current mill levy rates. In addition, the settlement provides that Montgomery County will not challenge or contest CRNF's application for a ten year tax exemption pursuant to Kansas law for the UAN expansion and will support the approval of such application by COTA, the reviewing body for such exemption application. Finally, the settlement provides that CRNF will continue its appeal of the 2008 case and that Montgomery County will make a payment to CRNF for the 2008 tax year upon the final conclusion of the appeal, with the amount of the payment to depend on the appeal's outcome.

In addition, on February 25, 2013, CRRM also agreed to a settlement with Montgomery County that generally provides the Coffeyville refinery will be appraised at a total value of $160.0 million for tax years 2013 through 2016. This is a continuation of the settlement CRRM has had with Montgomery County for tax years 2007 through 2012.

On July 25, 2011, Mid-America Pipeline Company, LLC ("MAPL") filed an application with the Kansas Corporation Commission ("KCC") for the purpose of establishing rates ("New Rates") effective October 1, 2011 for pipeline transportation service on MAPL's liquids pipelines running between Conway, Kansas and Coffeyville, Kansas ("Inbound Line") and between Coffeyville, Kansas and El Dorado, Kansas ("Outbound Line"). CRRM ships refined fuels on the Outbound Line and CRRM ships natural gas liquids on the Inbound Line. On April 3, 2012, the parties entered into a Settlement Agreement which resolved the rate dispute both at the KCC and at the U.S. Federal Energy Regulatory Commission ("FERC"). Among other provisions, the Settlement Agreement provides for pipeage contracts to be entered into between the parties with rates ("Settlement Rates") to be established for an initial one year period. The Settlement Rates consist of two components, a base rate and a pipeline integrity cost recovery rate along with an annual take or pay minimum transportation quantity. The Settlement Rate on the Inbound Line was effective April 1, 2012 and the Settlement Rate on the Outbound Line was effective June 1, 2012. Prior to the end of the initial one year term of the pipeage contracts, and prior to the end of each annual period thereafter until the tenth anniversary of each of the two pipeage contracts, MAPL will provide its estimate of pipeline integrity costs for the upcoming annual period and CRRM may either agree to pay a rate for such upcoming annual period which includes a recovery rate component sufficient to collect such pipeline integrity costs for such upcoming annual period subject to true-up to actual costs at the end of the annual period. FERC rates will be the same as the KCC rates.

Flood, Crude Oil Discharge and Insurance

Crude oil was discharged from the Company's Coffeyville refinery on July 1, 2007, due to the short amount of time available to shut down and secure the refinery in preparation for the flood that occurred on June 30, 2007. In connection with the discharge, the Company received in May 2008, notices of claims from sixteen private claimants under the Oil Pollution Act ("OPA") in an aggregate amount of approximately $4.4 million (plus punitive damages). In August 2008, those claimants filed suit against the Company in the United States District Court for the District of Kansas in Wichita (the "Angleton Case"). In October 2009 and June 2010, companion cases to the Angleton Case were filed in the United States District Court for the District of Kansas in Wichita, seeking a total of approximately $3.2 million (plus punitive damages) for three additional plaintiffs as a result of the July 1, 2007 crude oil discharge. The Company has settled all of the claims with the plaintiffs from the Angleton Case and has settled all of the claims except for one of the plaintiffs from the companion cases. The settlements did not have a material adverse effect on the consolidated financial statements. The Company believes that the resolution of the remaining claim will not have a material adverse effect on the consolidated financial statements.

As a result of the crude oil discharge that occurred on July 1, 2007, the Company entered into an administrative order on consent (the "Consent Order") with the U.S. Environmental Protection Agency (the "EPA") on July 10, 2007. As set forth in the Consent Order, the EPA concluded that the discharge of crude oil from the Company's Coffeyville refinery caused an imminent and substantial threat to the public health and welfare. Pursuant to the Consent Order, the Company agreed to perform specified remedial actions to respond to the discharge of crude oil from the Company's refinery. The substantial majority of all required remedial actions were completed by January 31, 2009. The Company prepared and provided its final report to the EPA in January 2011 to satisfy the final requirement of the Consent Order. In April 2011, the EPA provided the Company with a notice of completion indicating that the Company has no continuing obligations under the Consent Order, while reserving its rights to recover oversight costs and penalties.

On October 25, 2010, the Company received a letter from the United States Coast Guard on behalf of the EPA seeking approximately $1.8 million in oversight cost reimbursement. The Company responded by asserting defenses to the Coast Guard's claim for oversight costs. On September 23, 2011, the United States Department of Justice ("DOJ"), acting on behalf of the EPA and the United States Coast Guard, filed suit against CRRM in the United States District Court for the District of Kansas seeking recovery from CRRM related to alleged non-compliance with the Clean Air Act's Risk Management Program ("RMP"), the Clean Water Act ("CWA") and the OPA. (See "Environmental, Health and Safety ("EHS") Matters" below.) CRRM has reached an agreement with the DOJ resolving its claims under CWA and OPA. The agreement is memorialized in a Consent Decree that was filed with the Court on February 12, 2013 (the "2013 Consent Decree"). CRRM will pay a civil penalty in the amount of $0.6 million for CWA violations and reimburse the Coast Guard for oversight costs under OPA in the amount of $1.7 million. The 2013 Consent Decree also requires CRRM to make upgrades to the Coffeyville refinery, including flood control measures, the installation of river modeling and monitoring procedures, the implementation of a wet weather plan and training employees on proper shutdown procedures during a flood. The parties also reached an agreement to settle DOJ's RMP claims, but DOJ has re-opened the negotiations. Any liability to DOJ related to the RMP claims is not expected to be material.

The Company is seeking insurance coverage for this release and for the ultimate costs for remediation and third-party property damage claims. On July 10, 2008, the Company filed a lawsuit in the United States District Court for the District of Kansas against certain of the Company's environmental insurance carriers requesting insurance coverage indemnification for the June/July 2007 flood and crude oil discharge losses. Each insurer reserved its rights under various policy exclusions and limitations and cited potential coverage defenses. Although the Court has now issued summary judgment opinions that eliminate the majority of the insurance defendants' reservations and defenses, the Company cannot be certain of the ultimate amount or timing of such recovery because of the difficulty inherent in projecting the ultimate resolution of the Company's claims. The Company has received $25.0 million of insurance proceeds under its primary environmental liability insurance policy which constitutes full payment to the Company of the primary pollution liability policy limit.

The lawsuit with the insurance carriers under the environmental policies remains the only unsettled lawsuit with the insurance carriers related to these events.

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

CRRM, Coffeyville Resources Crude Transportation, LLC ("CRCT"), Coffeyville Resources Terminal, LLC ("CRT"), Wynnewood Refining Company LLC ("WRC"), all of which are wholly-owned subsidiaries of the Refining Partnership and CRNF 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, CRCT, WRC and 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 include the current owner or operator of property where a release or threatened release occurred, any persons who owned or operated the property when the release occurred, and any persons who disposed of, or arranged for the transportation or disposal of, hazardous substances at a contaminated property. Liability under CERCLA is strict, and under certain circumstances, joint and several, so that any responsible party may be held liable for the entire cost of investigating and remediating the release of hazardous substances. Similarly, the OPA generally subjects owners and operators of facilities to strict, joint and several liability for all containment and clean-up costs, natural resource damages, and potential governmental oversight costs arising from oil spills into the waters of the United States.

CRRM and CRT have agreed to perform corrective actions at the Coffeyville, Kansas refinery and the now-closed Phillipsburg, Kansas terminal facility, pursuant to Administrative Orders on Consent issued under RCRA to address historical contamination by the prior owners (RCRA Docket No. VII-94-H-0020 and Docket No. VII-95-H-011, respectively). As of December 31, 2012 and 2011, environmental accruals of approximately $2.3 million and $1.9 million, respectively, were reflected in the Consolidated Balance Sheets for probable and estimated costs for remediation of environmental contamination under the RCRA Administrative Orders, for which approximately $0.7 million and $0.5 million, respectively, are included in other current liabilities. Accruals were determined based on an estimate of payment costs through 2031, for which the scope of remediation was arranged with the EPA, and were discounted at the appropriate risk free rates at December 31, 2012 and 2011, respectively. The accruals include estimated closure and post-closure costs of approximately $0.8 million and $0.9 million for two landfills at December 31, 2012 and 2011, respectively. The estimated future payments for these required obligations are as follows:

Year Ending December 31,	Amount

	(in thousands)
2013	$	724
2014		334
2015		184
2016		127
2017		109
Thereafter		1,056

Undiscounted total		2,534
Less amounts representing interest at 1.47%		210

Accrued environmental liabilities at December 31, 2012	$	2,324

Management periodically reviews and, as appropriate, revises its environmental accruals. Based on current information and regulatory requirements, management believes that the accruals established for environmental expenditures are adequate.

CRRM, 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, 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.

In 2007, the EPA promulgated the Mobile Source Air Toxic II ("MSAT II") rule that requires the reduction of benzene in gasoline by 2011. CRRM and WRC are considered to be small refiners under the MSAT II rule and compliance with the rule is extended until 2015 for small refiners. However, the change in control resulting from the Icahn Enterprises acquisition in 2012 triggered the loss of small refiner status. Accordingly, the MSAT II projects have been accelerated by three months. Capital expenditures to comply with the rule are expected to be approximately $59.0 million for CRRM and $94.0 million for WRC.

The petroleum business is subject to the Renewable Fuel Standard ("RFS") which requires refiners to blend "renewable fuels" in with their transportation fuels or purchase renewable energy credits, known as renewable identification numbers ("RINs") in lieu of blending. The EPA is required to determine and publish the applicable annual renewable fuel percentage standards for each compliance year by November 30 for the forthcoming year. The percentage standards represent the ratio of renewable fuel volume to gasoline and diesel volume. In 2012, about 9% of all fuel used was required to be "renewable fuel." About 9.6% of all transportation fuel is required to be "renewable fuel" in 2013. Due to mandates in the RFS requiring increasing volumes of renewable fuels to replace petroleum products in the U.S. motor fuel market, there may be a decrease in demand for petroleum products. The petroleum business currently purchases RINs for some fuel categories on the open market as well as waiver credits for cellulosic biofuels from the EPA, in order to comply with RFS. Beginning in 2011, the Coffeyville refinery was required to blend renewable fuels into its gasoline and diesel fuel or purchase RINs in lieu of blending. The Wynnewood refinery is required to comply beginning in 2013. In the future, the petroleum business likely will be required to purchase additional RINs on the open market or waiver credits from the EPA to comply with RFS. The petroleum business cannot predict the future prices of RINs or waiver credits, but the costs to obtain the necessary number of RINs and waiver credits could likely be material. Additionally, the Coffeyville and Wynnewood refineries may be impacted by increased operating expenses and production costs to meet the mandated renewable fuel volumes to the extent that these increased costs cannot be passed on to the consumers.

The EPA is expected to propose "Tier 3" gasoline sulfur standards in 2013. If the EPA were to propose a standard at the level currently being discussed in the pre-proposal phase by the EPA, CRRM will need to make capital expenditures and install controls in order to meet the anticipated new standard. It is not anticipated that the Wynnewood refinery would require additional controls or capital expenditures to meet the anticipated new standard. The Company does not believe that costs associated with the EPA's proposed Tier 3 rule will be material.

In March 2004, CRRM and CRT entered into a Consent Decree (the "2004 Consent Decree") with the EPA and the Kansas Department of Health and Environment (the "KDHE") to resolve air compliance concerns raised by the EPA and KDHE related to Farmland Industries Inc.'s prior ownership and operation of the Coffeyville crude oil refinery and the now-closed Phillipsburg terminal facilities. Under the 2004 Consent Decree, CRRM agreed to install controls to reduce emissions of sulfur dioxide, nitrogen oxides and particulate matter from its FCCU by January 1, 2011. In addition, pursuant to the 2004 Consent Decree, CRRM and CRT assumed clean-up obligations at the Coffeyville refinery and the now-closed Phillipsburg terminal facilities.

In March 2012, CRRM entered into a "Second Consent Decree" with the EPA, which replaces the 2004 Consent Decree, as amended (other than certain financial assurance provisions associated with corrective action at the refinery and terminal under RCRA). The Second Consent Decree gives CRRM more time to install the FCCU controls from the 2004 Consent Decree and expands the scope of the settlement so that it is now considered a "global settlement" under the EPA's "National Petroleum Refining Initiative." Under the National Petroleum Refining Initiative, the EPA identified industry-wide Non-compliance with four "marquee" issues under the Clean Air Act: New Source Review, Flaring, Leak Detection and Repair, and Benzene Waste Operations NESHAP. The National Petroleum Refining Initiative has resulted in most U.S. refineries (representing more than 90% of the US refining capacity) entering into consent decrees imposing civil penalties and requiring the installation of pollution control equipment and enhanced operating procedures. Under the Second Consent Decree, the Company was required to pay a civil penalty of approximately $0.7 million and complete the installation of FCCU controls required under the 2004 Consent Decree, add controls to certain heaters and boilers and enhance certain work practices relating to wastewater and fugitive emissions. The remaining costs of complying with the Second Consent Decree are expected to be approximately $41.0 million, of which approximately $39.0 million is expected to be capital expenditures. CRRM also agreed to complete a voluntary environmental project that will reduce air emissions and conserve water at an estimated cost of approximately $1.2 million. The incremental capital expenditures associated with the Second Consent Decree will not be material and will be limited primarily to the retrofit and replacement of heaters and boilers over a five to seven year timeframe. The Second Consent Decree was entered by the U.S. District Court for the District of Kansas on April 19, 2012.

WRC's refinery has not entered into a global settlement with the EPA and the Oklahoma Department of Environmental Quality (the "ODEQ") under the National Petroleum Refining Initiative, although it had discussions with the EPA and the ODEQ about doing so. Instead, WRC entered into a Consent Order with the ODEQ in August 2011 (the "Wynnewood Consent Order"). The Wynnewood Consent Order addresses some, but not all, of the traditional marquee issues under the National Petroleum Refining Initiative and addresses certain historic Clean Air Act compliance issues that are generally beyond the scope of a traditional global settlement. Under the Wynnewood Consent Order, WRC paid a civil penalty of $950,000, and agreed to install certain controls, enhance certain compliance programs, and undertake additional testing and auditing A substantial portion of the costs of complying with the Wynnewood Consent Order were expended during the last turnaround. The remaining costs are expected to be $2.0 million. In consideration for entering into the Wynnewood Consent Order, WRC received a release from liability from ODEQ for matters described in the ODEQ order.

The EPA has investigated CRRM's operation for compliance with the RMP. On September 23, 2011, the DOJ, acting on behalf of the EPA and the United States Coast Guard, filed suit against CRRM in the United States District Court for the District of Kansas (in addition to the matters described above, see "Flood, Crude Oil Discharge and Insurance") seeking recovery from CRRM related to alleged non-compliance with the RMP. The Company has reached an agreement with DOJ to settle the RMP claims, but the DOJ re-opened the negotiations. Any liability to DOJ related to the RMP claims is not expected to be material. The lawsuit is stayed while the parties attempt to finalize and file the consent decree.

From time to time, the EPA has conducted inspections and issued information requests to CRNF with respect to the Company's compliance with the RMP and the release reporting requirements under CERCLA and the EPCRA. These previous investigations have resulted in the issuance of preliminary findings regarding CRNF's compliance status. In the fourth quarter of 2010, following CRNF's reported release of ammonia from its cooling water system and the rupture of its UAN vessel (which released ammonia and other regulated substances), the EPA conducted its most recent inspection and issued an additional request for information to CRNF. The EPA has not made any formal claims against the Company and the Company has not accrued for any liability associated with the investigations or releases.

WRC has entered into a series of Clean Water Act consent orders with ODEQ. The latest Consent Order (the "CWA Consent Order"), which supersedes other consent orders, became effective in September 2011. The CWA Consent Order addresses alleged Non-compliance by WRC with its Oklahoma Pollutant Discharge Elimination System permit limits. The CWA Consent Order requires WRC to take corrective action steps, including undertaking studies to determine whether the Wynnewood refinery's wastewater treatment plant capacity is sufficient. The Wynnewood refinery may need to install additional controls or make operational changes to satisfy the requirements of the CWA Consent Order. The cost of additional controls, if any, cannot be predicted at this time. However, based on our experience with wastewater treatment and controls, the Company does not anticipate that the costs of any required additional controls or operational changes would be material.

Environmental expenditures are capitalized when such expenditures are expected to result in future economic benefits. For the years ended December 31, 2012, 2011 and 2010, capital expenditures were approximately $28.4 million, $7.6 million and $13.7 million, respectively, and were incurred to improve the environmental compliance and efficiency of the operations.

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 above or other EHS matters which may develop in the future will not have a material adverse effect on the business, financial condition, or results of operations.

Wynnewood Refinery Incident

On September 28, 2012, the Wynnewood refinery experienced an explosion in a boiler unit that had been temporarily shut down as part of the turnaround process. Two employees were fatally injured. Damage at the refinery was limited to the boiler; process units and other areas of the facility were unaffected. Additionally, there has been no evidence of environmental impact. The refinery was shut down for turnaround maintenance at the time of the incident. The petroleum business completed an internal investigation of the incident and continues to cooperate with OSHA and Oklahoma Department of Labor ("ODL") investigations.

- Definition

The entire disclosure for commitments and contingencies.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 14
-Paragraph 3
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 5
-Paragraph 9, 10, 11, 12
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.25)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 450
-SubTopic 20
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=6952336&loc=d3e14435-108349

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 460
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=6398077&loc=d3e12565-110249

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 440
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6394976&loc=d3e25287-109308

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 20
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6449706&loc=d3e16207-108621

+ Details

Fair Value Measurements

12 Months Ended

Dec. 31, 2012

Fair Value Measurements

Fair Value Measurements

(16) Fair Value Measurements

ASC Topic 820 — Fair Value Measurements and Disclosures ("ASC 820") established a single authoritative definition of fair value when accounting rules require the use of fair value, set out a framework for measuring fair value and required additional disclosures about fair value measurements. ASC 820 clarifies that fair value is an exit price, representing the amount from the perspective of a market participant that holds the asset or owes the liability at the measurement date.

ASC 820 discusses valuation techniques, such as the market approach (prices and other relevant information generated by market transactions involving identical or comparable assets, liabilities or a group of assets and liabilities such as a business), the income approach (techniques to convert future amounts to a single current amount based on market expectations about those future amounts including present value techniques and option pricing), and the cost approach (amount that would be required currently to replace the service capacity of an asset which is often referred to as a replacement cost). ASC 820 utilizes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three broad levels. The following is a brief description of those three levels:

•

Level 1 — Quoted prices in active markets for identical assets 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 December 31, 2012 and 2011:

	December 31, 2012

	Level 1		Level 2			Level 3		Total
	(in thousands)
Location and Description
Cash equivalents	$	133,897	$	—		$	—	$	133,897
Other current assets (marketable securities)		38		—			—		38
Other current assets (other derivative agreements)		—		—			—		—
Other long-term assets (other derivative agreements)		—		938			—		938

Total Assets	$	133,935	$	938		$	—	$	134,873

Other current liabilities (other derivative agreements)		—		(67,747	)		—		(67,747	)
Other current liabilities (interest rate swap)		—		(861	)		—		(861	)
Other long-term liabilities (other derivative agreements)		—		—			—		—
Other long-term liabilities (interest rate swap)		—		(1,890	)		—		(1,890	)

Total Liabilities	$	—	$	(70,498	)	$	—	$	(70,498	)

	December 31, 2011

	Level 1		Level 2			Level 3		Total
	(in thousands)
Location and Description
Cash equivalents	$	187,327	$	—		$	—	$	187,327
Other current assets (marketable securities)		25		—			—		25
Other current assets (other derivative agreements)		—		63,051			—		63,051
Other long-term assets (other derivative agreements)		—		18,831			—		18,831

Total Assets	$	187,352	$	81,882		$	—	$	269,234

Other current liabilities (interest rate swap)		—		(905	)		—		(905	)
Other long-term liabilities (interest rate swap)		—		(1,483	)		—		(1,483	)

Total Liabilities	$	—	$	(2,388	)	$	—	$	(2,388	)

As of December 31, 2012 and 2011, the only financial assets and liabilities that are measured at fair value on a recurring basis are the Company's cash equivalents, available-for-sale marketable securities and derivative instruments. Additionally, the fair value of the Company's debt issuances is disclosed in Note 12 ("Long-Term Debt"). The Refining Partnership's commodity derivative contracts are valued using broker quoted market prices of similar commodity contracts using Level 2 inputs. The Nitrogen Fertilizer Partnership has an interest rate swap that is measured at fair value on a recurring basis using Level 2 inputs. The fair value of these interest rate swap instruments are based on discounted cash flow models that incorporate the cash flows of the derivatives, as well as the current LIBOR rate and a forward LIBOR curve, along with other observable market inputs. The Company's investments in marketable securities are classified as available-for-sale, and as a result, are reported at fair market value using quoted market prices. The Company had no transfers of assets or liabilities between any of the above levels during the year ended December 31, 2012.

- Definition

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 133
-Paragraph 44A, 44B
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15C, 15D
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15A
-Subparagraph a-d
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15B
-Subparagraph a, b
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 3, 10, 14, 15
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 157
-Paragraph 32, 33, 34
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 159
-Paragraph 17-22, 27, 28
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 820
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6925170&loc=d3e19207-110258

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 21
-URI http://asc.fasb.org/extlink&oid=6947722&loc=d3e13537-108611

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 28
-URI http://asc.fasb.org/extlink&oid=6957238&loc=d3e14064-108612

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=6947722&loc=d3e13433-108611

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 30
-URI http://asc.fasb.org/extlink&oid=6957238&loc=d3e14172-108612

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 16
-URI http://asc.fasb.org/extlink&oid=6947722&loc=d3e13504-108611

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 820
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=6925170&loc=d3e19296-110258

+ Details

Derivative Financial Instruments

12 Months Ended

Dec. 31, 2012

Derivative Financial Instruments

Derivative Financial Instruments

(17) Derivative Financial Instruments

Gain (loss) on derivatives, net consisted of the following:

	Year Ended December 31,

	2012			2011			2010
	(in thousands)
Realized gain (loss) on other derivative agreements	$	(137,565	)	$	(7,182	)	$	721
Unrealized gain (loss) on other derivative agreements		(148,027	)		85,262			(2,196	)
Realized gain (loss) on interest rate swap agreements		—			—			(2,860	)
Unrealized gain (loss) on interest rate swap agreements		—			—			2,830

Total gain (loss) on derivatives, net	$	(285,592	)	$	78,080		$	(1,505	)

CVR is subject to price fluctuations caused by supply conditions, weather, economic conditions, interest rate fluctuations and other factors. To manage price risk on crude oil and other inventories and to fix margins on certain future production, the Company from time to time enters into various commodity derivative transactions. The Company, as further described below, entered into certain commodity derivate contracts and an interest rate swap as required by the long-term debt agreements. The commodity derivative contracts are for the purpose of managing price risk on crude oil and finished goods and the interest rate swap was for the purpose of managing interest rate risk until September 30, 2010.

CVR has adopted accounting standards which impose extensive record-keeping requirements in order to designate a derivative financial instrument as a hedge. CVR holds derivative instruments, such as exchange-traded crude oil futures and certain over-the-counter forward swap agreements, which it believes provide an economic hedge on future transactions, but such instruments are not designated as hedges for GAAP purposes. Gains or losses related to the change in fair value and periodic settlements of these derivative instruments are classified as gain (loss) on derivatives, net in the Consolidated Statements of Operations.

CVR maintains a margin account to facilitate other commodity derivative activities. A portion of this account may include funds available for withdrawal. These funds are included in cash and cash equivalents within the Consolidated Balance Sheets. The maintenance margin balance is included within other current assets within the Consolidated Balance Sheets. Dependent upon the position of the open commodity derivatives, the amounts are accounted for as an other current asset or an other current liability within the Consolidated Balance Sheets. From time to time, CVR may be required to deposit additional funds into this margin account. The fair value of the open commodity positions as of December 31, 2012 was a net loss of $14,000 included in other current liabilities. For the year ended December 31, 2012, the Company recognized a realized loss of $10.9 million and an unrealized loss of $0.8 million, which is recorded in loss on derivatives, net in the Consolidated Statement of Operations.

Commodity Swap

Beginning September 2011, the Company entered into several commodity swap contracts with effective periods beginning in January 2012. The physical volumes are not exchanged and these contracts are net settled with cash. The contract fair value of the commodity swaps is reflected on the Consolidated Balance Sheets with changes in fair value currently recognized in the Consolidated 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 December 31, 2012 and 2011, the Company had open commodity hedging instruments consisting of 23.3 million barrels and 13.0 million barrels of crack spreads primarily to fix the margin on a portion of its future gasoline and distillate production. The fair value of the outstanding contracts at December 31, 2012 was a net unrealized loss of $66.8 million, $67.7 million of which is included in current liabilities and $0.9 million is included in non-current assets. The fair value of the outstanding contracts at December 31, 2011 was a net unrealized gain of $80.4 million, $61.6 million of which is included in current assets and $18.8 million is included in long-term assets. For the years ended December 31, 2012 and 2011, the Company recognized a realized loss of $126.6 million and $0, respectively, and an unrealized loss of $147.3 million and an unrealized gain of $80.4 million, respectively, which are recorded in loss on derivatives, net in the Consolidated Statements of Operations. In addition, the Company assumed a commodity swap as part of its Wynnewood Acquisition that expired on December 31, 2011. This commodity swap was not designated as a hedge.

Nitrogen Fertilizer Partnership Interest Rate Swap

On June 30 and July 1, 2011, CRNF entered into 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. The aggregate notional amount covered under these agreements, which commenced on August 12, 2011 and expires on February 12, 2016, totals $62.5 million (split evenly between the two agreement dates). Under the terms of the interest rate swap agreement entered into on June 30, 2011, CRNF will receive a floating rate based on three month LIBOR and pay a fixed rate of 1.94%. Under the terms of the interest rate swap agreement entered into on July 1, 2011, CRNF will receive a floating rate based on three month LIBOR and pay a fixed rate of 1.975%. Both swap agreements will be 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 governed by the CRNF credit agreement. At December 31, 2012, the effective rate was approximately 4.58%. 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 accumulated other comprehensive income (loss) ("AOCI"), and will be reclassified into interest expense when the interest rate swap transaction affects earnings. The ineffective portion of the gain or loss will be recognized immediately in current interest expense on the Consolidated Statement of Operations. The realized loss on the interest rate swap re-classed from AOCI into interest expense was $1.0 million and $0.4 million for the years ended December 31, 2012 and 2011, respectively. For the years ended December 31, 2012 and 2011, the decrease in the fair value of the interest rate swap agreements of $0.4 million and $2.4 million, respectively, which was unrealized, was recognized in accumulated other comprehensive income.

Interest Rate Swap — CRLLC

Until June 30, 2010, CRLLC held derivative contracts known as interest rate swap agreements (the "Interest Rate Swap") that converted CRLLC's floating-rate bank debt into 4.195% fixed-rate debt on a notional amount of $180.0 million from March 31, 2009 until March 31, 2010 and $110.0 million from March 31, 2010 until June 30, 2010. The Interest Rate Swap expired on June 30, 2010. Half of the Interest Rate Swap agreements were held with a related party (as described in Note 18, ("Related Party Transactions"), and the other half were held with a financial institution that was also a lender under CRLLC's first priority credit facility until April 6, 2010.

Under the Interest Rate Swap, CRLLC paid the fixed rate of 4.195% and received a floating rate based on three month LIBOR rates, with payments calculated on the notional amount. The notional amount did not represent the actual amount exchanged by the parties but instead represented the amount on which the contracts are based. The Interest Rate Swap was settled quarterly and marked to market at each reporting date with all unrealized gains and losses recognized on the Consolidated Statement of Operations. Transactions related to the Interest Rate Swap agreements were not allocated to the Petroleum or Nitrogen Fertilizer segments.

- Definition

The entire disclosure for the entity's entire derivative instruments and hedging activities. Describes an entity's risk management strategies, derivatives in hedging activities and non-hedging derivative instruments, the assets, obligations, liabilities, revenues and expenses arising therefrom, and the amounts of and methodologies and assumptions used in determining the amounts of such items.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 133
-Paragraph 45
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 133
-Paragraph 44
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 30
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6887037&loc=d3e80784-113994

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5579245-113959

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4B
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5624163-113959

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4C
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5624171-113959

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=6935481&loc=d3e41638-113959

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1B
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5580258-113959

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5579240-113959

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=6935481&loc=d3e41641-113959

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6935481&loc=d3e41620-113959

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 25
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6886632&loc=d3e76258-113986

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4E
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5624181-113959

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4A
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5618551-113959

Reference 15: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4D
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5624177-113959

Reference 16: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 30
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6887037&loc=d3e80748-113994

Reference 17: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4H
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5624258-113959

Reference 18: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4K
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5708775-113959

Reference 19: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6935481&loc=d3e41635-113959

Reference 20: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(n))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 21: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4J
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5708773-113959

Reference 22: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 30
-Section 45
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6441202&loc=d3e80720-113993

+ Details

Related Party Transactions	12 Months Ended
Related Party Transactions	Dec. 31, 2012
Related Party Transactions
Related Party Transactions	(18) Related Party Transactions In May 2012, Carl C. Icahn and certain of his affiliates (collectively, "Icahn") announced that Icahn 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 December 31, 2012, Icahn owned approximately 82% of all common shares outstanding. See Note 3 ("Change in Control") for additional discussion. Until February 2011, the Goldman Sachs Funds and Kelso Funds owned approximately 40% of CVR. On February 8, 2011, GS and Kelso completed a registered public offering, whereby GS sold into the public market its remaining ownership interest in CVR and Kelso substantially reduced its interest in the Company. On May 26, 2011, Kelso completed a registered public offering in which Kelso sold into the market its remaining ownership interest in CVR. As a result of these sales, the Goldman Sachs Funds and Kelso Funds are no longer stockholders of the Company. *Lease* Since March 2009, the Company, through the Nitrogen Fertilizer Partnership, has leased 200 railcars from American Railcar Leasing LLC, a company controlled by Mr. Carl Icahn, the Company's majority stockholder. The agreement is scheduled to expire on March 31, 2014. For the year ended December 31, 2012, $1.1 million of rent expense was recorded related to this agreement and is included in cost of product sold (exclusive of depreciation and amortization) in the Consolidated Statements of Operations. *Tax Allocation Agreement* On May 19, 2012, CVR became a member of the consolidated federal tax group of American Entertainment Properties Corporation ("AEPC"), a wholly-owned subsidiary of Icahn Enterprises, 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 December 31, 2012, the Company has an overpayment of approximately $9.2 million for federal income taxes due to AEPC under the Tax Allocation Agreement, to be applied as a credit against the Company's estimated tax to be paid during the first quarter of 2013. During the year ended December 31, 2012, the Company paid $150.7 million to AEPC under the Tax Allocation Agreement. *Insight Portfolio Group (formerly Icahn Sourcing, LLC)* Icahn Sourcing, LLC ("Icahn Sourcing") is an entity formed and controlled 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. CVR Energy was a member of the buying group in 2012. Prior to December 31, 2012, the Company did not pay Icahn Sourcing any fees or other amounts with respect to the buying group arrangement. In December, 2012, Icahn Sourcing advised CVR Energy that effective January 1, 2013 it would restructure its ownership and change its name to Insight Portfolio Group LLC ("Insight Portfolio Group"). In connection with the restructuring, 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. The Company projects payments to Insight Portfolio Group will be approximately $0.1 million during 2013. *Interest Rate Swap* On June 30, 2005, the Company entered into three Interest Rate Swap agreements with J. Aron & Company. Approximately $(16,000) was recognized in gain (loss) on derivatives, net, related to these swap agreements for the year ended December 31, 2010. The Interest Rate Swap expired June 30, 2010. *Financing and Other* In connection with the Nitrogen Fertilizer Partnership IPO, an affiliate of GS received an underwriting fee of approximately $5.7 million for its role as a joint book-running manager. In April 2011, CRNF entered into a credit facility as discussed further in Note 12 ("Long-Term Debt") whereby an affiliate of GS was paid fees and expenses of approximately $2.0 million. In March 2010, CRLLC amended its outstanding first priority credit facility. In connection with the amendment, CRLLC paid a subsidiary of GS fees and expenses of approximately $0.9 million for their services as lead bookrunner. In addition, on April 6, 2010, a subsidiary of GS received a fee of $2.0 million as a participating underwriter upon completion of the issuance of the Old Notes (as described in Note 12 "Long-Term Debt"). For the years ended December 31, 2011 and 2010, the Company recognized approximately $0.5 million and $0.7 million, respectively, in expenses for the benefit of GS, Kelso and the president, chief executive officer and chairman of the Board of CVR, in connection with CVR's Registration Rights Agreement. These amounts included registration and filing fees, printing fees, external accounting fees and external legal fees.

- Definition

The entire disclosure for related party transactions, including the nature of the relationship(s), a description of the transactions, the amount of the transactions, the effects of any change in the method of establishing the terms of the transaction from the previous period, stated interest rate, expiration date, terms and manner of settlement per the agreement with the related party, and amounts due to or from related parties. If the entity and one or more other entities are under common ownership or management control and this control affects the operating results or financial position, disclosure includes the nature of the control relationship even if there are no transactions between the entities. Disclosure may also include the aggregate amount of current and deferred tax expense for each statement of earnings presented where the entity is a member of a group that files a consolidated tax return, the amount of any tax related balances due to or from affiliates as of the date of each statement of financial position presented, the principal provisions of the method by which the consolidated amount of current and deferred tax expense is allocated to the members of the group and the nature and effect of any changes in that method. Examples of related party transactions include transactions between (a) a parent company and its subsidiary; (b) subsidiaries of a common parent; (c) and entity and its principal owners; and (d) affiliates.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Article 4
-Section 08
-Paragraph k

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Article 3A
-Section 04
-Paragraph b

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 57
-Paragraph 1-4
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 850
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=6457730&loc=d3e39622-107864

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 850
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6457730&loc=d3e39549-107864

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 850
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6457730&loc=d3e39603-107864

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(k))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 850
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=6457730&loc=d3e39691-107864

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 850
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=6457730&loc=d3e39678-107864

+ Details

Business Segments

12 Months Ended

Dec. 31, 2012

Business Segments

Business Segments

(19) Business Segments

The Company measures segment profit as operating income for Petroleum and Nitrogen Fertilizer, CVR's two reporting segments, based on the definitions provided in ASC Topic 280 — Segment Reporting. All operations of the segments are located within the United States.

Petroleum

Principal products of the Petroleum Segment are refined fuels, propane, and petroleum refining by-products, including pet coke. The Petroleum Segment's Coffeyville refinery sells pet coke to the Nitrogen Fertilizer Partnership for use in the manufacture of nitrogen fertilizer at the adjacent nitrogen fertilizer plant. For the Petroleum Segment, a per-ton transfer price is used to record intercompany sales on the part of the Petroleum Segment and corresponding intercompany cost of product sold (exclusive of depreciation and amortization) for the Nitrogen Fertilizer Segment. The per ton transfer price paid, pursuant to the pet coke supply agreement that became effective October 24, 2007, is based on the lesser of a pet coke price derived from the price received by the Nitrogen Fertilizer Segment for UAN (subject to a UAN based price ceiling and floor) and a pet coke price index for pet coke. The intercompany transactions are eliminated in the Other Segment. Intercompany sales included in petroleum net sales were approximately $9.9 million, $11.4 million and $4.3 million for the years ended December 31, 2012, 2011 and 2010, respectively.

The Petroleum Segment recorded intercompany cost of product sold (exclusive of depreciation and amortization) for the hydrogen sales (purchases) described below under "Nitrogen Fertilizer" of approximately $(6.1) million, $13.2 million and $(1.6) million for the years ended December 31, 2012, 2011 and 2010, 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 $10.2 million, $10.7 million and $4.0 million for the years ended December 31, 2012, 2011 and 2010, respectively.

Pursuant to the feedstock agreement, the Company's segments have the right to transfer excess hydrogen between the Coffeyville refinery and nitrogen fertilizer plant. Sales of hydrogen to the Petroleum Segment have been reflected as net sales for the Nitrogen Fertilizer Segment. Receipts of hydrogen from the Petroleum Segment have been reflected in cost of product sold (exclusive of depreciation and amortization) for the Nitrogen Fertilizer Segment. For the years ended December 31, 2012, 2011 and 2010, the net sales generated from intercompany hydrogen sales were $6.3 million, $14.2 million and $0.1 million, respectively. For the year ended December 31, 2012, 2011 and 2010, the nitrogen fertilizer segment also recognized approximately $0.2 million, $1.0 million and $1.8 million, respectively, of cost of product sold related to the transfer of excess hydrogen. As these intercompany sales and cost of product sold are eliminated, there is no financial statement impact on the consolidated financial statements.

Other Segment

The Other Segment reflects intercompany eliminations, cash and cash equivalents, certain debt related activities, income tax activities and other corporate activities that are not allocated to the operating segments.

	Year Ended December 31,

	2012			2011			2010
	(in thousands)
Net sales
Petroleum	$	8,281,539		$	4,751,826		$	3,903,826
Nitrogen Fertilizer		302,309			302,867			180,468
Other		—			—			—
Intersegment elimination		(16,521	)		(25,580	)		(4,526	)

Total	$	8,567,327		$	5,029,113		$	4,079,768

Cost of product sold (exclusive of depreciation and amortization)
Petroleum	$	6,667,311		$	3,926,632		$	3,538,017
Nitrogen Fertilizer		46,072			42,511			34,328
Other		—			—			—
Intersegment elimination		(16,471	)		(25,629	)		(4,227	)

Total	$	6,696,912		$	3,943,514		$	3,568,118

Direct operating expenses (exclusive of depreciation and amortization)
Petroleum	$	426,527		$	247,665		$	153,112
Nitrogen Fertilizer		95,614			86,491			86,679
Other		(66	)		(104	)		—

Total	$	522,075		$	334,052		$	239,791

Depreciation and amortization
Petroleum	$	107,643		$	69,852		$	66,391
Nitrogen Fertilizer		20,723			18,869			18,463
Other		1,639			1,600			1,907

Total	$	130,005		$	90,321		$	86,761

Operating income
Petroleum	$	1,012,521		$	465,710		$	104,564
Nitrogen Fertilizer		115,758			136,198			20,356
Other		(93,364	)		(35,312	)		(31,856	)

Total	$	1,034,915		$	566,596		$	93,064

Capital expenditures
Petroleum	$	119,974		$	68,612		$	19,761
Nitrogen fertilizer		82,151			19,144			10,117
Other		10,069			3,468			2,531

Total	$	212,194		$	91,224		$	32,409


Total assets
Petroleum	$	2,258,515		$	2,322,148		$	1,049,361
Nitrogen Fertilizer		622,954			659,309			452,165
Other		729,426			137,834			238,658

Total	$	3,610,895		$	3,119,291		$	1,740,184

Goodwill
Petroleum	$	—		$	—		$	—
Nitrogen Fertilizer		40,969			40,969			40,969
Other		—			—			—

Total	$	40,969		$	40,969		$	40,969

- Definition

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 131
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 34
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8981-108599

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 35
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8984-108599

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 42
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9054-108599

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 40
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9031-108599

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 31
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8924-108599

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8538-108599

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 30
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8906-108599

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 41
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9038-108599

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 29
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8864-108599

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 33
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8971-108599

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 26
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8844-108599

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8380-108599

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 12
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8595-108599

Reference 15: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8933-108599

+ Details

Major Customers and Suppliers

12 Months Ended

Dec. 31, 2012

Major Customers and Suppliers

Major Customers and Suppliers

(20) Major Customers and Suppliers

Sales to major customers were as follows:

	Year Ended December 31,

	2012			2011			2010
Petroleum
Customer A		10	%		15	%		14	%
Customer B		9	%		12	%		11	%
Customer C		8	%		9	%		10	%

		27	%		36	%		35	%

Nitrogen Fertilizer
Customer D		10	%		17	%		12	%
Customer E		10	%		12	%		10	%

		20	%		29	%		22	%

The Petroleum Segment obtained crude oil from one supplier under a long-term supply agreement during 2012, 2011 and 2010. The crude oil purchased from this supplier is governed by a long-term contract. Purchases contracted as a percentage of the total cost of product sold (exclusive of depreciation and amortization) for each of the periods were as follows:

	Year Ended December 31,

	2012			2011			2010
Petroleum
Supplier A		45	%		65	%		64	%

The Nitrogen Fertilizer Segment maintains long-term contracts with one supplier. Purchases from this supplier as a percentage of direct operating expenses (exclusive of depreciation and amortization) were as follows:

	Year Ended December 31,

	2012			2011			2010
Nitrogen Fertilizer
Supplier B		5	%		5	%		5	%

Selected Quarterly Financial Information (unaudited)

12 Months Ended

Dec. 31, 2012

Selected Quarterly Financial Information (unaudited)

Selected Quarterly Financial Information (unaudited)

(21) Selected Quarterly Financial Information (unaudited)

Summarized quarterly financial data for December 31, 2012 and 2011.

	Year Ended December 31, 2012

	Quarter
	First			Second			Third			Fourth
	(in thousands except share data)
Net sales	$	1,968,631		$	2,308,318		$	2,409,624		$	1,880,754
Operating costs and expenses:
Cost of product sold (exclusive of depreciation and amortization)		1,635,155			1,874,210			1,702,452			1,485,095
Direct operating expenses (exclusive of depreciation and amortization)		115,514			94,099			109,929			202,533
Selling, general and administrative (exclusive of depreciation and amortization)		45,342			72,047			30,390			35,641
Depreciation and amortization		32,112			32,190			33,109			32,594

Total operating costs and expenses		1,828,123			2,072,546			1,875,880			1,755,863

Operating income		140,508			235,772			533,744			124,891
Other income (expense):
Interest expense and other financing costs		(19,253	)		(18,974	)		(18,962	)		(18,246	)
Interest income		90			133			292			352
Realized loss on derivatives, net		(19,086	)		(8,069	)		(53,271	)		(57,139	)
Unrealized gain (loss) on derivatives, net		(128,167	)		46,886			(115,699	)		48,953
Loss on extinguishment of debt		—			—			—			(37,540	)
Other income (expense), net		117			709			(32	)		166

Total other income (expense)		(166,299	)		20,685			(187,672	)		(63,454	)

Income (loss) before income tax expense		(25,791	)		256,457			346,072			61,437
Income tax expense (benefit)		(9,746	)		91,099			127,618			16,613

Net income (loss)		(16,045	)		165,358			218,454			44,824
Less: Net income attributable to noncontrolling interest		9,157			10,624			9,558			4,647

Net income (loss) attributable to CVR Energy stockholders	$	(25,202	)	$	154,734		$	208,896		$	40,177

Net earnings (loss) per share
Basic	$	(0.29	)	$	1.78		$	2.41		$	0.46
Diluted	$	(0.29	)	$	1.75		$	2.41		$	0.46
Weighted-average common shares outstanding
Basic		86,808,150			86,821,224			86,831,050			86,831,050
Diluted		86,808,150			88,454,006			86,831,050			86,831,050

	Year Ended December 31, 2011

	Quarter
	First			Second			Third			Fourth
	(in thousands except share data)
Net sales	$	1,167,265		$	1,447,716		$	1,351,964		$	1,062,168
Operating costs and expenses:
Cost of product sold (exclusive of depreciation and amortization)		936,822			1,123,375			1,026,040			857,277
Direct operating expenses (exclusive of depreciation and amortization)		68,434			66,207			74,615			124,796
Insurance recovery — business interruption		(2,870	)		—			(490	)		—
Selling, general and administrative (exclusive of depreciation and amortization)		33,262			18,171			17,584			28,973
Depreciation and amortization		22,011			22,043			22,025			24,242

Total operating costs and expenses		1,057,659			1,229,796			1,139,774			1,035,288

Operating income		109,606			217,920			212,190			26,880
Other income (expense):
Interest expense and other financing costs		(13,190	)		(14,205	)		(13,757	)		(14,657	)
Interest income (expense)		274			211			93			(89	)
Realized gain (loss) on derivatives, net		(18,848	)		484			66			11,116
Unrealized gain (loss) on derivatives, net		(3,258	)		6,448			(9,991	)		92,063
Loss on extinguishment of debt		(1,908	)		(170	)		—			—
Other income, net		231			246			243			124

Total other income (expense)		(36,699	)		(6,986	)		(23,346	)		88,557

Income before income tax expense		72,907			210,934			188,844			115,437
Income tax expense		27,119			76,738			68,603			37,103

Net income		45,788			134,196			120,241			78,334
Less: Net income attributable to noncontrolling interest		—			9,331			10,976			12,476

Net income attributable to CVR Energy stockholders	$	45,788		$	124,865		$	109,265		$	65,858

Net earnings per share
Basic	$	0.53		$	1.44		$	1.26		$	0.76
Diluted	$	0.52		$	1.42		$	1.25		$	0.75
Weighted-average common shares outstanding
Basic		86,413,781			86,422,881			86,549,846			86,852,800
Diluted		87,783,857			87,789,351			87,743,600			87,746,843

- Definition

The entire disclosure for the quarterly financial data in the annual financial statements. The disclosure may include a tabular presentation of financial information for each fiscal quarter for the current and previous year, including revenues, gross profit, income or loss before extraordinary items and earnings per share data. It also includes an indication if the information in the note is unaudited, comments on the aggregate effect of year-end adjustments, and an explanation of matters or transactions that affect comparability or are pertinent to an understanding of the information furnished.

+ References + Details

Subsequent Events	12 Months Ended
Subsequent Events	Dec. 31, 2012
Subsequent Events
Subsequent Events	(22) Subsequent Events *Initial Public Offering of CVR Refining, LP* On January 23, 2013, CVR Refining, LP (the "Refining Partnership") completed its initial public offering of its common units representing limited partner interests (the "Refining Partnership IPO"). The Refining Partnership sold 24,000,000 common units at a price of $25.00 per unit, resulting in gross proceeds of $600.0 million, before giving effect to underwriting discounts and other offering expenses. Of the common units issued, 4,000,000 units were purchased by an affiliate of Icahn Enterprises. Additionally, on January 30, 2013, the underwriters closed their option to purchase an additional 3,600,000 common units at a price of $25.00 per common unit resulting in gross proceeds of $90.0 million, before giving effect to underwriting discounts and other offering costs. The common units, which are listed on the NYSE, began trading on January 17, 2013 under the symbol "CVRR." In connection with the Refining Partnership IPO, the Refining Partnership paid approximately $32.5 million in underwriting fees and incurred approximately $3.9 million of other offering costs. Upon consummation of the Refining Partnership IPO, CVR indirectly owned the Refining Partnership's general partner and limited partnership interests in the form of common units. Following the Offering, the Refining Partnership has two types of partnership interests outstanding: • common units representing limited partner interests; and • a general partner interest, which is not entitled to any distributions, and which is held by the Refining Partnership's general partner. The net proceeds from the Refining Partnership IPO of approximately $653.6 million, after deducting underwriting discounts and commissions and offering expenses, have been, or will be, utilized as follows: • approximately $253.0 million was used to repurchase the 10.875% senior secured notes due 2017 (including accrued interest); • approximately $160.0 million will be used to pre-fund certain maintenance and environmental capital expenditures through 2014; • approximately $54.0 million was used to fund the turnaround expenses at the Wynnewood refinery that were incurred during the fourth quarter of 2012; • approximately $85.1 million was distributed to CRLLC; and • the balance of the proceeds are being utilized by the Refining Partnership for general partnership purposes. Subsequent to the Refining Partnership IPO, CVR Energy indirectly owns approximately 81% of the Refining Partnership's outstanding common units and 100% of the Partnership's general partner, which holds a non-economic general partner interest. The Refining Partnership's general partner, CVR Refining GP, LLC, 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 Refining Partnership's general partner is elected by the Refining Partnership's unitholders and will not be subject to re-election on a regular basis in the future. The officers of its general partner manage the day-to-day affairs of the business. 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 and will generally be distributed within 60 days of quarter end. 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. In connection with the Initial Public Offering, the Refining Partnership entered into a services agreement, pursuant to which the Refining Partnership and its general partner will 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 CVR Partners' outstanding units. *Second Lien Senior Secured Notes Repurchase* On January 23, 2013, $253.0 million of the proceeds from the Refining Partnership's IPO were utilized to satisfy and discharge the indenture governing the Second Lien Notes. The amounts were used to (i) repay the face amount of all $222.8 million aggregate principal amount of Second Lien Notes then outstanding, (ii) pay the redemption premium of approximately $20.6 million and (iii) settle accrued interest with respect thereto in an amount of approximately $9.5 million. The repurchase of the Second Lien Notes resulted in a loss on extinguishment of debt of approximately $26.1 million in the first quarter of 2013, which includes the write-off of previously deferred financing fees of $3.7 million and unamortized original issue discount of $1.8 million. *Dividend* On January 24, 2013, the board of directors of the Company adopted a quarterly cash dividend policy. Subject to declaration by its board of directors, CVR Energy's initial quarterly dividend is expected to be $0.75 per share, or $3.00 per share on an annualized basis, which the Company plans to begin paying in the second quarter of 2013. In addition, the board of directors of CVR Energy declared a special dividend of $5.50 per share, which was paid on February 19, 2013, to stockholders of record at the close of business on February 5, 2013. The total amount of the special dividend payment was approximately $477.6 million. *Nitrogen Fertilizer Partnership Distribution* On February 14, 2013, the Nitrogen Fertilizer Partnership paid out a cash distribution to the Nitrogen Fertilizer Partnership's unitholders of record at the close of business on February 7, 2013 for the fourth quarter of 2012 in the amount of $0.192 per unit, or $14.0 million in aggregate. The Company received $9.8 million in respect of our common units.

Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2012

Summary of Significant Accounting Policies

Principles of Consolidation

Principles of Consolidation

Cash and Cash Equivalents

Cash and Cash Equivalents

Accounts Receivable, net

Accounts Receivable, net

Inventories

Inventories

Prepaid Expenses and Other Current Assets

Prepaid Expenses and Other Current Assets

Property, Plant, and Equipment

Property, Plant, and Equipment

Asset		Range of Useful Lives, in Years

Improvements to land		15 to 30
Buildings		20 to 30
Machinery and equipment		5 to 30
Automotive equipment		5 to 15
Furniture and fixtures		3 to 10
Railcars		25 to 40

Goodwill and Intangible Assets

Goodwill and Intangible Assets

Deferred Financing Costs, Underwriting and Original Issue Discount

Deferred Financing Costs, Underwriting and Original Issue Discount

Planned Major Maintenance Costs

Planned Major Maintenance Costs

Cost Classifications

Cost Classifications

Income Taxes

Income Taxes

Impairment of Long-Lived Assets

Impairment of Long-Lived Assets

Revenue Recognition

Revenue Recognition

Shipping Costs

Shipping Costs

Derivative Instruments and Fair Value of Financial Instruments

Derivative Instruments and Fair Value of Financial Instruments

Share-Based Compensation

Share-Based Compensation

Treasury Stock

Treasury Stock

Environmental Matters

Environmental Matters

Use of Estimates

Use of Estimates

Subsequent Events

Subsequent Events

New Accounting Pronouncements

New Accounting Pronouncements

Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2012

Summary of Significant Accounting Policies

Schedule of lives used in computing depreciation for depreciable assets

Asset		Range of Useful Lives, in Years

Improvements to land		15 to 30
Buildings		20 to 30
Machinery and equipment		5 to 30
Automotive equipment		5 to 15
Furniture and fixtures		3 to 10
Railcars		25 to 40

Wynnewood Acquisition (Tables)

12 Months Ended

Dec. 31, 2012

Wynnewood Acquisition

Schedule of total final purchase price allocated to GWEC's net tangible assets based on their fair values

The following table, set forth below, displays the total final purchase price allocated to WEC's net tangible assets based on their fair values as of December 15, 2011 (in millions):


Cash and cash equivalents	$	6.3
Accounts receivable		159.0
Inventories		213.5
Prepaid expenses and other current assets		6.0
Property, plant and equipment		577.0
Accounts payable and accrued liabilities		(316.1	)
Long-term debt		(52.3	)

Total fair values of net assets acquired		593.4

Less: cash acquired		6.3

Total consideration transferred, net of cash acquired	$	587.1

Summary of pro forma condensed consolidated financial information

	Years Ended December 31,

	2011		2010
	(in millions) (unaudited)
Net sales	$	7,674.5	$	6,220.8
Net income		468.8		22.0

- Definition

Tabular disclosure of pro forma results of operations for a material business acquisition or series of individually immaterial business acquisitions that are material in the aggregate.

+ References + Details

Share-Based Compensation (Tables)

12 Months Ended

Dec. 31, 2012

Share-based Compensation

Schedule of service phantom interest and performance phantom interest values

	December 31, 2010

Service Phantom interest (per point)	$	14.64
Performance Phantom interest (per point)	$	21.25

Summary of restricted stock and restricted stock units grant activity and changes

			Weighted- Average Grant-Date Fair Value		Aggregate Intrinsic Value

					(in thousands)
Non-vested at December 31, 2009	177,060		$	6.59	$	1,215

Granted	1,307,378			11.42
Vested	(113,457	)		9.79
Forfeited	(1,799	)		4.14

Non-vested at December 31, 2010	1,369,182		$	10.94	$	20,784

Granted	826,959			18.79
Vested	(557,355	)		11.83
Forfeited	(4,632	)		8.67

Non-vested at December 31, 2011	1,634,154		$	14.61	$	30,608

Granted	318,508			43.66
Vested	(740,811	)		13.59
Forfeited	(66,240	)		16.54

Non-vested at December 31, 2012	1,145,611		$	23.24	$	55,894

Summary of activity and price information regarding stock options granted

			Weighted- Average Exercise Price

Outstanding, December 31, 2009	32,350		$	19.08	8.21

Granted	—			—
Exercised	—			—
Forfeited	(3,149	)		21.61
Expired	(6,301	)		21.61

Outstanding, December 31, 2010	22,900		$	18.03	8.35

Granted	—			—
Exercised	—			—
Forfeited	—			—
Expired	—			—

Outstanding, December 31, 2011	22,900		$	18.03	7.35

Granted	—			—
Exercised	(22,900	)
Forfeited	—			—
Expired	—			—

Outstanding, December 31, 2012	—			—	—

CALLC, CALLC II and CALLC III

Share-based Compensation

Schedule of key information for share-based compensation plans related to override units

						*Compensation Expense for the Year Ended December 31,

	Benchmark Value (per Unit)		Original Awards Issued			*Compensation Expense for the Year Ended December 31,
Award Type	Benchmark Value (per Unit)		Original Awards Issued		Grant Date	2011		2010
						(in thousands)
Override Operating Units	$	11.31		919,630	June 2005	$	—	$	338
Override Operating Units	$	34.72		72,492	December 2006		—		13
Override Value Units(a)	$	11.31		1,839,265	June 2005		4,960		17,586
Override Value Units(b)	$	34.72		144,966	December 2006		451		581
Override Units(c)	$	10.00		642,219	February 2008		184		772

					Total	$	5,595	$	19,290

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

CVR Partners' Long-Term Incentive Plan

Share-based Compensation

Summary of common units and phantom units activity

			Weighted- Average Grant-Date Fair Value		Aggregate Intrinsic Value

					(in thousands)
Non-vested at April 13, 2011	—		$	—	$	—

Granted	200,647			22.34
Vested	(36,076	)		19.36
Forfeited	—			—

Non-vested at December 31, 2011	164,571		$	22.99	$	4,085

Granted	95,370			24.53
Vested	(58,129	)		23.08
Forfeited	—			—

Non-vested at December 31, 2012	201,812		$	23.70	$	5,094

Override Units

Share-based Compensation

Schedule of significant assumption used in the valuation of the Units

		December 31,

		2010
Estimated forfeiture rate		None
Derived Service Period		Forfeiture schedule
Estimated fair value (per unit)		$2.60
Marketability and minority interest discounts		10.0%
Volatility		47.6%

Override Value Units

Share-based Compensation

Schedule of significant assumption used in the valuation of the Units

	(a) Override Value Units December 31,			(b) Override Value Units December 31,

	2010			2010
Estimated forfeiture rate		None			None
Derived service period		6 years			6 years
CVR Energy's closing stock price	$	15.18		$	15.18
Estimated fair value (per unit)	$	22.39		$	6.56
Marketability and minority interest discounts		20.0	%		20.0	%
Volatility		43.0	%		43.0	%

Inventories (Tables)

12 Months Ended

Dec. 31, 2012

Inventories

Schedule of inventories

	December 31,

	2012		2011
	(in thousands)
Finished goods	$	275,169	$	323,315
Raw materials and precious metals		164,287		157,931
In-process inventories		42,767		115,372
Parts and supplies		45,847		39,603

	$	528,070	$	636,221

Property, Plant, and Equipment (Tables)

12 Months Ended

Dec. 31, 2012

Property, Plant, and Equipment

Summary of costs for property, plant, and equipment

	December 31,

	2012		2011
	(in thousands)
Land and improvements	$	30,992	$	26,136
Buildings		40,617		37,289
Machinery and equipment		2,089,545		1,967,269
Automotive equipment		14,969		10,217
Furniture and fixtures		13,658		12,349
Leasehold improvements		2,483		1,445
Railcars		2,496		2,496
Construction in progress		189,291		94,085

		2,384,051		2,151,286
Accumulated depreciation		601,133		478,325

	$	1,782,918	$	1,672,961

Income Taxes (Tables)

12 Months Ended

Dec. 31, 2012

Income Taxes

Schedule of income tax expense (benefit)

	Year Ended December 31,

	2012			2011		2010
	(in thousands)
Current
Federal	$	237,349		$	141,305	$	13,434
State		25,369			7,972		1,262

Total current		262,718			149,277		14,696

Deferred
Federal		(39,857	)		40,350		808
State		2,723			19,936		(1,721	)

Total deferred		(37,134	)		60,286		(913	)

Total income tax expense	$	225,584		$	209,563	$	13,783

Schedule of reconciliation of total income tax expense (benefit) to income tax expense (benefit) computed by applying the statutory federal income tax rate (35%) to pre-tax income (loss)

	Year Ended December 31,

	2012			2011			2010
	(in thousands)
Tax computed at federal statutory rate	$	223,361		$	205,843		$	9,826
State income taxes, net of federal tax benefit		23,910			20,600			1,923
State tax incentives, net of federal tax expense		(5,355	)		(3,174	)		(2,382	)
Domestic production activities deduction		(16,467	)		(10,562	)		(2,025	)
Non-deductible share-based compensation		7,256			2,000			6,747
Non-deductible transaction costs		4,208			—			—
IRS interest (income)/expense, net		93			34			(814	)
Noncontrolling interest		(11,895	)		(11,474	)		—
Partnership basis adjustment		—			4,174			—
Other, net		473			2,122			508

Total income tax expense	$	225,584		$	209,563		$	13,783

Schedule of income tax effect of temporary differences that give rise to significant portions of the deferred income tax assets and deferred income tax liabilities

	Year Ended December 31,

	2012			2011
	(in thousands)
Deferred income tax assets:
Allowance for doubtful accounts	$	751		$	475
Personnel accruals		12,925			6,437
Inventories		3,606			2,097
Unrealized derivative losses, net		26,206			—
Accrued expenses		2,080			101
State tax credit carryforward, net of federal expense		14,425			17,682
Contingent liabilities		10,845			—
Deferred financing		—			76
Other		2,050			2,695

Total gross deferred income tax assets		72,888			29,563

Deferred income tax liabilities:
Unrealized derivative gains, net		—			(31,990	)
Property, plant, and equipment		(282,219	)		(224,452	)
Investment in CVR Partners		(109,701	)		(134,920	)
Deferred financing		(1,046	)		—
Prepaid expenses		(9,439	)		(4,945	)

Total gross deferred income tax liabilities		(402,405	)		(396,307	)

Net deferred income tax liabilities	$	(329,517	)	$	(366,744	)

Schedule of reconciliation of the unrecognized tax benefits

	Year Ended December 31,

	2012			2011		2010
	(in thousands)
Balance beginning of year	$	17,712		$	245	$	—
Increase based on prior year tax positions		4,755			—		245
Decrease based on prior year tax positions		(30	)		—		—
Increases and decrease in current year tax positions		14,705			17,467		—
Settlements		—			—		—
Reductions related to expirations of statute of limitations		(193	)		—		—

Balance end of year	$	36,949		$	17,712	$	245

- Definition

Tabular disclosure of tax positions taken in the tax returns filed or to be filed for which it is more likely than not that the tax position will not be sustained upon examination by taxing authorities (i.e., uncertain tax positions) and other types of income tax contingencies, including: (1) the policy on classification of interest and penalties; (2) a tabular reconciliation of the total amounts of unrecognized tax benefits at the beginning and end of the period; the total amount(s) of: (3) unrecognized tax benefits that, if recognized, would affect the effective tax rate, and (4) interest and penalties recognized in each of the income statement and balance sheet; (5) for positions for which it is reasonably possible that the total amounts unrecognized will significantly change within 12 months of the reporting date the: (i) nature of the uncertainty, (ii) nature of the event that could occur that would cause the change, and (iii) an estimate of the range of the reasonably possible change or a statement that an estimate of the range cannot be made; and (6) a description of tax years that remain subject to examination by major tax jurisdictions.

+ References + Details

Long-Term Debt (Tables)

12 Months Ended

Dec. 31, 2012

Long-Term Debt

Schedule of long-term debt

	December 31,

	2012		2011
	(in thousands)
9.0% First Lien Senior Secured Notes, due 2015, net of unamortized premium of $9,003(1) as of December 31, 2011	$	—	$	456,053
10.875% Second Lien Senior Secured Notes, due 2017, net of unamortized discount of $1,840 and $2,159 as of December 31, 2012 and December 31, 2011, respectively(2)		220,910		220,591
6.5% Second Lien Senior Secured Notes, due 2022		500,000		—
CRNF credit facility		125,000		125,000
Capital lease obligations		51,168		52,259

Long-term debt	$	897,078	$	853,903

(1): Net unamortized premium of $9.0 million represents an unamortized discount of $0.9 million on the original First Lien Notes and a $9.9 million unamortized premium on the additional First Lien Notes issued in December 2011.
(2): All of the Second Lien Notes due 2017 were repaid as of February 2013.

Schedule of estimated amortization of deferred financing costs

Year Ending December 31,	Deferred Financing

	(in thousands)
2013	$	3,687
2014		3,687
2015		3,687
2016		2,995
2017		2,047
Thereafter		4,215

	$	20,318

Schedule of future payments required under capital lease

	Capital Lease

	(in thousands)
2013	$	6,269
2014		6,311
2015		6,355
2016		6,411
2017		6,444
2018 and thereafter		76,756

Total future payments		108,546
Less: amount representing interest		56,287

Present value of future minimum payments		52,259
Less: current portion		1,091

Long-term portion	$	51,168

- Definition

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 02
-Paragraph 22
-Article 5

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6451184&loc=d3e28551-108399

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=6451184&loc=d3e28541-108399

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21475-112644

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.22)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21506-112644

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21538-112644

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21521-112644

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 55
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=6584090&loc=d3e28878-108400

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 470
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6479336&loc=d3e64711-112823

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(e),(f))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

+ Details

Earnings Per Share (Tables)

12 Months Ended

Dec. 31, 2012

Earnings Per Share

Schedule of computations of the basic and diluted earnings per share

	For the Year Ended December 31,

	2012		2011		2010
	(in thousands, except share data)
Net income attributable to CVR Energy stockholders	$	378,605	$	345,776	$	14,290
Weighted-average number of shares of common stock outstanding		86,822,913		86,493,735		86,340,342
Effect of dilutive securities:
Non-vested restricted shares		567,166		1,268,471		448,837
Stock options		2,191		4,367		—

Weighted-average number of shares of common stock outstanding assuming dilution		87,392,270		87,766,573		86,789,179

Basic earnings per share	$	4.36	$	4.00	$	0.17
Diluted earnings per share	$	4.33	$	3.94	$	0.16

Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2012

Commitments and Contingencies

Schedule of minimum required payments for CVR's operating lease agreements and unconditional purchase obligations

Year Ending December 31,	Operating Leases		Unconditional Purchase Obligations(1)

	(in thousands)
2013	$	9,968	$	123,388
2014		7,804		110,011
2015		6,392		99,095
2016		5,545		92,053
2017		3,192		90,770
Thereafter		6,465		930,749

	$	39,366	$	1,446,066

(1): This amount includes approximately $1,007.8 million payable ratably over eighteen years pursuant to petroleum transportation service agreements between CRRM and TransCanada Keystone Pipeline, LP ("TransCanada"). Under the agreements, CRRM receives transportation of at least 25,000 barrels per day of crude oil with a delivery point at Cushing, Oklahoma for a term of twenty years on TransCanada's Keystone pipeline system. CRRM began receiving crude oil under the agreements in the first quarter of 2011.

Schedule of accrual for environmental loss contingencies

Year Ending December 31,	Amount

	(in thousands)
2013	$	724
2014		334
2015		184
2016		127
2017		109
Thereafter		1,056

Undiscounted total		2,534
Less amounts representing interest at 1.47%		210

Accrued environmental liabilities at December 31, 2012	$	2,324

Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2012

Fair Value Measurements

Schedule of assets and liabilities measured at fair value on a recurring basis

	December 31, 2012

	Level 1		Level 2			Level 3		Total
	(in thousands)
Location and Description
Cash equivalents	$	133,897	$	—		$	—	$	133,897
Other current assets (marketable securities)		38		—			—		38
Other current assets (other derivative agreements)		—		—			—		—
Other long-term assets (other derivative agreements)		—		938			—		938

Total Assets	$	133,935	$	938		$	—	$	134,873

Other current liabilities (other derivative agreements)		—		(67,747	)		—		(67,747	)
Other current liabilities (interest rate swap)		—		(861	)		—		(861	)
Other long-term liabilities (other derivative agreements)		—		—			—		—
Other long-term liabilities (interest rate swap)		—		(1,890	)		—		(1,890	)

Total Liabilities	$	—	$	(70,498	)	$	—	$	(70,498	)

	December 31, 2011

	Level 1		Level 2			Level 3		Total
	(in thousands)
Location and Description
Cash equivalents	$	187,327	$	—		$	—	$	187,327
Other current assets (marketable securities)		25		—			—		25
Other current assets (other derivative agreements)		—		63,051			—		63,051
Other long-term assets (other derivative agreements)		—		18,831			—		18,831

Total Assets	$	187,352	$	81,882		$	—	$	269,234

Other current liabilities (interest rate swap)		—		(905	)		—		(905	)
Other long-term liabilities (interest rate swap)		—		(1,483	)		—		(1,483	)

Total Liabilities	$	—	$	(2,388	)	$	—	$	(2,388	)

Derivative Financial Instruments (Tables)

12 Months Ended

Dec. 31, 2012

Derivative Financial Instruments

Components of gain (loss) on derivatives, net

	Year Ended December 31,

	2012			2011			2010
	(in thousands)
Realized gain (loss) on other derivative agreements	$	(137,565	)	$	(7,182	)	$	721
Unrealized gain (loss) on other derivative agreements		(148,027	)		85,262			(2,196	)
Realized gain (loss) on interest rate swap agreements		—			—			(2,860	)
Unrealized gain (loss) on interest rate swap agreements		—			—			2,830

Total gain (loss) on derivatives, net	$	(285,592	)	$	78,080		$	(1,505	)

- Definition

Tabular disclosure of the location and amount of gains and losses reported in the statement of financial performance, or when applicable, the statement of financial position. For example, (a) gains and losses recognized in the income statement on derivative instruments designated and qualifying as hedging instruments in fair value hedges and related hedged items designated and qualifying in fair value hedges and (b) gains and losses initially recognized in other comprehensive income on derivative instruments designated and qualifying as cash flow hedges.

+ References + Details

Business Segments (Tables)

12 Months Ended

Dec. 31, 2012

Business Segments

Schedule of segment information

	Year Ended December 31,

	2012			2011			2010
	(in thousands)
Net sales
Petroleum	$	8,281,539		$	4,751,826		$	3,903,826
Nitrogen Fertilizer		302,309			302,867			180,468
Other		—			—			—
Intersegment elimination		(16,521	)		(25,580	)		(4,526	)

Total	$	8,567,327		$	5,029,113		$	4,079,768

Cost of product sold (exclusive of depreciation and amortization)
Petroleum	$	6,667,311		$	3,926,632		$	3,538,017
Nitrogen Fertilizer		46,072			42,511			34,328
Other		—			—			—
Intersegment elimination		(16,471	)		(25,629	)		(4,227	)

Total	$	6,696,912		$	3,943,514		$	3,568,118

Direct operating expenses (exclusive of depreciation and amortization)
Petroleum	$	426,527		$	247,665		$	153,112
Nitrogen Fertilizer		95,614			86,491			86,679
Other		(66	)		(104	)		—

Total	$	522,075		$	334,052		$	239,791

Depreciation and amortization
Petroleum	$	107,643		$	69,852		$	66,391
Nitrogen Fertilizer		20,723			18,869			18,463
Other		1,639			1,600			1,907

Total	$	130,005		$	90,321		$	86,761

Operating income
Petroleum	$	1,012,521		$	465,710		$	104,564
Nitrogen Fertilizer		115,758			136,198			20,356
Other		(93,364	)		(35,312	)		(31,856	)

Total	$	1,034,915		$	566,596		$	93,064

Capital expenditures
Petroleum	$	119,974		$	68,612		$	19,761
Nitrogen fertilizer		82,151			19,144			10,117
Other		10,069			3,468			2,531

Total	$	212,194		$	91,224		$	32,409


Total assets
Petroleum	$	2,258,515		$	2,322,148		$	1,049,361
Nitrogen Fertilizer		622,954			659,309			452,165
Other		729,426			137,834			238,658

Total	$	3,610,895		$	3,119,291		$	1,740,184

Goodwill
Petroleum	$	—		$	—		$	—
Nitrogen Fertilizer		40,969			40,969			40,969
Other		—			—			—

Total	$	40,969		$	40,969		$	40,969

- Definition

Tabular disclosure of the profit or loss and total assets for each reportable segment. An entity discloses certain information on each reportable segment if the amounts (a) are included in the measure of segment profit or loss reviewed by the chief operating decision maker or (b) are otherwise regularly provided to the chief operating decision maker, even if not included in that measure of segment profit or loss.

+ References + Details

Major Customers and Suppliers (Tables)

12 Months Ended

Dec. 31, 2012

Major Customers and Suppliers

Schedule of sales to major customers

	Year Ended December 31,

	2012			2011			2010
Petroleum
Customer A		10	%		15	%		14	%
Customer B		9	%		12	%		11	%
Customer C		8	%		9	%		10	%

		27	%		36	%		35	%

Nitrogen Fertilizer
Customer D		10	%		17	%		12	%
Customer E		10	%		12	%		10	%

		20	%		29	%		22	%

Petroleum | Supplier concentration

Major Customers and Suppliers

Schedule of purchases contracted as a percentage of the total cost of product sold (exclusive of depreciation and amortization)

	Year Ended December 31,

	2012			2011			2010
Petroleum
Supplier A		45	%		65	%		64	%

Nitrogen Fertilizer | Supplier concentration

Major Customers and Suppliers

Schedule of purchases contracted as a percentage of the total cost of product sold (exclusive of depreciation and amortization)

	Year Ended December 31,

	2012			2011			2010
Nitrogen Fertilizer
Supplier B		5	%		5	%		5	%

- Definition

Tabular disclosure of the nature of a concentration, a benchmark to which it is compared, and the percentage that the risk is to the benchmark.

+ References + Details

Selected Quarterly Financial Information (unaudited) (Tables)

12 Months Ended

Dec. 31, 2012

Selected Quarterly Financial Information (unaudited)

Summary of quarterly financial data

	Year Ended December 31, 2012

	Quarter
	First			Second			Third			Fourth
	(in thousands except share data)
Net sales	$	1,968,631		$	2,308,318		$	2,409,624		$	1,880,754
Operating costs and expenses:
Cost of product sold (exclusive of depreciation and amortization)		1,635,155			1,874,210			1,702,452			1,485,095
Direct operating expenses (exclusive of depreciation and amortization)		115,514			94,099			109,929			202,533
Selling, general and administrative (exclusive of depreciation and amortization)		45,342			72,047			30,390			35,641
Depreciation and amortization		32,112			32,190			33,109			32,594

Total operating costs and expenses		1,828,123			2,072,546			1,875,880			1,755,863

Operating income		140,508			235,772			533,744			124,891
Other income (expense):
Interest expense and other financing costs		(19,253	)		(18,974	)		(18,962	)		(18,246	)
Interest income		90			133			292			352
Realized loss on derivatives, net		(19,086	)		(8,069	)		(53,271	)		(57,139	)
Unrealized gain (loss) on derivatives, net		(128,167	)		46,886			(115,699	)		48,953
Loss on extinguishment of debt		—			—			—			(37,540	)
Other income (expense), net		117			709			(32	)		166

Total other income (expense)		(166,299	)		20,685			(187,672	)		(63,454	)

Income (loss) before income tax expense		(25,791	)		256,457			346,072			61,437
Income tax expense (benefit)		(9,746	)		91,099			127,618			16,613

Net income (loss)		(16,045	)		165,358			218,454			44,824
Less: Net income attributable to noncontrolling interest		9,157			10,624			9,558			4,647

Net income (loss) attributable to CVR Energy stockholders	$	(25,202	)	$	154,734		$	208,896		$	40,177

Net earnings (loss) per share
Basic	$	(0.29	)	$	1.78		$	2.41		$	0.46
Diluted	$	(0.29	)	$	1.75		$	2.41		$	0.46
Weighted-average common shares outstanding
Basic		86,808,150			86,821,224			86,831,050			86,831,050
Diluted		86,808,150			88,454,006			86,831,050			86,831,050

	Year Ended December 31, 2011

	Quarter
	First			Second			Third			Fourth
	(in thousands except share data)
Net sales	$	1,167,265		$	1,447,716		$	1,351,964		$	1,062,168
Operating costs and expenses:
Cost of product sold (exclusive of depreciation and amortization)		936,822			1,123,375			1,026,040			857,277
Direct operating expenses (exclusive of depreciation and amortization)		68,434			66,207			74,615			124,796
Insurance recovery — business interruption		(2,870	)		—			(490	)		—
Selling, general and administrative (exclusive of depreciation and amortization)		33,262			18,171			17,584			28,973
Depreciation and amortization		22,011			22,043			22,025			24,242

Total operating costs and expenses		1,057,659			1,229,796			1,139,774			1,035,288

Operating income		109,606			217,920			212,190			26,880
Other income (expense):
Interest expense and other financing costs		(13,190	)		(14,205	)		(13,757	)		(14,657	)
Interest income (expense)		274			211			93			(89	)
Realized gain (loss) on derivatives, net		(18,848	)		484			66			11,116
Unrealized gain (loss) on derivatives, net		(3,258	)		6,448			(9,991	)		92,063
Loss on extinguishment of debt		(1,908	)		(170	)		—			—
Other income, net		231			246			243			124

Total other income (expense)		(36,699	)		(6,986	)		(23,346	)		88,557

Income before income tax expense		72,907			210,934			188,844			115,437
Income tax expense		27,119			76,738			68,603			37,103

Net income		45,788			134,196			120,241			78,334
Less: Net income attributable to noncontrolling interest		—			9,331			10,976			12,476

Net income attributable to CVR Energy stockholders	$	45,788		$	124,865		$	109,265		$	65,858

Net earnings per share
Basic	$	0.53		$	1.44		$	1.26		$	0.76
Diluted	$	0.52		$	1.42		$	1.25		$	0.75
Weighted-average common shares outstanding
Basic		86,413,781			86,422,881			86,549,846			86,852,800
Diluted		87,783,857			87,789,351			87,743,600			87,746,843

Organization and History of the Company (Details) $ / shares in Units, bbl in Millions, $ in Millions		1 Months Ended			12 Months Ended
	Jun. 30, 2011 USD ($)	Dec. 31, 2011 bbl bbl / d	Apr. 30, 2011 USD ($) $ / shares shares	Oct. 31, 2007 entity	Dec. 31, 2012 USD ($) segment type shares	Dec. 31, 2007 USD ($)	Aug. 29, 2012 shares	May 06, 2012	Dec. 31, 2010
Number of reportable segments \| segment					2
Percentage owned by the public prior to Icahn's acquisition								100.00%
GWEC
Capacity of refinery acquired by the entity in Wynnewood, Oklahoma (in bpd) \| bbl / d		70,000
Capacity of refinery owned by acquiree in Wynnewood, Oklahoma (in bpd) \| bbl		2.0
Goldman Sachs Funds and Kelso Funds
Percentage of outstanding shares beneficially owned									40.00%
Affiliate of GS
CVR Partners, LP
Underwriting fees	$ 5.7
CVR Partners, LP
Percentage of CVR's indirect ownership in CVR Partners, LP					70.00%
CVR Partners, LP
Sale price of managing GP interest						$ 10.6
Interest in the partnership sold into the public market (as a percent)			30.00%
Number of units sold in public offering (in shares) \| shares			22,080,000
Offering price per unit (in dollars per share) \| $ / shares			$ 16.00
Purchase of incentive distribution rights			$ 26.0
Common units outstanding (in units) \| shares					73,065,143
Common units owned by the public (in shares) \| shares					22,145,143
Percentage of common units owned by the public					30.00%
Common units owned by general partner (in units) \| shares					50,920,000
Gross proceeds from the Partnership IPO					$ 353.3
Underwriting fees					24.7
Other offering costs incurred					4.4
Amount paid for purchase of IDRs from general partner					$ 26.0
Number of types of partnership interests outstanding \| type					2
Amount distributed to general partner for reimbursement of certain capital expenditures					$ 18.4
Amount distributed to general partner to fund debt repurchase					117.1
Amount used to pay financing fees and associated legal and professional fees					4.8
Expected investment required for funding of the UAN expansion					130.0
Amount spent for UAN expansion					106.1
Limited partner units to offer and sell \| shares							50,920,000
CVR Partners, LP \| Affiliate of GS
CVR Partners, LP
Underwriting fees					$ 5.7
CALLC Pre Split
Number of entities into which the limited liability company was split \| entity				2
Icahn
Ownership percentage held by controlling stockholder					82.00%
Refining LLC \| Formation and initial public offering
Percentage of CRLLC's ownership interest in CVR GP, LLC					100.00%

Summary of Significant Accounting Policies (Details) $ in Millions	Dec. 31, 2012 USD ($) customer	Dec. 31, 2011 USD ($)
Basis of Consolidation
Percentage of holders of the outstanding common units required to vote for removal of the general partner	66.667%
Cash and Cash Equivalents
Checks issued but not presented to banks \| $	$ 21.3	$ 13.4
Accounts receivable \| Credit concentration \| One customer with largest risk concentration
Accounts Receivable, net
Number of customers \| customer	0
Customers individually representing greater than this percentage for disclosure	9.80%	9.40%

Summary of Significant Accounting Policies (Details 2) $ in Millions	12 Months Ended
	Dec. 31, 2012 USD ($) yr mo
Property, Plant, and Equipment
Minimum project cost required for capitalization of interest \| $	$ 1.0
Minimum period required for completion of project for capitalization of interest (in months) \| mo	6
Improvements to land
Property, Plant, and Equipment
Useful life, low end of range (in years)	15
Useful life, high end of range (in years)	30
Buildings
Property, Plant, and Equipment
Useful life, low end of range (in years)	20
Useful life, high end of range (in years)	30
Machinery and equipment
Property, Plant, and Equipment
Useful life, low end of range (in years)	5
Useful life, high end of range (in years)	30
Automotive equipment
Property, Plant, and Equipment
Useful life, low end of range (in years)	5
Useful life, high end of range (in years)	15
Furniture and fixtures
Property, Plant, and Equipment
Useful life, low end of range (in years)	3
Useful life, high end of range (in years)	10
Railcars
Property, Plant, and Equipment
Useful life, low end of range (in years)	25
Useful life, high end of range (in years)	40

Summary of Significant Accounting Policies (Details 3) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2012 USD ($) shares yr mo phase $ / shares	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)
Cost Classifications
Depreciation and amortization not included in cost of product sold	$ 3.7	$ 2.5	$ 2.8
Depreciation and amortization not included in direct operating expenses	124.1	86.0	81.8
Depreciation and amortization not included in selling, general and administrative expenses	$ 2.2	1.8	2.1
Revenue Recognition
Expected period of delivery of deferred revenue (in months) \| mo	12
Long-Term Incentive Plan \| Restricted Shares
Share-Based Compensation
Offer price per Share on restricted stock awards vested in 2012 \| $ / shares	$ 30.00
Number of non-transferable contingent cash payments right for each restricted stock awards vested in 2012 (in shares) \| shares	1
Coffeyville refinery
Planned Major Maintenance Costs
Number of phases \| phase	2
Turnaround costs	$ 21.2	$ 66.4	1.2
Coffeyville refinery \| Minimum
Planned Major Maintenance Costs
Frequency of planned major maintenance activities (in years) \| yr	4
Coffeyville refinery \| Maximum
Planned Major Maintenance Costs
Frequency of planned major maintenance activities (in years) \| yr	5
Wynnewood refinery
Planned Major Maintenance Costs
Turnaround costs	$ 102.5
Nitrogen fertilizer plant
Planned Major Maintenance Costs
Turnaround costs	$ 4.8		$ 3.5
Frequency of planned major maintenance activities (in years) \| yr	2

Summary of Significant Accounting Policies (Details 4) - Designated as hedges - CRNF $ in Millions	12 Months Ended
	Dec. 31, 2012 USD ($) d agreement	Jul. 01, 2011 agreement
Interest rate swap agreements
Derivative Financial Instruments
Borrowing capacity \| $	$ 125.0
Aggregate notional amount \| $	$ 62.5
Average fixed rate of interest (as a percent)	1.96%
Number of agreements \| agreement	2	2
Interest rate swap agreements entered into on June 30, 2011
Derivative Financial Instruments
Floating rate basis	Three months LIBOR
Fixed rate (as a percent)	1.94%
Settlement period (in days) \| d	90
Interest rate swap agreements entered into on July 1, 2011
Derivative Financial Instruments
Floating rate basis	Three months LIBOR
Fixed rate (as a percent)	1.975%
Settlement period (in days) \| d	90

Change of Control (Details) - Icahn	12 Months Ended
Change of Control (Details) - Icahn	Dec. 31, 2012 shares $ / shares	May 31, 2012 shares $ / shares
Change of Control
Price per share \| $ / shares		$ 30.00
Number of non-transferable contingent cash payments right for each Share (in shares) \| shares		1
Ownership percentage held by controlling stockholder	82.00%
Offer price per Share on restricted stock awards vested in 2012 \| $ / shares	$ 30.00
Number of non-transferable contingent cash payments right for each restricted stock awards vested in 2012 (in shares) \| shares	1

Wynnewood Acquisition (Details) $ in Thousands, bbl in Millions	1 Months Ended		12 Months Ended
	Mar. 31, 2012 USD ($)	Dec. 31, 2011 USD ($) bbl subsidiary bbl / d	Dec. 31, 2012 USD ($) yr	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)	Dec. 15, 2011 USD ($)
Purchase Price Allocation
Total consideration transferred, net of cash acquired				$ 585,987
WEC
Acquisition
Number of wholly-owned subsidiaries of acquired entity \| subsidiary		2
Preliminary purchase price						$ 592,300
Initial cash payment						525,000
Capital expenditure adjustment						1,500
Working capital adjustment						65,800
GWEC's revenues included in Consolidated Statement of Operations from date of acquisition		$ 115,700
GWEC's loss before taxes included in Consolidated Statement of Operations from date of acquisition		$ 2,300
Capacity of refinery acquired by the entity in Wynnewood, Oklahoma (in bpd) \| bbl / d		70,000
Number of barrels of storage tanks owned by the entity included in the refinery of the acquiree \| bbl		2.0
Amount of increase in preliminary purchase price	$ 1,100
Purchase Price Allocation
Cash and cash equivalents						6,300
Accounts Receivable						159,000
Inventories						213,500
Prepaid expenses and other current assets						6,000
Property, plant and equipment						577,000
Accounts payable and accrued liabilities						(316,100)
Long-term debt						(52,300)
Total fair values of net assets acquired						$ 593,400
Less: cash acquired		$ 6,300
Total consideration transferred, net of cash acquired		587,100
Unaudited Pro Forma Financial Information
Net sales				7,674,500	$ 6,220,800
Net income (loss)				468,800	$ 22,000
Acquisition Costs
Refund resulting from post-closing working capital and capital expenditure adjustments		$ 15,800		15,800
Transaction fees and expenses included in selling, general and administrative expense			$ 11,000	$ 5,200
Period of bridge loan (in years) \| yr			1
Commitment fee and other third party costs			$ 3,900

Share-Based Compensation (Details)	1 Months Ended					12 Months Ended
Share-Based Compensation (Details)	Feb. 28, 2011 shares	Feb. 29, 2008 shares	Oct. 31, 2007 entity	Dec. 31, 2006 shares	Jun. 30, 2005 shares	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($) $ / shares	Dec. 31, 2006 shares	Dec. 31, 2012 $ / shares
CALLC Pre Split
Share-based Compensation
Number of entities into which the limited liability company was split \| entity			2
CALLC -Post Split
Share-based Compensation
Number of shares of common stock sold pursuant to a registered public offering	11,759,023
CALLC II
Share-based Compensation
Number of shares of common stock sold pursuant to a registered public offering	15,113,254
CALLC, CALLC II and CALLC III
Key information for the share-based compensation plans related to the override units of CALLC, CALLC II and CALLC III
Compensation Expense \| $						$ 5,595,000	$ 19,290,000
Override Operating Units \| CALLC, CALLC II and CALLC III
Key information for the share-based compensation plans related to the override units of CALLC, CALLC II and CALLC III
Benchmark Value (per unit) \| $ / shares									$ 11.31
Original Award Issued (in shares)					919,630
Compensation Expense \| $							338,000
Valuation Assumptions
Original Award Issued (in shares)					919,630
Override Operating Units \| CALLC, CALLC II and CALLC III
Key information for the share-based compensation plans related to the override units of CALLC, CALLC II and CALLC III
Benchmark Value (per unit) \| $ / shares									34.72
Original Award Issued (in shares)								72,492
Compensation Expense \| $							13,000
Valuation Assumptions
Original Award Issued (in shares)								72,492
Override Value Units (a) \| CALLC, CALLC II and CALLC III
Key information for the share-based compensation plans related to the override units of CALLC, CALLC II and CALLC III
Benchmark Value (per unit) \| $ / shares									11.31
Original Award Issued (in shares)					1,839,265
Compensation Expense \| $						4,960,000	$ 17,586,000
Valuation Assumptions
Original Award Issued (in shares)					1,839,265
Override Value Units (a) \| CALLC and CALLC II
Valuation Assumptions
Derived service period (in years)							6 years
CVR closing stock price (in dollars per share) \| $ / shares							$ 15.18
Estimated fair value (per unit) \| $ / shares							$ 22.39
Marketability and minority interest discounts (as a percent)							20.00%
Volatility (as a percent)							43.00%
Override Value Units (b) \| CALLC, CALLC II and CALLC III
Key information for the share-based compensation plans related to the override units of CALLC, CALLC II and CALLC III
Benchmark Value (per unit) \| $ / shares									34.72
Original Award Issued (in shares)				144,966
Compensation Expense \| $						451,000	$ 581,000
Valuation Assumptions
Original Award Issued (in shares)				144,966
Override Value Units (b) \| CALLC and CALLC II
Valuation Assumptions
Derived service period (in years)							6 years
CVR closing stock price (in dollars per share) \| $ / shares							$ 15.18
Estimated fair value (per unit) \| $ / shares							$ 6.56
Marketability and minority interest discounts (as a percent)							20.00%
Volatility (as a percent)							43.00%
Override Units (c) \| CALLC, CALLC II and CALLC III
Key information for the share-based compensation plans related to the override units of CALLC, CALLC II and CALLC III
Benchmark Value (per unit) \| $ / shares									$ 10.00
Original Award Issued (in shares)		642,219
Compensation Expense \| $						184,000	$ 772,000
Valuation Assumptions
Original Award Issued (in shares)		642,219
Override Units (c) \| CALLC III
Key information for the share-based compensation plans related to the override units of CALLC, CALLC II and CALLC III
Original Award Issued (in shares)		642,219
Valuation Assumptions
Estimated fair value (per unit) \| $ / shares							$ 2.60
Marketability and minority interest discounts (as a percent)							10.00%
Volatility (as a percent)							47.60%
Estimated grant date fair value \| $						$ 3,000
Number of units vested upon issuance (in shares)		109,720
Original Award Issued (in shares)		642,219

Share-Based Compensation (Details 2) $ / shares in Units, $ in Millions	1 Months Ended	3 Months Ended		12 Months Ended
	Nov. 30, 2010 USD ($)	Jun. 30, 2011 USD ($)	Mar. 31, 2011 USD ($)	Dec. 31, 2012 item	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($) $ / shares
Phantom Unit Plans
Share-based Compensation
Number of Phantom Unit Appreciation Plans \| item				2
Payments to phantom unit holders \| $	$ 3.6	$ 9.2	$ 20.1
Compensation expense \| $					$ 10.6	$ 15.5
Service Phantom interest
Share-based Compensation
Interest (per point) \| $ / shares						$ 14.64
Performance Phantom interest
Share-based Compensation
Interest (per point) \| $ / shares						$ 21.25

- Definition

Represents the expense recognized during the period arising from equity-based compensation arrangements (for example, shares of stock, unit, stock options or other equity instruments) with employees, directors and certain consultants qualifying for treatment as employees.

+ References + Details

Share-Based Compensation (Details 3)	1 Months Ended	12 Months Ended
Share-Based Compensation (Details 3)	May 31, 2012 shares	Dec. 31, 2012 USD ($) yr shares $ / shares	Dec. 31, 2011 USD ($) yr $ / shares shares	Dec. 31, 2010 USD ($) yr $ / shares shares	Dec. 31, 2009 USD ($) yr
Other disclosures
Additional share based compensation incurred on modification of awards \| $		$ 9,924,000
Liability for unvested restricted share awards \| $		51,154,000	$ 20,849,000
Restricted Shares
Other disclosures
Liability for unvested restricted share awards \| $		19,500,000
Cash paid to settle liability-classified awards upon vesting \| $		$ 22,200,000
Restricted stock units
Other disclosures
Vesting period		3 years
Portion of stock awards vested per year for Company employees		0.3333
Restricted stock units \| Certain executive officers
Other disclosures
Vesting period		1 year
Restricted stock units \| Mr. Lipinski
Non-vested shares activity
Granted (in shares)		62,920
Long-Term Incentive Plan
Share-based Compensation
Common stock authorized for issuance (in shares)		7,500,000
Shares available for issuance		6,787,341
Long-Term Incentive Plan \| Stock Options
Share-based Compensation
Common stock authorized for issuance (in shares)		1,000,000
Stock option activity
Options outstanding at the beginning of the period (in shares)		22,900	22,900	32,350
Exercised (in shares)	(22,900)	(22,900)
Forfeited (in shares)				(3,149)
Expired (in shares)				(6,301)
Options outstanding at the end of the period (in shares)			22,900	22,900
Weighted-Average Exercise Price
Options outstanding at the beginning of the period (in dollars per share) \| $ / shares		$ 18.03	$ 18.03	$ 19.08
Forfeited (in dollars per share) \| $ / shares				21.61
Expired (in dollars per share) \| $ / shares				21.61
Options outstanding at the end of the period (in dollars per share) \| $ / shares			$ 18.03	$ 18.03
Weighted-Average Remaining Contractual Term
Options outstanding at the end of the period (in years) \| yr			7.35	8.35	8.21
Other disclosures
Compensation expense \| $		$ 0	$ 8,000	$ 9,000
Long-Term Incentive Plan \| Restricted Stock
Other disclosures
Weighted-average period for amortization of unrecognized compensation cost (in years) \| yr		1
Long-Term Incentive Plan \| Restricted Shares
Non-vested shares activity
Non-vested at the beginning of the period (in shares)		1,634,154	1,369,182	177,060
Granted (in shares)		318,508	826,959	1,307,378
Vested (in shares)		(740,811)	(557,355)	(113,457)
Forfeited (in shares)		(66,240)	(4,632)	(1,799)
Non-vested at the end of the period (in shares)		1,145,611	1,634,154	1,369,182
Weighted-Average Grant-Date Fair Value
Non-vested at the beginning of the period (in dollars per share) \| $ / shares		$ 14.61	$ 10.94	$ 6.59
Granted (in dollars per share) \| $ / shares		43.66	18.79	11.42
Vested (in dollars per share) \| $ / shares		13.59	11.83	9.79
Forfeited (in dollars per share) \| $ / shares		16.54	8.67	4.14
Non-vested at the end of the period (in dollars per share) \| $ / shares		$ 23.24	$ 14.61	$ 10.94
Other disclosures
Aggregate Intrinsic Value \| $		$ 55,894,000	$ 30,608,000	$ 20,784,000	$ 1,215,000
Vesting period		3 years
Offer price per share received as cash settlement on restricted stock awards vested in 2012 \| $ / shares		$ 30.00
Number of non-transferable contingent cash payments right for each restricted stock awards vested in 2012 (in shares)		1
Additional share based compensation incurred on modification of awards \| $		$ 12,400,000
Unrecognized compensation cost \| $		19,900,000
Aggregate fair value at the grant date of the shares that vested \| $		10,100,000
Aggregate fair value at grant date of unvested stock outstanding \| $		26,600,000	23,900,000	15,000,000
Compensation expense \| $		$ 36,900,000	$ 9,800,000	$ 2,400,000

Share-Based Compensation (Details 4) $ / shares in Units, $ in Thousands	9 Months Ended	12 Months Ended
	Dec. 31, 2011 USD ($) $ / shares shares	Dec. 31, 2012 USD ($) yr $ / shares shares	Dec. 31, 2011 USD ($) $ / shares shares	Apr. 30, 2011 shares
Share-based Compensation
Additional share based compensation incurred on modification of awards		$ 9,924
Weighted-Average Grant-Date Fair Value
Liability for unvested restricted share awards	$ 20,849	$ 51,154	$ 20,849
CVR Partners, LP \| Long-Term Incentive Plan - CVR Partners
Share-based Compensation
Common stock authorized for issuance (in shares) \| shares		4,748,893		5,000,000
Non-vested shares activity
Non-vested at the beginning of the period (in shares) \| shares		164,571
Granted (in shares) \| shares	200,647	95,370
Vested (in shares) \| shares	(36,076)	(58,129)
Non-vested at the end of the period (in shares) \| shares	164,571	201,812	164,571
Weighted-Average Grant-Date Fair Value
Non-vested at the beginning of the period (in dollars per share) \| $ / shares		$ 22.99
Granted (in dollars per share) \| $ / shares	$ 22.34	24.53
Vested (in dollars per share) \| $ / shares	19.36	23.08
Non-vested at the end of the period (in dollars per share) \| $ / shares	$ 22.99	$ 23.70	$ 22.99
Aggregate Intrinsic Value	$ 4,085	$ 5,094	$ 4,085
Compensation expense		$ 2,200	$ 1,200
CVR Partners, LP \| Long-Term Incentive Plan - CVR Partners \| Units \| Employees of general partner
Share-based Compensation
Vesting period		3 years
CVR Partners, LP \| Long-Term Incentive Plan - CVR Partners \| Phantom stock units
Share-based Compensation
Unrecognized compensation cost		$ 3,600
Weighted-average period for amortization of unrecognized compensation cost (in years) \| yr		1.6
Weighted-Average Grant-Date Fair Value
Liability for unvested restricted share awards		$ 200
Cash paid to settle liability-classified awards upon vesting		$ 300
CVR Partners, LP \| Long-Term Incentive Plan - CVR Partners \| Phantom stock units \| Employees of general partner and CRNF and employee of CVR Energy
Share-based Compensation
Vesting period		3 years

Inventories (Details) - USD ($) $ in Thousands	Dec. 31, 2012	Dec. 31, 2011
Inventories
Finished goods	$ 275,169	$ 323,315
Raw materials and precious metals	164,287	157,931
In-process inventories	42,767	115,372
Parts and supplies	45,847	39,603
Inventories	$ 528,070	$ 636,221

Property, Plant, and Equipment (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Property, Plant, and Equipment
Gross property, plant and equipment	$ 2,384,051	$ 2,151,286
Accumulated depreciation	601,133	478,325
Property, plant, and equipment, net of accumulated depreciation	1,782,918	1,672,961
Capitalized interest	10,800	3,900	$ 1,800
Original carrying value of assets under capital lease obligations	25,100	24,900	$ 5,200
Land and improvements
Property, Plant, and Equipment
Gross property, plant and equipment	30,992	26,136
Buildings
Property, Plant, and Equipment
Gross property, plant and equipment	40,617	37,289
Machinery and equipment
Property, Plant, and Equipment
Gross property, plant and equipment	2,089,545	1,967,269
Automotive equipment
Property, Plant, and Equipment
Gross property, plant and equipment	14,969	10,217
Furniture and fixtures
Property, Plant, and Equipment
Gross property, plant and equipment	13,658	12,349
Leasehold improvements
Property, Plant, and Equipment
Gross property, plant and equipment	2,483	1,445
Railcars
Property, Plant, and Equipment
Gross property, plant and equipment	2,496	2,496
Construction in progress
Property, Plant, and Equipment
Gross property, plant and equipment	$ 189,291	$ 94,085

Goodwill (Details) - USD ($) $ in Thousands	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Goodwill.
Goodwill	$ 40,969	$ 40,969	$ 40,969

- Definition

Carrying amount as of the balance sheet date, which is the cumulative amount paid and (if applicable) the fair value of any noncontrolling interest in the acquiree, adjusted for any amortization recognized prior to the adoption of any changes in generally accepted accounting principles (as applicable) and for any impairment charges, in excess of the fair value of net assets acquired in one or more business combination transactions.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 142
-Paragraph 45
-Subparagraph e
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 142
-Paragraph 43
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Paragraph 68
-Subparagraph l
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 350
-SubTopic 20
-Section 45
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6388280&loc=d3e13770-109266

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 350
-SubTopic 20
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6905597&loc=d3e13816-109267

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Paragraph 72
-Subparagraph d
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 142
-Paragraph 45
-Subparagraph e
-Clause 1
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Paragraph 34
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Note Payable and Capital Lease Obligations (Details) $ in Thousands	1 Months Ended	12 Months Ended
	Nov. 30, 2011 USD ($)	Dec. 31, 2012 USD ($) mo agreement	Dec. 31, 2011 USD ($)
Note Payable and Capital Lease Obligations
Original note payable balance	$ 9,900
Borrowings on note payable			$ 8,800
Capital lease obligations
Outstanding obligation, Noncurrent		$ 897,078	$ 853,903
Wynnewood Acquisition \| Capital lease obligations assumed in acquisition
Capital lease obligations
Number of lease agreements assumed in acquisition \| agreement		2
Outstanding obligation		$ 52,300
Outstanding obligation, Noncurrent		51,200
Outstanding obligation, Current		$ 1,100
Wynnewood Acquisition \| Capital Lease related to Magellan Pipeline Terminals, L.P.
Capital lease obligations
Remaining term of leases (in months) \| mo		201
Wynnewood Acquisition \| Capital Lease related to Excel Pipeline
Capital lease obligations
Remaining term of leases (in months) \| mo		202

Insurance Claims (Details) - USD ($) $ in Thousands	12 Months Ended			27 Months Ended
Insurance Claims (Details) - USD ($) $ in Thousands	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2012
Insurance Claims
Business interruption insurance proceeds		$ 3,360
Insurance proceeds on Coffeyville Refinery incident	$ 703	4,000
Nitrogen Fertilizer Incident
Insurance Claims
Repairs and other associated costs				$ 11,700
Repairs and other associated costs capitalized	4,900			4,900
Repairs and other associated costs recognized	300	900	$ 10,500
Insurance proceeds for UAN reactor rupture	1,000	2,700	$ 4,300	8,000
Business interruption insurance proceeds		3,400
Coffeyville refinery incident in connection with FCCU
Insurance Claims
Repairs and other associated costs		8,000
Property damage insurance deductible amount	2,500			2,500
Insurance proceeds on Coffeyville Refinery incident	4,000	4,000
Insurance receivable	1,300	1,200		1,300
Coffeyville refinery incident at CCR
Insurance Claims
Repairs and other associated costs		3,200
Property damage insurance deductible amount	2,500			$ 2,500
Insurance proceeds on Coffeyville Refinery incident	$ 700
Insurance receivable		$ 700

Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
Income Taxes (Details) - USD ($) $ in Thousands	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Current
Federal									$ 237,349	$ 141,305	$ 13,434
State									25,369	7,972	1,262
Total current									262,718	149,277	14,696
Deferred
Federal									(39,857)	40,350	808
State									2,723	19,936	(1,721)
Total deferred									(37,134)	60,286	(913)
Total income tax expense	$ 16,613	$ 127,618	$ 91,099	$ (9,746)	$ 37,103	$ 68,603	$ 76,738	$ 27,119	$ 225,584	209,563	13,783
Statutory federal income tax rate (as a percent)									35.00%
Reconciliation of total income tax expense (benefit) to income tax expense (benefit) computed by applying the statutory federal income tax rate (35%) to pre-tax income (loss)
Tax computed at federal statutory rate									$ 223,361	205,843	9,826
State income taxes, net of federal tax benefit									23,910	20,600	1,923
State tax incentives, net of federal tax expense									(5,355)	(3,174)	(2,382)
Domestic production activities deduction									(16,467)	(10,562)	(2,025)
Non-deductible share-based compensation									7,256	2,000	6,747
Non-deductible transaction costs									4,208
IRS interest (income)/expense, net									93	34	(814)
Noncontrolling interest									(11,895)	(11,474)
Partnership basis adjustment										4,174
Other, net									473	2,122	508
Total income tax expense	16,613	$ 127,618	$ 91,099	$ (9,746)	37,103	$ 68,603	$ 76,738	$ 27,119	225,584	209,563	13,783
Deferred income tax assets:
Allowance for doubtful accounts	751				475				751	475
Personnel accruals	12,925				6,437				12,925	6,437
Inventories	3,606				2,097				3,606	2,097
Unrealized derivative losses, net	26,206								26,206
Accrued expenses	2,080				101				2,080	101
State tax credit carryforward, net of federal expense	14,425				17,682				14,425	17,682
Contingent liabilities	10,845								10,845
Deferred financing					76					76
Other	2,050				2,695				2,050	2,695
Total gross deferred income tax assets	72,888				29,563				72,888	29,563
Deferred income tax liabilities:
Unrealized derivative gains, net					(31,990)					(31,990)
Property, plant, and equipment	(282,219)				(224,452)				(282,219)	(224,452)
Investment in CVR Partners	(109,701)				(134,920)				(109,701)	(134,920)
Deferred financing	(1,046)								(1,046)
Prepaid expenses	(9,439)				(4,945)				(9,439)	(4,945)
Total gross deferred income tax liabilities	(402,405)				(396,307)				(402,405)	(396,307)
Net deferred income tax liabilities	(329,517)				$ (366,744)				(329,517)	(366,744)
American Entertainment Properties Corp
Kansas High Performance Incentive Program (HPIP) credits
Receivable under the federal tax sharing agreement	$ 9,200								9,200
Federal taxes paid to AEPC under the Tax Sharing Agreement									150,700
Kansas
Kansas High Performance Incentive Program (HPIP) credits
Net income tax benefit recognized from Kansas High Performance Incentive Program									4,500	3,200	2,400
Kansas High Performance Incentive Program (HPIP) credits for qualified business facility investment earned									6,900	$ 4,900	$ 3,700
Oklahoma
Kansas High Performance Incentive Program (HPIP) credits
Net income tax benefit recognized from qualified manufacturing facility investment									900
Qualified manufacturing facility investment credit earned									$ 1,300

Income Taxes (Details 2) - USD ($) $ in Thousands	12 Months Ended
Income Taxes (Details 2) - USD ($) $ in Thousands	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Income taxes
Federal and state interest expense and penalties		$ 100
Interest income related to 2005 and 2006 amended returns to carry back 2007 losses			$ 1,300
Unrecognized tax benefits which, if recognized, would impact the company's effective tax rate	$ 10,400
Interest expense recognized on uncertain tax positions	500
Penalties recognized on uncertain tax positions	200
Accrued interest	500
Accrued penalties	200
Decrease in unrecognized tax benefits that is reasonably possible, maximum	1,500
Reconciliation of the unrecognized tax benefits
Balance beginning of year	17,712	245
Increase based on prior year tax positions	4,755		245
Decrease based on prior year tax positions	(30)
Increases and decrease in current year tax positions	14,705	17,467
Reductions related to expirations of statute of limitations	(193)
Balance end of year	36,949	$ 17,712	$ 245
State \| Kansas
Income taxes
Tax credit carryforwards	9,800
State \| Oklahoma
Income taxes
Tax credit carryforwards	$ 3,800

Long-Term Debt (Details)					1 Months Ended								3 Months Ended					12 Months Ended
Long-Term Debt (Details)	Nov. 23, 2012 USD ($)	Oct. 23, 2012 USD ($)	Dec. 15, 2011 USD ($)	Apr. 13, 2011 USD ($)	Jun. 30, 2012	Dec. 31, 2011 USD ($)	Nov. 30, 2011 USD ($)	May 31, 2011 USD ($)	Apr. 30, 2011 USD ($)	Feb. 28, 2011	Dec. 31, 2010 USD ($)	Apr. 30, 2010 USD ($)	Dec. 31, 2012 USD ($)	Dec. 31, 2011 USD ($)	Jun. 30, 2011 USD ($)	Mar. 31, 2011 USD ($)	Mar. 31, 2010 USD ($)	Dec. 31, 2012 USD ($)	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)	Dec. 20, 2012 USD ($)	Nov. 02, 2011 yr	Apr. 14, 2011 USD ($)	Feb. 22, 2011 USD ($)	Dec. 30, 2010	Apr. 06, 2010 USD ($)
Long-Term Debt
Capital lease obligations						$ 52,259,000							$ 51,168,000	$ 52,259,000				$ 51,168,000	$ 52,259,000
Long-term debt						853,903,000							897,078,000	853,903,000				897,078,000	853,903,000
Aggregate principal amount							$ 9,900,000
Loss on extinguishment of debt													37,540,000		$ 170,000	$ 1,908,000		37,540,000	2,078,000	$ 16,647,000
Total net proceeds from the offering																			206,000,000
Accrued interest payable						16,100,000							12,200,000	16,100,000				12,200,000	16,100,000
Accrued interest settled on redemption																		73,886,000	45,230,000	$ 45,352,000
9.0% Senior Secured Notes, due 2015
Long-Term Debt
Long-term debt						$ 456,053,000								$ 456,053,000					$ 456,053,000
Stated interest rate (as a percent)						9.00%								9.00%					9.00%
Net unamortized premium						$ 9,003,000								$ 9,003,000					$ 9,003,000
9.0% Senior Secured Notes, due 2015 \| CRLLC
Long-Term Debt
Net unamortized premium						9,000,000								9,000,000					9,000,000
Unamortized discount						900,000								900,000					900,000
Unamortized premium						9,900,000								9,900,000					9,900,000
Principal payment	$ 124,100,000	$ 323,000,000							$ 500,000
Loss on extinguishment of debt													33,400,000
Prepayment Premium	8,400,000	23,200,000											31,600,000
Redemption of notes		348,100,000
Portion of unamortized premium written off													6,300,000
Accrued interest settled on redemption	$ 1,600,000	$ 1,800,000
Write-off of previously deferred financing charges													8,100,000
Original Notes \| CRLLC
Long-Term Debt
Write-off of deferred financing costs and original issue discount								$ 89,000
Principal payment								$ 2,700,000			$ 27,500,000
Prepayment premium percentage																									3.00%
Loss on extinguishment of debt											$ 1,600,000
Purchase price as a percentage of the principal amount at which the entity is required to purchase a portion of the notes								103.00%
Portion of prepayment premium recorded as loss on extinguishment of debt								$ 81,000
Original Notes \| CRLLC and Coffeyville Finance Inc. (Issuers)
Long-Term Debt
Stated interest rate (as a percent)																										9.00%
Aggregate principal amount												$ 275,000,000
Issue price as a percentage of principal amount																										99.511%
Additional First Lien Notes \| CRLLC
Long-Term Debt
Stated interest rate (as a percent)			9.00%
Unamortized premium			$ 10,000,000
Total net proceeds from the offering			202,800,000
Deferred underwriting discounts			4,000,000
Third party fees																			800,000
Bridge loan commitment and other associated fees			$ 3,300,000
Structuring fees																			200,000
Additional First Lien Notes \| CRLLC and Coffeyville Finance Inc. (Issuers)
Long-Term Debt
Aggregate principal amount						200,000,000
Issue price as a percentage of principal amount			105.00%
Accrued interest payable														3,700,000
10.875% Senior Secured Notes, due 2017
Long-Term Debt
Long-term debt						$ 220,591,000							$ 220,910,000	$ 220,591,000				$ 220,910,000	$ 220,591,000
Stated interest rate (as a percent)						10.875%							10.875%	10.875%				10.875%	10.875%
Unamortized discount						$ 2,159,000							$ 1,840,000	$ 2,159,000				$ 1,840,000	$ 2,159,000
10.875% Senior Secured Notes, due 2017 \| Level 2
Long-Term Debt
Estimated fair value													243,000,000					243,000,000
10.875% Senior Secured Notes, due 2017 \| CRLLC
Long-Term Debt
Principal payment									2,200,000
10.875% Senior Secured Notes, due 2017 \| CRLLC and Coffeyville Finance Inc. (Issuers)
Long-Term Debt
Stated interest rate (as a percent)																										10.875%
Aggregate principal amount												225,000,000
Issue price as a percentage of principal amount																										98.811%
Old Notes \| CRLLC
Long-Term Debt
Unamortized discount																										$ 4,000,000
Total net proceeds from the offering												485,700,000
Underwriter fees												10,000,000
Underwriting discount expensed												76,000
Third party costs expensed												30,000
Deferred underwriting discounts																										9,900,000
Third party costs capitalized																										$ 3,900,000
Third party fees												287,000
Additional third party fees and expenses associated with the offering												3,600,000
Old Notes \| CRLLC \| Maximum
Long-Term Debt
Amount of debt to be purchased under a fertilizer event offer																							$ 100,000,000
Old Notes \| CRLLC and Coffeyville Finance Inc. (Issuers)
Long-Term Debt
Purchase price as a percentage of the principal amount at which the entity is required to purchase a portion of the notes					101.00%
6.5% Second Lien Senior Secured Notes, due 2022
Long-Term Debt
Long-term debt													$ 500,000,000					$ 500,000,000
Stated interest rate (as a percent)													6.50%					6.50%
6.5% Second Lien Senior Secured Notes, due 2022 \| Refining LLC
Long-Term Debt
Stated interest rate (as a percent)		6.50%
Aggregate principal amount		$ 500,000,000
Total net proceeds from the offering		492,500,000
Deferred finance costs		$ 8,700,000
6.5% Second Lien Senior Secured Notes, due 2022 \| Refining LLC \| Level 2
Long-Term Debt
Estimated fair value													$ 497,500,000					$ 497,500,000
Tranche D term loan \| CRLLC
Long-Term Debt
Principal payment												453,300,000					$ 25,000,000
Prepayment premium percentage																	2.00%									2.00%
Prepayment Premium												9,100,000					$ 500,000
Write-off of previously deferred financing charges												$ 5,400,000
Bridge loan \| CRLLC
Long-Term Debt
Period of bridge loan (in years) \| yr																						1
Fees and third party costs																			3,900,000
ABL Credit Facility \| CRLLC
Long-Term Debt
Commitment fees			$ 2,600,000
Deferred finance costs						9,100,000								9,100,000					9,100,000
Write-off of previously deferred financing charges													4,100,000
Increase in deferred financing costs due to modification or extinguishment of debt instrument																$ 800,000
Borrowing capacity			$ 400,000,000																					$ 250,000,000
Letter of credit sublimit as a percentage of the total facility commitment																								90.00%
Maximum borrowing capacity optional expansion																								$ 250,000,000
ABL Credit Facility \| CRLLC \| LIBOR
Long-Term Debt
Variable rate basis										LIBOR
ABL Credit Facility \| CRLLC \| LIBOR \| Minimum
Long-Term Debt
Basis spread on variable rate (as a percent)																								2.75%
ABL Credit Facility \| CRLLC \| LIBOR \| Maximum
Long-Term Debt
Basis spread on variable rate (as a percent)																								3.00%
ABL Credit Facility \| CRLLC \| Prime
Long-Term Debt
Variable rate basis										prime rate
ABL Credit Facility \| CRLLC \| Prime \| Minimum
Long-Term Debt
Basis spread on variable rate (as a percent)																								1.75%
ABL Credit Facility \| CRLLC \| Prime \| Maximum
Long-Term Debt
Basis spread on variable rate (as a percent)																								2.00%
First Priority Credit Facility \| CRLLC
Long-Term Debt
Borrowing capacity																								$ 150,000,000
CRNF credit facility \| CRNF
Long-Term Debt
Borrowing capacity				$ 125,000,000
CRNF credit facility
Long-Term Debt
Long-term debt						$ 125,000,000							125,000,000	$ 125,000,000				125,000,000	$ 125,000,000
CRNF credit facility \| CRNF
Long-Term Debt
Deferred finance costs				$ 4,800,000
Amount of special distribution made by the Partnership to CRLLC upon closing of credit facility									$ 87,200,000
CRNF credit facility \| CRNF \| Prime
Long-Term Debt
Variable rate basis									prime rate
Basis spread on variable rate (as a percent)				2.50%
CRNF credit facility \| CRNF \| Eurodollar
Long-Term Debt
Variable rate basis									Eurodollar rate
Basis spread on variable rate (as a percent)				3.50%
Revolving credit facility \| CRNF
Long-Term Debt
Borrowing capacity				$ 25,000,000
Uncommitted incremental facility				$ 50,000,000
Amended and Restated ABL Credit Facility \| CRLLC
Long-Term Debt
Deferred finance costs													2,100,000					2,100,000
Increase in deferred financing costs due to modification or extinguishment of debt instrument													2,800,000
Aggregate availability													372,300,000					372,300,000
Outstanding letters of credit													$ 27,700,000					$ 27,700,000
Amended and Restated ABL Credit Facility \| Credit parties
Long-Term Debt
Borrowing capacity																					$ 400,000,000
Letter of credit sublimit as a percentage of the total facility commitment																					90.00%
Maximum borrowing capacity optional expansion																					$ 200,000,000
Swingline loans sublimit as a percentage of the total facility commitment																					10.00%
Percentage threshold of borrowing base and total commitments for determination of interest rate on borrowings													50.00%					50.00%
Percentage threshold of borrowing base and total commitments for determination of unused capacity commitment fee													50.00%					50.00%
Percentage of maximum amount available to be drawn under line of credit deducted to compute fees on commercial letters of credit																		0.50%
Percentage of customary facing fees																		0.125%
Amended and Restated ABL Credit Facility \| Credit parties \| Daily Average Amount Of Loans And Letters Of Credit Outstanding Less Than 50% Of Lesser Of Borrowing Base And Total Commitments
Long-Term Debt
Unused line fee (as a percent)																		0.40%
Amended and Restated ABL Credit Facility \| Credit parties \| Daily Average Amount Of Loans And Letters Of Credit Outstanding Equal To Or Greater Than 50% Of Lesser Of Borrowing Base And Total Commitments
Long-Term Debt
Unused line fee (as a percent)																		0.30%
Amended and Restated ABL Credit Facility \| Credit parties \| LIBOR
Long-Term Debt
Variable rate basis																		LIBOR
Amended and Restated ABL Credit Facility \| Credit parties \| LIBOR \| Quarterly Average Excess Availability Exceeding 50% Of Lesser Of Borrowing Base And Total Commitments
Long-Term Debt
Basis spread on variable rate (as a percent)													1.75%					1.75%
Amended and Restated ABL Credit Facility \| Credit parties \| LIBOR \| Quarterly Average Excess Availability Less Than Or Equal To 50% Of Lesser Of Borrowing Base And Total Commitments
Long-Term Debt
Basis spread on variable rate (as a percent)													2.00%					2.00%
Amended and Restated ABL Credit Facility \| Credit parties \| Prime
Long-Term Debt
Variable rate basis																		prime rate
Amended and Restated ABL Credit Facility \| Credit parties \| Prime \| Quarterly Average Excess Availability Exceeding 50% Of Lesser Of Borrowing Base And Total Commitments
Long-Term Debt
Basis spread on variable rate (as a percent)													0.75%					0.75%
Amended and Restated ABL Credit Facility \| Credit parties \| Prime \| Quarterly Average Excess Availability Less Than Or Equal To 50% Of Lesser Of Borrowing Base And Total Commitments
Long-Term Debt
Basis spread on variable rate (as a percent)													1.00%					1.00%

Long-Term Debt (Details 2) $ in Thousands	12 Months Ended
Long-Term Debt (Details 2) $ in Thousands	Dec. 31, 2012 USD ($) mo	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)
Deferred Financing Costs and Original Issue Discount
Amortization of deferred financing costs reported as interest expense and other financing costs	$ 5,000	$ 4,900	$ 3,700
Estimated amortization of deferred financing costs
2013	3,687
2014	3,687
2015	3,687
2016	2,995
2017	2,047
Thereafter	4,215
Total	20,318
Future payments required under capital leases
Long-term portion	51,168	$ 52,259
Wynnewood Acquisition \| Capital lease
Future payments required under capital leases
2013	6,269
2014	6,311
2015	6,355
2016	6,411
2017	6,444
2018 and thereafter	76,756
Total future payments	108,546
Less: amount representing interest	56,287
Present value of future minimum payments	52,259
Less: current portion	1,091
Long-term portion	$ 51,168
Wynnewood Acquisition \| Capital Lease related to Excel Pipeline LLC
Estimated amortization of deferred financing costs
Remaining term of leases (in months) \| mo	202
Wynnewood Acquisition \| Capital Lease related to Magellan Pipeline Terminals, L.P.
Estimated amortization of deferred financing costs
Remaining term of leases (in months) \| mo	201

Earnings Per Share (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Earnings Per Share
Net income attributable to CVR Energy stockholders	$ 40,177	$ 208,896	$ 154,734	$ (25,202)	$ 65,858	$ 109,265	$ 124,865	$ 45,788	$ 378,605	$ 345,776	$ 14,290
Weighted-average number of shares of common stock outstanding	86,831,050	86,831,050	86,821,224	86,808,150	86,852,800	86,549,846	86,422,881	86,413,781	86,822,913	86,493,735	86,340,342
Effect of dilutive securities:
Non-vested restricted shares									567,166	1,268,471	448,837
Stock options (in shares)									2,191	4,367
Weighted-average number of shares of common stock outstanding assuming dilution	86,831,050	86,831,050	88,454,006	86,808,150	87,746,843	87,743,600	87,789,351	87,783,857	87,392,270	87,766,573	86,789,179
Basic earnings per share (in dollars per share)	$ 0.46	$ 2.41	$ 1.78	$ (0.29)	$ 0.76	$ 1.26	$ 1.44	$ 0.53	$ 4.36	$ 4.00	$ 0.17
Diluted earnings per share (in dollars per share)	$ 0.46	$ 2.41	$ 1.75	$ (0.29)	$ 0.75	$ 1.25	$ 1.42	$ 0.52	$ 4.33	$ 3.94	$ 0.16
Antidilutive securities excluded from computation of diluted earnings per share (in shares)										18,533	22,900

Benefit Plans (Details) - Defined-contribution 401(k) plans $ in Millions		12 Months Ended
	Apr. 03, 2013	Dec. 31, 2012 USD ($) yr plan	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)	Apr. 01, 2013 plan
Benefit Plans
Number of defined-contribution 401(k) plans \| plan		3			2
Vesting schedule for employer's matching funds \| yr		3
Matching contributions made by the company during the year \| $		$ 4.5	$ 2.3	$ 2.2
CVR
Benefit Plans
Employee contribution limit per calendar year as a percentage of annual salaries		50.00%
Employee contribution limit per calendar year as a percentage of annual income sharing		100.00%
Nonunion plan \| CVR
Benefit Plans
Employer match of employee contributions of first 6% of eligible compensation (as a percent)		100.00%
Percentage of eligible compensation, matched by employer		6.00%
Union plan \| Wynnewood Acquisition
Benefit Plans
Employer match of employee contributions of first 6% of eligible compensation (as a percent)		80.00%
Percentage of eligible compensation, matched by employer		5.00%
Employer contribution each pay period (as a percent)		3.00%
Union plan \| CVR
Benefit Plans
Employer match of employee contributions of first 6% of eligible compensation (as a percent)		100.00%
Percentage of eligible compensation, matched by employer		6.00%
Union plan \| CVR \| Wynnewood Acquisition
Benefit Plans
Employer match of employee contributions of first 6% of eligible compensation (as a percent)	100.00%
Percentage of eligible compensation, matched by employer	6.00%

Commitments and Contingencies (Details) $ in Thousands	12 Months Ended
Commitments and Contingencies (Details) $ in Thousands	Dec. 31, 2012 USD ($) bbl	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)
Operating Leases
2013	$ 9,968
2014	7,804
2015	6,392
2016	5,545
2017	3,192
Thereafter	6,465
Operating leases	39,366
Unconditional Purchase Obligations
2013	123,388
2014	110,011
2015	99,095
2016	92,053
2017	90,770
Thereafter	930,749
Unconditional purchase obligations	1,446,066
Lease expenses	7,700	$ 5,100	$ 5,100
Petroleum transportation service agreement with TransCanada \| CRRM
Unrecorded purchase agreements
Amount payable related to petroleum transportation service agreements	$ 1,007,800
Term of agreement	18 years
Minimum quantity of crude oil to be received per day (in barrels) \| bbl	25,000
Period over which minimum quantity of crude oil is receivable	20 years

Commitments and Contingencies (Details 2) $ in Millions	1 Months Ended			12 Months Ended
Commitments and Contingencies (Details 2) $ in Millions	Mar. 31, 2011 USD ($) yr	Aug. 31, 2010 USD ($)	Oct. 31, 2008 yr bbl / d	Dec. 31, 2012 USD ($) yr bbl / d	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)	Dec. 31, 2007 yr bbl / d	Dec. 31, 2005 USD ($) bbl / d	Dec. 31, 2004 bbl / d
City \| Lawsuit under long-term purchase agreement \| CRNF
Long-term commitments
Receipt of refunds		$ 4.8
Throughput and deficiency agreement assumed \| Wynnewood Acquisition
Long-term commitments
Estimated annual expenses associated with agreement				$ 3.6
HollyFrontier Corporation
Long-term commitments
Expenses related to agreement				$ 6.0
Material \| Plains Pipeline \| CRRM
Long-term commitments
Minimum barrels of crude oil to be transported per day \| bbl / d				80,000
Term of agreement (in years) \| yr				5
Term of agreement over which a quantity of materials must be purchased to meet the capacity of the supplier (in years) \| yr				15
Expenses related to agreement				$ 12.5	$ 9.8	$ 11.4
Material \| MAPL \| CRRM
Long-term commitments
Minimum barrels of crude oil to be transported per day \| bbl / d								2,000,000
Expenses related to agreement				3.5	1.3	2.4
Material \| CCPS \| CRRM
Long-term commitments
Minimum barrels of crude oil to be transported per day \| bbl / d									10,000
Expenses related to agreement				6.1	8.4	16.6
Material \| Plains \| CRRM
Long-term commitments
Minimum barrels of crude oil to be transported per day \| bbl / d							29,200,000
Expenses related to agreement				2.6	2.4	2.5
Annual automatic extension period of agreement (in years) \| yr							1
Period after which agreement is subject to annual automatic extensions							2 years 1 day
Expenses related to separate Terminalling Agreement				3.4	3.3	3.1
Material \| Linde, Inc. \| CRNF
Long-term commitments
Minimum committed contractual payment								$ 0.3
Expenses related to agreement				4.3	4.2	4.7
Material \| Enterprise \| CRRM
Long-term commitments
Term of agreement (in years) \| yr	5
Expenses related to agreement	$ 2.4				1.8	1.3
Material \| Magellan
Long-term commitments
Minimum barrels of crude oil to be transported per day \| bbl / d			20,000
Term of agreement (in years) \| yr			10
Expenses related to agreement				$ 2.1	$ 0.7	$ 0.6

Commitments and Contingencies (Details 3)					1 Months Ended								12 Months Ended
Commitments and Contingencies (Details 3)	Feb. 25, 2013 USD ($)	Sep. 28, 2012 item	Aug. 10, 2012 USD ($)	Jun. 21, 2012 USD ($)	Aug. 31, 2012 item	Apr. 30, 2012 yr component contract anniversary	Mar. 31, 2012 USD ($)	Jun. 30, 2010 USD ($)	May 31, 2010 lawsuit	Feb. 28, 2010 yr	Oct. 31, 2009 USD ($) plaintiff	May 31, 2008 USD ($) claimant	Dec. 31, 2012 USD ($) yr landfill lawsuit plaintiff issue	Dec. 31, 2011 USD ($) landfill	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)	Dec. 31, 2008 USD ($)	Feb. 12, 2013 USD ($)	Oct. 25, 2010 USD ($)
Commitments and Contingencies
Insurance proceeds under primary environmental liability insurance policy															$ 3,161,000
Estimated future payments for environmental obligations
Expenses related to environmental, health and safety ("EHS") matters													$ 28,400,000	$ 7,600,000	13,700,000
CRRM
Commitments and Contingencies
Tenure of pipeage contracts under Settlement Agreement (in years) \| yr													1
WRC
Estimated future payments for environmental obligations
Payment of civil penalties													$ 950,000
Expected remaining costs under consent order													$ 2,000,000
KCC and FERC
Commitments and Contingencies
Tenure of pipeage contracts under Settlement Agreement (in years) \| yr						1
Number of components of Settlement Rates \| component						2
MAPL
Commitments and Contingencies
Tenure of pipeage contracts under Settlement Agreement (in years) \| yr						1
Period until which third party entity would provide an estimate of pipeline integrity costs (in years) \| anniversary						10
Number of pipeage contracts \| contract						2
Litigation \| CRRM
Commitments and Contingencies
Appraised value of Coffeyville refinery	$ 160,000,000
Litigation \| Deutsche Bank
Commitments and Contingencies
Aggregate amount of claims			$ 18,500,000
Litigation \| CRNF
Commitments and Contingencies
Property tax abatement period (in years) \| yr													10
Increase in property tax expenses													$ 11,300,000	11,400,000	$ 11,700,000	$ 10,700,000	$ 10,700,000
Appraised value of nitrogen fertilizer plant	35,000,000
Decrease in property tax expenses	$ 10,500,000
Litigation \| Oklahoma and Kansas \| CRRM
Commitments and Contingencies
Number of lawsuits filed \| lawsuit									2
Litigation \| Oklahoma \| CRRM
Commitments and Contingencies
Number of lawsuits filed \| lawsuit													15
Litigation \| New Mexico \| CRRM
Commitments and Contingencies
Number of lawsuits filed \| lawsuit													2
Flood, Crude Oil Discharge and Insurance
Commitments and Contingencies
Aggregate amount of claims								$ 3,200,000			$ 3,200,000	$ 4,400,000
Number of private claimants \| claimant												16
Number of additional plaintiffs \| plaintiff											3
Number of claims not settled \| plaintiff													1
Reimbursement of oversight cost																			$ 1,800,000
Insurance proceeds under primary environmental liability insurance policy													$ 25,000,000
Flood, Crude Oil Discharge and Insurance \| CRRM
Commitments and Contingencies
Environmental civil penalty for CWA violations																		$ 600,000
Amount of reimbursement agreed for oversight cost																		$ 1,700,000
EHS
Environmental, Health, and Safety ("EHS") Matters
Environmental accruals													2,300,000	1,900,000
Environmental accruals included in other current liabilities													700,000	500,000
Estimated closure and post-closure costs													$ 800,000	$ 900,000
Number of landfills \| landfill													2	2
Estimated future payments for environmental obligations
2013													$ 724,000
2014													334,000
2015													184,000
2016													127,000
2017													109,000
Thereafter													1,056,000
Undiscounted total													2,534,000
Less amounts representing interest at 1.47%													210,000
Accrued environmental liabilities at the end of the year													$ 2,324,000
Interest rate (as a percent)													1.47%
EHS \| CRRM
Estimated future payments for environmental obligations
Renewable fuel as percentage of all fuel used as required by the EPA under the Renewable Fuel Standard													9.00%
Required percentage of refining capacity													9.60%
Marquee issues under the Clean Air Act \| issue													4
Percentage of refining capacity							90.00%
Environmental civil penalty							$ 700,000
Remaining costs associated with Second Consent Decree							41,000,000
Portion of remaining costs associated with Second Consent Decree to be recorded as capital expenditures							39,000,000
Estimated cost of completion of project							$ 1,200,000
EHS \| Maximum
Estimated future payments for environmental obligations
Period over which incremental capital expenditure not material and limited primarily to retrofit and replacement of heaters and boilers (in years) \| yr										7
EHS \| Minimum
Estimated future payments for environmental obligations
Period over which incremental capital expenditure not material and limited primarily to retrofit and replacement of heaters and boilers (in years) \| yr										5
MSAT II \| CRRM and CRT
Estimated future payments for environmental obligations
Remaining amount expected to be spent for environmental remediation compliance, including capital expenditures													$ 59,000,000
MSAT II \| WRC
Estimated future payments for environmental obligations
Remaining amount expected to be spent for environmental remediation compliance, including capital expenditures													$ 94,000,000
Goldman Sachs Tender Offer Dispute
Commitments and Contingencies
Aggregate amount of claims				$ 18,500,000
Wynnewood refinery incident
Estimated future payments for environmental obligations
Number of employees fatally injured \| item		2
New Vitol Agreement \| CRRM
Commitments and Contingencies
Number of companies for which crude oil will obtain \| item					2
Renewal term of agreement													1 year
Number of days for prior notice of nonrenewal													180 days

Fair Value Measurements (Details) - Recurring - USD ($) $ in Thousands	Dec. 31, 2012	Dec. 31, 2011
Level 1
Fair value measurements
Cash equivalents	$ 133,897	$ 187,327
Other current assets (marketable securities)	38	25
Total Assets	133,935	187,352
Level 2
Fair value measurements
Total Assets	938	81,882
Total Liabilities	(70,498)	(2,388)
Level 2 \| Other derivative agreements
Fair value measurements
Other current assets		63,051
Other long-term assets	938	18,831
Other current liabilities	(67,747)
Level 2 \| Interest rate swap
Fair value measurements
Other current liabilities	(861)	(905)
Other long-term liabilities	(1,890)	(1,483)
Total
Fair value measurements
Cash equivalents	133,897	187,327
Other current assets (marketable securities)	38	25
Total Assets	134,873	269,234
Total Liabilities	(70,498)	(2,388)
Total \| Other derivative agreements
Fair value measurements
Other current assets		63,051
Other long-term assets	938	18,831
Other current liabilities	(67,747)
Total \| Interest rate swap
Fair value measurements
Other current liabilities	(861)	(905)
Other long-term liabilities	$ (1,890)	$ (1,483)

Derivative Financial Instruments (Details) bbl in Millions	3 Months Ended									12 Months Ended
Derivative Financial Instruments (Details) bbl in Millions	Dec. 31, 2012 USD ($) bbl d agreement	Sep. 30, 2012 USD ($)	Jun. 30, 2012 USD ($)	Mar. 31, 2012 USD ($)	Dec. 31, 2011 USD ($) bbl	Sep. 30, 2011 USD ($)	Jun. 30, 2011 USD ($)	Mar. 31, 2011 USD ($)	Jun. 30, 2010 USD ($)	Dec. 31, 2012 USD ($) bbl d agreement	Dec. 31, 2011 USD ($) bbl	Dec. 31, 2010 USD ($)	Jul. 01, 2011 agreement	Apr. 13, 2011 USD ($)	Mar. 31, 2010 USD ($)
Derivative Financial Instruments
Unrealized (loss)	$ 48,953,000	$ (115,699,000)	$ 46,886,000	$ (128,167,000)	$ 92,063,000	$ (9,991,000)	$ 6,448,000	$ (3,258,000)		$ (148,027,000)	$ 85,262,000	$ 634,000
Realized gain (loss) on other derivatives	(57,139,000)	$ (53,271,000)	$ (8,069,000)	$ (19,086,000)	$ 11,116,000	$ 66,000	$ 484,000	$ (18,848,000)		(137,565,000)	(7,182,000)	(2,139,000)
Total gain (loss) on derivatives, net										(285,592,000)	78,080,000	(1,505,000)
CRNF \| Term loan facility
Derivative Financial Instruments
Borrowing capacity on credit facility														$ 125,000,000
Derivative agreements
Derivative Financial Instruments
Realized gain (loss)										(137,565,000)	(7,182,000)	721,000
Unrealized (loss)										(148,027,000)	85,262,000	(2,196,000)
Commodity derivatives
Derivative Financial Instruments
Unrealized (loss)										(800,000)
Portion of net unrealized loss in other current liabilities	$ 14,000									14,000
Realized gain (loss)										10,900,000
Commodity swap
Derivative Financial Instruments
Unrealized (loss)										(147,300,000)	80,400,000
Realized gain (loss) on other derivatives										126,600,000	0
Interest rate swap agreements
Derivative Financial Instruments
Realized gain (loss)												(2,860,000)
Unrealized (loss)										400,000	2,400,000	$ 2,830,000
Realized loss on the interest rate swap re-classed from AOCI into interest expense										$ 1,000,000	$ 400,000
Designated as hedges \| Interest rate swap agreements entered into on June 30, 2011 \| CRNF
Derivative Financial Instruments
Floating rate basis										Three months LIBOR
Fixed rate (as a percent)	1.94%									1.94%
Settlement period (in days) \| d	90									90
Designated as hedges \| Interest rate swap agreements entered into on July 1, 2011 \| CRNF
Derivative Financial Instruments
Floating rate basis										Three months LIBOR
Fixed rate (as a percent)	1.975%									1.975%
Settlement period (in days) \| d	90									90
Designated as hedges \| Interest rate swap agreements \| CRNF
Derivative Financial Instruments
Number of floating-to-fixed interest rate swap agreements \| agreement	2									2			2
Borrowing capacity on credit facility	$ 125,000,000									$ 125,000,000
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)	4.58%									4.58%
Not designated as hedges \| Commodity derivative contracts entered into during September 2011
Derivative Financial Instruments
Number of barrels \| bbl	23.3				13.0					23.3	13.0
Net unrealized loss	$ 66,800,000									$ 66,800,000
Portion of net unrealized loss in current liabilities	67,700,000									67,700,000
Net unrealized gain					$ 80,400,000						$ 80,400,000
Portion of net unrealized gain in current assets					61,600,000						61,600,000
Portion of net unrealized gain in long-term assets	$ 900,000				$ 18,800,000					$ 900,000	$ 18,800,000
Not designated as hedges \| Interest rate swap agreements \| CRLLC
Derivative Financial Instruments
Aggregate notional amount									$ 110,000,000						$ 180,000,000
Floating rate basis									Three months LIBOR
Fixed rate (as a percent)									4.195%

Related Party Transactions (Details)		1 Months Ended				3 Months Ended								12 Months Ended
Related Party Transactions (Details)	Jun. 30, 2011 USD ($)	Apr. 30, 2011 USD ($)	Apr. 30, 2010 USD ($)	Mar. 31, 2010 USD ($)	Mar. 31, 2009 item	Dec. 31, 2012 USD ($)	Sep. 30, 2012 USD ($)	Jun. 30, 2012 USD ($)	Mar. 31, 2012 USD ($)	Dec. 31, 2011 USD ($)	Sep. 30, 2011 USD ($)	Jun. 30, 2011 USD ($)	Mar. 31, 2011 USD ($)	Dec. 31, 2012 USD ($)	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)	Jun. 30, 2005 agreement
Interest Rate Swap
Recognized in gain (loss) on derivatives						$ (57,139,000)	$ (53,271,000)	$ (8,069,000)	$ (19,086,000)	$ 11,116,000	$ 66,000	$ 484,000	$ (18,848,000)	$ (137,565,000)	$ (7,182,000)	$ (2,139,000)
American Railcar Leasing LLC
Related Party Transactions
Number of railcars leased \| item					200
Rent expenses														1,100,000
American Entertainment Properties Corp
Related Party Transactions
Receivable under the federal tax sharing agreement						$ 9,200,000								9,200,000
Federal taxes paid to AEPC under the Tax Sharing Agreement														$ 150,700,000
Icahn
Related Party Transactions
Ownership percentage held by controlling stockholder						82.00%								82.00%
Goldman Sachs Funds and Kelso Funds
Related Party Transactions
Percentage of outstanding shares beneficially owned																40.00%
J. Aron \| Terminated derivative contract \| Interest Rate Swap June 30 2005
Interest Rate Swap
Number of Interest Rate Swap Agreements \| agreement																	3
Recognized in gain (loss) on derivatives																$ (16,000)
Affiliate of GS
Financing and Other
Underwriter fees	$ 5,700,000
Affiliate of GS \| CRLLC \| CRNF credit facility
Financing and Other
Additional third party fees and expenses associated with the offering		$ 2,000,000
Subsidiary of GS \| CRNF \| First Priority Credit Facility
Financing and Other
Additional third party fees and expenses associated with the offering			$ 2,000,000	$ 900,000
GS, Kelso and the president, chief executive officer and chairman of the board of CVR
Financing and Other
Expenses related to Registration Rights Agreement															$ 500,000	$ 700,000
Insight Portfolio Group (formerly Icahn Sourcing, LLC)
Related Party Transactions
Projected payment to related party						$ 100,000								$ 100,000

Business Segments (Details) $ in Thousands	3 Months Ended								12 Months Ended
Business Segments (Details) $ in Thousands	Dec. 31, 2012 USD ($)	Sep. 30, 2012 USD ($)	Jun. 30, 2012 USD ($)	Mar. 31, 2012 USD ($)	Dec. 31, 2011 USD ($)	Sep. 30, 2011 USD ($)	Jun. 30, 2011 USD ($)	Mar. 31, 2011 USD ($)	Dec. 31, 2012 USD ($) segment	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)
Business Segments
Number of reportable segments \| segment									2
Business Segments
Net sales	$ 1,880,754	$ 2,409,624	$ 2,308,318	$ 1,968,631	$ 1,062,168	$ 1,351,964	$ 1,447,716	$ 1,167,265	$ 8,567,327	$ 5,029,113	$ 4,079,768
Cost of product sold (exclusive of depreciation and amortization)	1,485,095	1,702,452	1,874,210	1,635,155	857,277	1,026,040	1,123,375	936,822	6,696,912	3,943,514	3,568,118
Direct operating expenses (exclusive of depreciation and amortization)	202,533	109,929	94,099	115,514	124,796	74,615	66,207	68,434	522,075	334,052	239,791
Depreciation and amortization	32,594	33,109	32,190	32,112	24,242	22,025	22,043	22,011	130,005	90,321	86,761
Operating income (loss)	124,891	$ 533,744	$ 235,772	$ 140,508	26,880	$ 212,190	$ 217,920	$ 109,606	1,034,915	566,596	93,064
Capital expenditures									212,194	91,224	32,409
Total assets	3,610,895				3,119,291				3,610,895	3,119,291	1,740,184
Goodwill	40,969				40,969				40,969	40,969	40,969
Petroleum
Business Segments
Intercompany sales									9,900	11,400	4,300
Intercompany cost of product sold (exclusive of depreciation and amortization)									(6,100)	13,200	(1,600)
Net sales									8,281,539	4,751,826	3,903,826
Cost of product sold (exclusive of depreciation and amortization)									6,667,311	3,926,632	3,538,017
Direct operating expenses (exclusive of depreciation and amortization)									426,527	247,665	153,112
Depreciation and amortization									107,643	69,852	66,391
Operating income (loss)									1,012,521	465,710	104,564
Capital expenditures									119,974	68,612	19,761
Total assets	2,258,515				2,322,148				2,258,515	2,322,148	1,049,361
Nitrogen Fertilizer
Business Segments
Intercompany sales									6,300	14,200	100
Intercompany cost of product sold (exclusive of depreciation and amortization)									10,200	10,700	4,000
Cost of product sold related to the transfer of excess hydrogen									200	1,000	1,800
Net sales									302,309	302,867	180,468
Cost of product sold (exclusive of depreciation and amortization)									46,072	42,511	34,328
Direct operating expenses (exclusive of depreciation and amortization)									95,614	86,491	86,679
Depreciation and amortization									20,723	18,869	18,463
Operating income (loss)									115,758	136,198	20,356
Capital expenditures									82,151	19,144	10,117
Total assets	622,954				659,309				622,954	659,309	452,165
Goodwill	40,969				40,969				40,969	40,969	40,969
Other
Business Segments
Direct operating expenses (exclusive of depreciation and amortization)									(66)	(104)
Depreciation and amortization									1,639	1,600	1,907
Operating income (loss)									(93,364)	(35,312)	(31,856)
Capital expenditures									10,069	3,468	2,531
Total assets	$ 729,426				$ 137,834				729,426	137,834	238,658
Intersegment elimination
Business Segments
Net sales									(16,521)	(25,580)	(4,526)
Cost of product sold (exclusive of depreciation and amortization)									$ (16,471)	$ (25,629)	$ (4,227)

Major Customers and Suppliers (Details) - item	12 Months Ended
Major Customers and Suppliers (Details) - item	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Sales \| Customer concentration \| Petroleum
Major Customers and Suppliers
Concentration risk (as a percent)	27.00%	36.00%	35.00%
Sales \| Customer concentration \| Petroleum \| Customer A
Major Customers and Suppliers
Concentration risk (as a percent)	10.00%	15.00%	14.00%
Sales \| Customer concentration \| Petroleum \| Customer B
Major Customers and Suppliers
Concentration risk (as a percent)	9.00%	12.00%	11.00%
Sales \| Customer concentration \| Petroleum \| Customer C
Major Customers and Suppliers
Concentration risk (as a percent)	8.00%	9.00%	10.00%
Sales \| Customer concentration \| Nitrogen Fertilizer
Major Customers and Suppliers
Concentration risk (as a percent)	20.00%	29.00%	22.00%
Sales \| Customer concentration \| Nitrogen Fertilizer \| Customer D
Major Customers and Suppliers
Concentration risk (as a percent)	10.00%	17.00%	12.00%
Sales \| Customer concentration \| Nitrogen Fertilizer \| Customer E
Major Customers and Suppliers
Concentration risk (as a percent)	10.00%	12.00%	10.00%
Total cost of products sold (exclusive of depreciation and amortization) \| Supplier concentration \| Petroleum
Major Customers and Suppliers
Number of major suppliers	1	1	1
Total cost of products sold (exclusive of depreciation and amortization) \| Supplier concentration \| Petroleum \| Supplier A
Major Customers and Suppliers
Concentration risk (as a percent)	45.00%	65.00%	64.00%
Direct operating expenses (exclusive of depreciation and amortization) \| Supplier concentration \| Nitrogen Fertilizer
Major Customers and Suppliers
Number of major suppliers	1	1	1
Direct operating expenses (exclusive of depreciation and amortization) \| Supplier concentration \| Nitrogen Fertilizer \| Supplier B
Major Customers and Suppliers
Concentration risk (as a percent)	5.00%	5.00%	5.00%

Selected Quarterly Financial Information (unaudited) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Selected Quarterly Financial Information (unaudited)
Net sales	$ 1,880,754	$ 2,409,624	$ 2,308,318	$ 1,968,631	$ 1,062,168	$ 1,351,964	$ 1,447,716	$ 1,167,265	$ 8,567,327	$ 5,029,113	$ 4,079,768
Operating costs and expenses:
Cost of product sold (exclusive of depreciation and amortization)	1,485,095	1,702,452	1,874,210	1,635,155	857,277	1,026,040	1,123,375	936,822	6,696,912	3,943,514	3,568,118
Direct operating expenses (exclusive of depreciation and amortization)	202,533	109,929	94,099	115,514	124,796	74,615	66,207	68,434	522,075	334,052	239,791
Insurance recovery - business interruption						(490)		(2,870)		(3,360)
Selling, general and administrative (exclusive of depreciation and amortization)	35,641	30,390	72,047	45,342	28,973	17,584	18,171	33,262	183,420	97,990	92,034
Depreciation and amortization	32,594	33,109	32,190	32,112	24,242	22,025	22,043	22,011	130,005	90,321	86,761
Total operating costs and expenses	1,755,863	1,875,880	2,072,546	1,828,123	1,035,288	1,139,774	1,229,796	1,057,659	7,532,412	4,462,517	3,986,704
Operating income	124,891	533,744	235,772	140,508	26,880	212,190	217,920	109,606	1,034,915	566,596	93,064
Other income (expense):
Interest expense and other financing costs	(18,246)	(18,962)	(18,974)	(19,253)	(14,657)	(13,757)	(14,205)	(13,190)	(75,435)	(55,809)	(50,268)
Interest income (expense)	352	292	133	90	(89)	93	211	274	867	489	2,211
Realized gain (loss) on derivatives, net	(57,139)	(53,271)	(8,069)	(19,086)	11,116	66	484	(18,848)	(137,565)	(7,182)	(2,139)
Unrealized gain (loss) on derivatives, net	48,953	(115,699)	46,886	(128,167)	92,063	(9,991)	6,448	(3,258)	(148,027)	85,262	634
Loss on extinguishment of debt	(37,540)						(170)	(1,908)	(37,540)	(2,078)	(16,647)
Other income (expense), net	166	(32)	709	117	124	243	246	231	960	844	1,218
Total other income (expense)	(63,454)	(187,672)	20,685	(166,299)	88,557	(23,346)	(6,986)	(36,699)	(396,740)	21,526	(64,991)
Income before income taxes	61,437	346,072	256,457	(25,791)	115,437	188,844	210,934	72,907	638,175	588,122	28,073
Income tax expense (benefit)	16,613	127,618	91,099	(9,746)	37,103	68,603	76,738	27,119	225,584	209,563	13,783
Net income	44,824	218,454	165,358	(16,045)	78,334	120,241	134,196	45,788	412,591	378,559	14,290
Less: Net income attributable to noncontrolling interest	4,647	9,558	10,624	9,157	12,476	10,976	9,331		33,986	32,783
Net income attributable to CVR Energy Stockholders	$ 40,177	$ 208,896	$ 154,734	$ (25,202)	$ 65,858	$ 109,265	$ 124,865	$ 45,788	$ 378,605	$ 345,776	$ 14,290
Net earnings (loss) per share
Basic (in dollars per share)	$ 0.46	$ 2.41	$ 1.78	$ (0.29)	$ 0.76	$ 1.26	$ 1.44	$ 0.53	$ 4.36	$ 4.00	$ 0.17
Diluted (in dollars per share)	$ 0.46	$ 2.41	$ 1.75	$ (0.29)	$ 0.75	$ 1.25	$ 1.42	$ 0.52	$ 4.33	$ 3.94	$ 0.16
Weighted-average common shares outstanding
Basic (in shares)	86,831,050	86,831,050	86,821,224	86,808,150	86,852,800	86,549,846	86,422,881	86,413,781	86,822,913	86,493,735	86,340,342
Diluted (in shares)	86,831,050	86,831,050	88,454,006	86,808,150	87,746,843	87,743,600	87,789,351	87,783,857	87,392,270	87,766,573	86,789,179

Subsequent Events (Details) - USD ($)					1 Months Ended		3 Months Ended				12 Months Ended
Subsequent Events (Details) - USD ($)	Feb. 14, 2013	Jan. 30, 2013	Jan. 23, 2013	Jan. 17, 2013	Jan. 31, 2013	Apr. 30, 2011	Mar. 31, 2013	Dec. 31, 2012	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Jan. 24, 2013
Distribution
Net proceeds from IPO after deducting underwriting discounts and commissions and offering expenses												$ 324,880,000
Loss on extinguishment of debt								$ (37,540,000)	$ (170,000)	$ (1,908,000)	$ (37,540,000)	(2,078,000)	$ (16,647,000)
10.875% Senior Secured Notes, due 2017
Distribution
Unamortized original issue discount								$ 1,840,000			$ 1,840,000	$ 2,159,000
Stated interest rate (as a percent)								10.875%			10.875%	10.875%
CVR Partners
Distribution
Number of units sold in public offering (in shares)						22,080,000
Offering price per unit (in dollars per share)						$ 16.00
Other offering costs incurred											$ 4,400,000
Dividend declared
Dividend
Initial quarterly dividend expected (in dollars per share)														$ 0.75
Dividend expected on annualized basis (in dollars per share)														3.00
Special dividend payable (in dollars per share)														$ 5.50
Amount of the special dividend paid							$ 477,600,000
Initial Public Offering \| 10.875% Senior Secured Notes, due 2017
Distribution
Stated interest rate (as a percent)			10.875%
Initial Public Offering \| CVR Refining, LP
Distribution
Number of units sold in public offering (in shares)			24,000,000
Offering price per unit (in dollars per share)			$ 25.00
Gross proceeds before giving effect to underwriting discounts and other offering expenses			$ 600,000,000
Additional common units sold on exercise of option by underwriters (in shares)		3,600,000
Common units price per unit (in dollars per share)		$ 25.00
Gross proceeds before giving effect to underwriting discounts and other offering costs		$ 90,000,000
Underwriting fees				$ 32,500,000
Other offering costs incurred				$ 3,900,000
CVR Energy's indirect ownership in outstanding common units (as a percent)			81.00%
Percentage of CRLLC's ownership interest in CVR GP, LLC			100.00%
Net proceeds from IPO after deducting underwriting discounts and commissions and offering expenses			$ 653,600,000
Proceeds from IPO to be utilized for pre-funding of certain maintenance and environmental capital expenditures through 2014					$ 160,000,000
Initial Public Offering \| CVR Refining, LP \| Icahn
Distribution
Number of units sold in public offering (in shares)			4,000,000
Initial Public Offering \| CVR Partners \| Minimum
Distribution
Sustaining ownership of the reporting entity or its subsidiary in partnership (as a percent)					50.00%
Initial Public Offering \| CRLLC
Distribution
Amount distributed to CRLLC			$ 85,100,000
Initial Public Offering \| Wynnewood refinery
Distribution
Proceeds from IPO to be utilized for funding the turnaround expenses in acquisitions								$ 54,000,000
Repurchase of debt \| CVR Refining, LP \| 10.875% Senior Secured Notes, due 2017
Distribution
Proceeds from IPO to be utilized for repurchase of debt			253,000,000
Face amount of debt repurchased			222,800,000
Redemption premium			20,600,000
Accrued interest			$ 9,500,000
Loss on extinguishment of debt							26,100,000
Write-off of previously deferred financing charges							3,700,000
Unamortized original issue discount							$ 1,800,000
Cash distribution \| Nitrogen fertilizer plant
Distribution
Cash distribution (in dollars per unit)	$ 0.192
Aggregate cash distributions paid	$ 14,000,000
Proceeds from issuance of common units	$ 9,800,000