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Document and Entity Information - USD ($) $ in Millions	12 Months Ended
Document and Entity Information - USD ($) $ in Millions	Dec. 31, 2011	Feb. 17, 2012	Jun. 30, 2011
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, 2011
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Public Float			$ 2,180
Entity Common Stock, Shares Outstanding		86,808,150
Document Fiscal Year Focus	2011
Document Fiscal Period Focus	FY

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2011	Dec. 31, 2010
Current assets:
Cash and cash equivalents	$ 388,328	$ 200,049
Accounts receivable, net of allowance for doubtful accounts of $1,282 and $722, respectively	182,619	80,169
Inventories	636,221	247,172
Prepaid expenses and other current assets	117,509	28,616
Insurance receivable	1,939
Income tax receivable	30,167
Deferred income taxes		43,351
Total current assets	1,356,783	599,357
Property, plant, and equipment, net of accumulated depreciation	1,672,961	1,081,312
Intangible assets, net	312	344
Goodwill	40,969	40,969
Deferred financing costs, net	20,319	10,601
Insurance receivable	4,076	3,570
Other long-term assets	23,871	4,031
Total assets	3,119,291	1,740,184
Current liabilities:
Note payable and capital lease obligations	9,880	8,014
Accounts payable	466,559	155,220
Personnel accruals	20,849	29,151
Accrued taxes other than income taxes	35,147	21,266
Income taxes payable	2,400	7,983
Deferred income taxes	9,271
Deferred revenue	9,026	18,685
Other current liabilities	34,427	25,396
Total current liabilities	587,559	265,715
Long-term liabilities:
Long-term debt and capital lease obligations, net of current portion	853,903	468,954
Accrued environmental liabilities, net of current portion	1,459	2,552
Deferred income taxes	357,473	298,943
Other long-term liabilities	19,194	3,847
Total long-term liabilities	1,232,029	774,296
Commitments and contingencies
CVR stockholders' equity:
Common stock $0.01 par value per share, 350,000,000 shares authorized, 86,906,760 and 86,435,672 shares issued, respectively	869	864
Additional paid-in-capital	587,199	467,871
Retained earnings	566,855	221,079
Treasury stock, 98,610 and 21,891 shares, respectively, at cost	(2,303)	(243)
Accumulated other comprehensive income, net of tax	(1,008)	2
Total CVR stockholders' equity	1,151,612	689,573
Noncontrolling interest	148,091	10,600
Total equity	1,299,703	700,173
Total liabilities and equity	$ 3,119,291	$ 1,740,184

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2011	Dec. 31, 2010
CONSOLIDATED BALANCE SHEETS
Accounts receivable, allowance for doubtful accounts (in dollars)	$ 1,282	$ 722
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	86,906,760	86,435,672
Treasury stock shares	98,610	21,891

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010	Sep. 30, 2010	Jun. 30, 2010	Mar. 31, 2010	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Net sales	$ 1,062,168	$ 1,351,964	$ 1,447,716	$ 1,167,265	$ 1,148,184	$ 1,031,174	$ 1,005,898	$ 894,512	$ 5,029,113	$ 4,079,768	$ 3,136,329
Operating costs and expenses:
Cost of product sold (exclusive of depreciation and amortization)	857,277	1,026,040	1,123,375	936,822	983,726	889,850	891,652	802,890	3,943,514	3,568,118	2,547,695
Direct operating expenses (exclusive of depreciation and amortization)	124,796	74,615	66,207	68,434	64,216	52,534	62,479	60,562	334,052	239,791	226,657
Insurance recovery - business interruption		(490)		(2,870)					(3,360)
Selling, general and administrative expenses (exclusive of depreciation and amortization)	28,973	17,584	18,171	33,262	43,450	16,397	10,793	21,394	97,990	92,034	68,918
Depreciation and amortization	24,242	22,025	22,043	22,011	22,005	21,943	21,553	21,260	90,321	86,761	84,873
Total operating costs and expenses	1,035,288	1,139,774	1,229,796	1,057,659	1,113,397	980,724	986,477	906,106	4,462,517	3,986,704	2,928,143
Operating income	26,880	212,190	217,920	109,606	34,787	50,450	19,421	(11,594)	566,596	93,064	208,186
Other income (expense):
Interest expense and other financing costs	(14,657)	(13,757)	(14,205)	(13,190)	(13,717)	(13,863)	(12,766)	(9,922)	(55,809)	(50,268)	(44,237)
Interest income	(89)	93	211	274	603	549	643	416	489	2,211	1,717
Gain (loss) on derivatives, net	103,179	(9,925)	6,932	(22,106)	(9,320)	(1,014)	7,339	1,490	78,080	(1,505)	(65,286)
Loss on extinguishment of debt			(170)	(1,908)	(1,595)		(14,552)	(500)	(2,078)	(16,647)	(2,101)
Other income, net	124	243	246	231	517	17	642	42	844	1,218	310
Total other income (expense)	88,557	(23,346)	(6,986)	(36,699)	(23,512)	(14,311)	(18,694)	(8,474)	21,526	(64,991)	(109,597)
Income before income taxes	115,437	188,844	210,934	72,907	11,275	36,139	727	(20,068)	588,122	28,073	98,589
Income tax expense	37,103	68,603	76,738	27,119	8,981	12,932	(425)	(7,705)	209,563	13,783	29,235
Net income	78,334	120,241	134,196	45,788	$ 2,294	$ 23,207	$ 1,152	$ (12,363)	378,559	14,290	69,354
Less: Net income attributable to noncontrolling interest	12,476	10,976	9,331						32,783
Net income attributable to CVR Energy Stockholders	$ 65,858	$ 109,265	$ 124,865	$ 45,788					$ 345,776	$ 14,290	$ 69,354
Basic earnings per share (in dollars per share)	$ 0.76	$ 1.26	$ 1.44	$ 0.53	$ 0.03	$ 0.27	$ 0.01	$ (0.14)	$ 4.00	$ 0.17	$ 0.80
Diluted earnings per share (in dollars per share)	$ 0.75	$ 1.25	$ 1.42	$ 0.52	$ 0.03	$ 0.27	$ 0.01	$ (0.14)	$ 3.94	$ 0.16	$ 0.80
Weighted-average common shares outstanding:
Basic (in shares)	86,852,800	86,549,846	86,422,881	86,413,781	86,352,627	86,343,102	86,336,125	86,329,237	86,493,735	86,340,342	86,248,205
Diluted (in shares)	87,746,843	87,743,600	87,789,351	87,783,857	87,121,094	87,013,575	86,506,590	86,329,237	87,766,573	86,789,179	86,342,433

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	Comprehensive Income
Balance at Dec. 31, 2008	$ 590,067	$ 579,467	$ 862	$ 441,170	$ 137,435			$ 10,600
Balance (in shares) at Dec. 31, 2008			86,243,745
Increase (Decrease) in Stockholders' Equity
Share-based compensation	4,614	4,614		4,614
Issuance of common stock to Directors	480	480	$ 1	479
Issuance of common stock to Directors (in shares)			73,284
Purchase of treasury stock	(100)	(100)				$ (100)
Vesting of non-vested stock awards (in shares)			27,479
Comprehensive income
Net income	69,354	69,354			69,354
Other comprehensive income, net of tax
Comprehensive income (loss)	69,354
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
Comprehensive income
Net income	14,290	14,290			14,290				$ 14,290
Other comprehensive income, net of tax
Unrealized gains on available-for-sale securities, net of tax	2	2					$ 2		2
Comprehensive income (loss)	14,292	14,292							14,292
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		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)
Comprehensive income
Net income	378,559	345,776			345,776			32,783	378,559
Other comprehensive income, net of tax
Unrealized gains on available-for-sale securities, net of tax	(1)	(1)					(1)		(1)
Unrealized gains (losses) on hedging instruments	(1,732)	(1,009)					(1,009)	(723)	(1,732)
Comprehensive income (loss)	376,826	344,766			345,776		(1,010)	32,060	$ 376,826
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		86,906,760

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Cash flows from operating activities:
Net income	$ 378,559	$ 14,290	$ 69,354
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	90,321	86,761	84,873
Allowance for doubtful accounts	561	(414)	644
Amortization of deferred financing costs	4,566	3,356	1,941
Amortization of original issue discount	512	356
Amortization of original issue premium	(148)
Deferred income taxes	62,688	(770)	(7,282)
Excess income tax benefit of share-based compensation	(2,270)	(141)
Loss on disposition of assets	3,452	3,536	41
Loss on extinguishment of debt	2,078	16,647	2,101
Share-based compensation	27,173	37,244	7,935
Unrealized (gain) loss on derivatives	(85,262)	(634)	37,791
Changes in assets and liabilities:
Restricted cash			34,560
Accounts receivable	55,435	(34,026)	(13,057)
Inventories	(175,543)	27,666	(126,414)
Prepaid expenses and other current assets	(8,776)	(13,080)	12,104
Insurance receivable	(12,325)	(7,070)
Insurance proceeds for flood			11,756
Insurance proceeds for UAN reactor rupture		3,161
Business interruption insurance proceeds	3,360
Insurance proceeds on Coffeyville Refinery incident	4,000
Other long-term assets	(1,649)	105	862
Accounts payable	5,805	47,938	5,650
Accrued income taxes	(35,750)	28,841	19,996
Deferred revenue	(9,659)	8,396	4,541
Other current liabilities	(27,253)	3,588	3,027
Payable to swap counterparty			(65,016)
Accrued environmental liabilities	(1,093)	(276)	(1,412)
Other long-term liabilities	(227)	(46)	1,279
Net cash provided by operating activities	278,555	225,428	85,274
Cash flows from investing activities:
Capital expenditures	(91,224)	(32,409)	(48,773)
Proceeds from sale of assets	57	37	481
Insurance proceeds for UAN reactor rupture	2,745	1,114
Acquisition of Gary-Williams	(585,987)
Net cash used in investing activities	(674,409)	(31,258)	(48,292)
Cash flows from financing activities:
Revolving debt payments		(60,000)	(87,200)
Revolving debt borrowings		60,000	87,200
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
Principal payments on long-term debt		(507,003)	(4,825)
Principal payments on senior secured notes	(2,700)
Payment of capital lease obligations	(4,897)	(193)	(100)
Payment of financing costs	(15,133)	(8,775)	(3,975)
Repurchase of common stock	(3,535)	(215)	(100)
Excess tax benefit of share-based compensation	2,270	141
Deferred costs of CVR Partners' initial public offering		(674)
Purchase of managing general partner interest and 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	(21,630)
Redemption of common units	(121)
Net cash provided by (used in) financing activities	584,133	(31,026)	(9,000)
Net increase in cash and cash equivalents	188,279	163,144	27,982
Cash and cash equivalents, beginning of period	200,049	36,905	8,923
Cash and cash equivalents, end of period	388,328	200,049	36,905
Supplemental disclosures
Cash paid for income taxes, net of refunds (received)	182,622	(14,285)	16,521
Cash paid for interest net of capitalized interest of $3,877, $1,827 and $2,020 for the years ended December 31, 2011, 2010 and 2009, respectively	45,230	45,352	40,537
Cash funding of margin account for other derivative activities, net of withdrawals	4,314	2,649	4,956
Non-cash investing and financing activities:
Accrual of construction in progress additions	19,054	653	$ (5,040)
Assets acquired through capital lease		415
Reduction of proceeds from senior notes for underwriting discount and financing costs	$ 4,000	10,287
Receipt of marketable securities		$ 23

CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
CONSOLIDATED STATEMENTS OF CASH FLOWS
Capitalized interest	$ 3,877	$ 1,827	$ 2,020

Organization and History of the Company

12 Months Ended

Dec. 31, 2011

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.

The Company, through its wholly-owned subsidiaries, acts as an independent petroleum refiner and marketer of high value transportation fuels in the mid-continental United States. In addition, the Company, through its majority-owned subsidiaries, acts as an independent producer and marketer of upgraded nitrogen fertilizer products in North America. 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 New York Stock Exchange 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 December 15, 2011, CVR acquired all of the issued and outstanding shares of Gary-Williams Energy Corporation (subsequently converted to Gary-Williams Energy Company, LLC or "GWEC") for a preliminary purchase price of $592.3 million. 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. Assets acquired include a 70,000 bpd refinery in Wynnewood, Oklahoma and approximately 2.0 million barrels of company-owned storage tanks. See Note 3 ("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, LP, a Delaware limited partnership ("CVR Partners" or the "Partnership"), 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. This interest was classified as a noncontrolling interest that was included as a separate component of equity in the Consolidated Balance Sheet at December 31, 2010. On April 13, 2011, the Partnership completed its initial public offering of 22,080,000 common units (the "Partnership IPO") priced at $16.00 per unit. The common units, which are listed on the New York Stock Exchange, began trading on April 8, 2011 under the symbol "UAN". In connection with the Partnership IPO, the IDRs were purchased by the 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 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 Partnership at the time of the 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 Partnership.

At December 31, 2011, the Partnership had 73,030,936 common units outstanding, consisting of 22,110,936 common units owned by the public, representing approximately 30% of the total Partnership units and 50,920,000 common units owned by CRLLC, representing approximately 70% of the total Partnership units.

The gross proceeds to the Partnership from the Partnership IPO were approximately $353.3 million, before giving effect to underwriting discounts and commissions and offering expenses. In connection with the Partnership IPO, the 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 Partnership IPO. Until completion of CVR's February 2011 secondary offering, an affiliate of GS was a stockholder and related party of the Company. As a result of the Partnership IPO and as of the date of this Report, CVR indirectly owns approximately 70% of the Partnership's outstanding common units and 100% of the Partnership's general partner, CVR GP, LLC, which only holds a non-economic general partner interest.

On February 13, 2012, CVR announced its intention to sell a portion of its investment in the Partnership and use the proceeds to pay a special dividend to holders of its common stock and to strengthen its balance sheet. There can be no assurance as to the terms, conditions, amount or timing of such sale or dividend, or whether such sale or dividend will take place at all. This announcement does not constitute an offer of any securities for sale and is being made in accordance with Rule 135 under the Securities Act.

In connection with the Partnership IPO, the Partnership's limited partner interests were converted into common units, the Partnership's special general partner interests were converted into common units, and the 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 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 Partnership IPO, the 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 Partnership's general partner.

The proceeds from the Partnership IPO were utilized as follows:

•

approximately $18.4 million was distributed to CRLLC to satisfy the 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 senior secured notes required upon the consummation of the Partnership IPO;

•

$26.0 million was used by the 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 Partnership's credit facility; and

•

the balance of the proceeds are being utilized by the Partnership for general partnership purposes, including the funding of the UAN expansion that is expected to require an investment of approximately $135.0 million, of which approximately $43.6 million had been spent as of December 31, 2011.

The Partnership has adopted a policy pursuant to which the 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 Partnership's general partner following the end of such quarter. The partnership agreement does not require that the Partnership make cash distributions on a quarterly or other basis.

The 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 Partnership. The Partnership's general partner, CVR GP, LLC, manages the operations and activities of the 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 will be 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 Partnership. CVR, the 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 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
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+ Details

Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2011

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 interest. Certain prior year amounts have been reclassified to conform to current year presentation.

Prior to the Partnership IPO, management had determined that the 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 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 Partnership in CVR's consolidated financial statements for the periods presented prior to the Partnership IPO.

Subsequent to the Partnership IPO, the Partnership is no longer considered a VIE. The consolidation of the 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 Partnership. Additionally, the Partnership's general partner manages the operations and activities of the 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 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 will be 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 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.

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 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, 2011, no customers individually represented greater than 10% of the total accounts receivable balance. At December 31, 2010, two customers individually represented greater than 10% and collectively represented 22% of the total accounts receivable balance. The largest concentration of credit for any one customer at December 31, 2011 and 2010 was approximately 9% and 12%, 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 receivables, current portions of prepaid insurance and deferred financing costs, 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 the impairment test. The Company performed its annual impairment review of goodwill for 2011, which is attributable entirely to the nitrogen fertilizer segment and concluded there was no impairment. Additionally, there was also no impairment charge recognized in 2010 or 2009, with respect to the nitrogen fertilizer segment. See Note 7 ("Goodwill and Intangible Assets") for further discussion.

Deferred Financing Costs, Underwriting and Original Issue Discount

Deferred financing costs related to the first priority term debt credit facility, CRNF credit facility and senior secured notes 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 the issuance of senior secured notes are 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 first priority revolving credit facility, 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. Deferred financing costs related to the first priority funded letter of credit facility were amortized to interest expense and other financing costs using the straight-line method through the termination of the facility in October 2009.

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. During the years ended December 31, 2011, the Coffeyville refinery completed the first phase of a two-phase major scheduled turnaround. Costs of approximately $66.4 million and $1.2 million associated with the Coffeyville refinery's 2011 turnaround were included in direct operating expenses (exclusive of depreciation and amortization) for the year ended December 31, 2011 and 2010, respectively. During the year ended December 31, 2010, the nitrogen fertilizer plant completed a major scheduled turnaround. Costs of approximately $3.5 million associated with the nitrogen fertilizer plant's 2010 turnaround were included in direct operating expenses (exclusive of depreciation and amortization) for the year ended December 31, 2010.

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 Wynnewood refinery's next major maintenance activities are scheduled for fourth quarter 2012.

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 $2.5 million, $2.8 million and $2.9 million for the years ended December 31, 2011, 2010 and 2009, 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 $86.0 million, $81.8 million and $79.9 million for the years ended December 31, 2011, 2010 and 2009, respectively.

Selling, general and administrative expenses (exclusive of depreciation and amortization) consist primarily of legal expenses, treasury, accounting, marketing, human resources and maintaining the corporate and administrative office in Texas and the administrative offices in Kansas and Oklahoma. Selling, general and administrative expenses exclude depreciation and amortization of approximately $1.8 million, $2.1 million and $2.0 million for the years ended December 31, 2011, 2010 and 2009, 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 12 ("Income Taxes") for further discussion.

Impairment of Long-Lived Assets

CVR accounts for long-lived assets in accordance with accounting standards issued by the FASB regarding the treatment of the impairment or disposal of long-lived assets. As required by this standard, CVR 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 assumed. 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

CVR 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 its $125 million floating rate term debt which matures in April 2016. The aggregate notional amount covered under these agreements totals $62.5 million (split evenly between the two agreement dates) and commenced on August 12, 2011 and expires on February 12, 2016. 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 13 ("Long-Term Debt") for further discussion of the extinguishment of the first priority credit facility long-term debt and issuance of senior secured notes. The senior secured notes are carried at the aggregate principal value less the unamortized original issue discount or premium. See Note 13 ("Long-Term Debt") for the fair value of the senior secured notes.

Share-Based Compensation

CVR accounts for share-based compensation in accordance with standards issued by the Financial Accounting Standards Board ("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 Partnership IPO, no further amounts will be allocated by CALLC, CALLC II or CALLC III.

Non-vested shares, when granted, are 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, generally a three-year period.

The Partnership grants certain awards out of its Long-Term Incentive Plan ("CVR Partners LTIP"). Phantom units granted to employees of the Partnership are valued at closing unit price on the date of grant and amortized to compensation expense on a straight-line basis over the vesting period of the awards.

Awards granted to employees of the Partnership's general partner or to the directors of its general partner are considered non-employee awards and are marked-to-market each reporting period until they vest.

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.

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 changes the wording used to describe many of the requirements in U.S. GAAP for measuring fair value and for disclosing information about fair value measurements to ensure consistency between U.S. GAAP and International Financial Reporting Standards ("IFRS"). ASU 2011-04 also expands the disclosures for fair value measurements that are estimated using significant unobservable (Level 3) inputs. This new guidance is to be applied prospectively. ASU 2011-04 will be effective for interim and annual periods beginning after December 15, 2011. The Company believes that the adoption of this standard will not materially expand its 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. ASU 2011-05 will be effective for interim and annual periods beginning after December 15, 2011. The Company believes that the adoption of ASU 2011-05 will not have a material impact on the Company's consolidated financial statements.

In September 2011, the FASB issued ASU No. 2011-08, "Intangibles — Goodwill and Other (Topic 350): Testing Goodwill for Impairment," ("ASU 2011-08"). ASU 2011-08 permits an entity to make a qualitative assessment of whether it is more likely than not that a reporting unit's fair value is less than its carrying amount before applying the two-step goodwill impairment test. This new guidance is to be applied prospectively. ASU 2011-08 will be effective for interim and annual periods beginning after December 15, 2011, with early adoption permitted. The Company adopted this standard on October 1, 2011. The adoption of this standard did not impact the Company's financial position or results of operations.

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 U.S. GAAP with those prepared under IFRS. This new guidance is to be applied retrospectively. ASU 2011-11 will be effective for interim and annual periods beginning January 1, 2013. The Company believes this standard will expand its consolidated financial statement footnote disclosures.

Wynnewood Acquisition

12 Months Ended

Dec. 31, 2011

Wynnewood Acquisition

Wynnewood Acquisition

(3) Wynnewood Acquisition

On December 15, 2011, the Company completed the acquisition of all the issued and outstanding shares of GWEC, 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 9% First Lien Senior Secured Notes. See Note 13 ("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 GWEC'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.

GWEC owns 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 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. The Company believes the Wynnewood Acquisition will provide the Company with high quality, recently upgraded assets, which will increase the Company's scale and operational diversity, generate significant operating synergies, and contribute significant operating cash flow.

Purchase Price Allocation

Under the purchase method of accounting, the total preliminary purchase price was allocated to GWEC's net tangible assets based on their fair values as of December 15, 2011. An independent appraisal of the net assets acquired has been completed. The following table, set forth below, displays the total preliminary purchase price allocated to GWEC's net tangible assets based on their fair values as of December 15, 2011 (in millions):


Cash and cash equivalents	$	6.3
Accounts receivable		158.5
Inventories		213.5
Prepaid expenses and other current assets		6.0
Property, plant and equipment		574.5
Accounts payable and accrued liabilities		(314.2	)
Long-term debt		(52.3	)

Total fair values of net assets acquired		592.3

Less: cash acquired		6.3

Total consideration transferred, net of cash acquired	$	586.0

The purchase price includes a preliminary net working capital amount anticipated to be finalized in the first quarter of 2012. In accordance with the Stock Purchase and Sale Agreement, (the "Purchase Agreement"), the Company provided a Post-Closing Statement on February 13, 2012, to Seller which reflects the difference of the cash paid at closing for the estimated working capital as compared to the Company's net working capital acquired. This difference is approximately $15.8 million and has been recorded in prepaid expenses and other current assets in the Consolidated Balance Sheet at December 31, 2011. The Seller has 30 days from February 13, 2012 to review the Post-Closing Statement and contest it or pay the amount due the Company. Any difference between the estimated amount and the final settlement will be adjusted in the fair market value of tangible or intangible long-lived assets.

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		473.8		22.0

Acquisition Costs

As of December 31, 2011, CVR has recognized approximately $5.2 million in transaction fees and preliminary integration expenses that are included in selling, general and administrative expense in the Consolidated Statement of Operations. 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
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-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
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Reference 3: http://www.xbrl.org/2003/role/presentationRef
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Reference 4: http://www.xbrl.org/2003/role/presentationRef
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Reference 14: http://www.xbrl.org/2003/role/presentationRef
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-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
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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, 2011

Share-Based Compensation

Share-Based Compensation

(4) 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 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, 2010 and 2009, 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 7,988,179 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 has been incurred with respect to override units and phantom units after each respective divestiture date. 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 value, resulting from the proceeds received by the general partner upon the purchase of the IDR's by the Partnership. These proceeds were subsequently distributed to the owners of CALLC III which includes the override unitholders. This value was utilized to determine the related compensation expense for the unvested units. No additional share-based compensation has been or will be 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. For the year ended December 31, 2010, the estimated fair value of the CALLC III override units were determined using a probability-weighted expected return method which utilized CALLC III's cash flow projections and also considered the proposed initial public offering of the Partnership, including the purchase of the managing GP interest (including the IDRs). For the year ended December 31, 2009, the estimated fair value of the override units of CALLC III was determined using a probability-weighted expected return method which utilized CALLC III's cash flow projections.

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 Increase (Decrease) for the Year Ended December 31,

	Benchmark Value (per Unit)		Original Awards Issued
Award Type	Benchmark Value (per Unit)		Original Awards Issued		Grant Date	2011		2010		2009
						(in thousands)
Override Operating Units(a)	$	11.31		919,630	June 2005	$	—	$	338	$	1,369
Override Operating Units(b)	$	34.72		72,492	December 2006		—		13		36
Override Value Units(c)	$	11.31		1,839,265	June 2005		4,960		17,586		2,690
Override Value Units(d)	$	34.72		144,966	December 2006		451		581		37
Override Units(e)	$	10.00		642,219	February 2008		184		772		26

					Total	$	5,595	$	19,290	$	4,158

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, 2011.

Valuation Assumptions

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

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

	2009			2009
Estimated forfeiture rate		None			None
CVR closing stock price	$	6.86		$	6.86
Estimated weighted-average fair value (per unit)	$	11.95		$	1.40
Marketability and minority interest discounts		20.0	%		20.0	%
Volatility		50.7	%		50.7	%

On the tenth anniversary of the issuance of override operating units, such units convert into an equivalent number of override value units. Override operating units are forfeited upon termination of employment for cause. As of December 31, 2010 these units were fully vested.

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

	(c) Override Value Units December 31,						(d) Override Value Units December 31,

	2010			2009			2010			2009
Estimated forfeiture rate		None			None			None			None
Derived service period		6 years			6 years			6 years			6 years
CVR closing stock price	$	15.18		$	6.86		$	15.18		$	6.86
Estimated weighted-average fair value (per unit)	$	22.39		$	5.63		$	6.56		$	1.39
Marketability and minority interest discounts		20.0	%		20.0	%		20.0	%		20.0	%
Volatility		43.0	%		50.7	%		43.0	%		50.7	%

(e) Override Units — Using a probability-weighted expected return method which utilized CALLC III's cash flow projections and included 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 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	2009
Estimated forfeiture rate	None	None
Derived Service Period	Based on forfeiture schedule	Based on forfeiture schedule
Estimated fair value (per unit)	$2.60	$0.08
Marketability and minority interest discount	10.0%	20.0%
Volatility	47.6%	59.7%

Phantom Unit Appreciation Plan

CVR, through a wholly-owned subsidiary, has two Phantom Unit Appreciation Plans (the "Phantom Unit Plans") whereby directors, employees, and service providers may be awarded phantom points at the discretion of the board of directors or the compensation committee. Holders of service phantom points have rights to receive distributions when CALLC and CALLC II holders of override operating units receive distributions. Holders of performance phantom points have rights to receive distributions when CALLC and CALLC II holders of override value units receive distributions. There are no other rights or guarantees, and the plans expire on July 25, 2015, or at the discretion of the compensation committee of the board of directors. 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. In November 2009, CALLC II completed a sale of common shares of CVR as afforded by a registered offering into the public market. As a result of this sale, the Company made a payment to phantom unit holders totaling approximately $0.9 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. 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, 2011. CVR has recorded approximately $0.0 and $18.7 million in personnel accruals as of December 31, 2011 and 2010, respectively. Compensation expense for the years ended December 31, 2011, 2010 and 2009 related to the Phantom Unit Plans was approximately $10.6 million, $15.5 million and $3.7 million, respectively.

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		2009
Service Phantom interest (per point)	$	14.64	$	11.37
Performance Phantom interest (per point)	$	21.25	$	5.48

Long-Term Incentive Plan

CVR has a Long-Term Incentive Plan ("LTIP"), which permits the grant of options, stock appreciation rights, non-vested shares, non-vested share units, dividend equivalent rights, share awards and performance awards (including performance share units, performance units and performance-based restricted stock). As of December 31, 2011, only restricted shares of CVR common stock 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, 2011, 5,176,087 shares of common stock were available for issuance under the LTIP.

Restricted Stock

A summary of restricted stock grant activity and changes during the years ended December 31, 2011, 2010 and 2009 is presented below:

			Weighted- Average Grant-Date Fair Value		Aggregate Intrinsic Value (in thousands)

Non-vested at December 31, 2008	78,666		$	6.62	$	315

Granted	202,257			6.68
Vested	(100,763	)		6.86
Forfeited	(3,100	)		4.14

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

As of December 31, 2011, there was approximately $19.5 million of total unrecognized compensation cost related to non-vested shares to be recognized over a weighted-average period of approximately two years. The aggregate fair value at the grant date of the shares that vested during the year ended December 31, 2011 was approximately $6.6 million. As of December 31, 2011, 2010 and 2009, unvested stock outstanding had an aggregate fair value at grant date of approximately $23.9 million, $15.0 million and $1.2 million, respectively. Total compensation expense for the years ended December 31, 2011, 2010 and 2009, related to the non-vested stock was approximately $9.8 million, $2.4 million and $0.8 million, respectively.

Stock Options

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

			Weighted- Average Exercise Price

Outstanding, December 31, 2008	32,350		$	19.08	9.21

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

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

Exercisable at December 31, 2011	22,900		$	18.03	7.35

There were no grants of stock options in 2011, 2010 or 2009. The weighted-average grant-date fair value of options granted during the year ended December 31, 2008 was $8.97 per share. The aggregate intrinsic value of options exercisable at December 31, 2011, was approximately $70,000. Total compensation expense for the years ended December 31, 2011, 2010 and 2009, related to the stock options was $8,000, $9,000 and $118,000, respectively.

CVR Partners Long-Term Incentive Plan

In April 2011, the board of directors of the 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 employees, officers, consultants and directors of CVR Partners and its general partner and their respective subsidiaries' parents. 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.

In April 2011, 23,448 phantom units were granted to certain board members of the Partnership's general partner. These phantom unit awards granted to the directors of the general partner are considered non-employee equity-based awards since the directors are not elected by unitholders. These phantom unit director awards were required to be marked-to-market each reporting period until they vested on October 12, 2011.

In June 2011, 50,659 phantom units were granted to an employee of the general partner. These phantom units are expected to vest over three years on the basis of one-third of the award each year. As this phantom unit award, which is an equity-based award, was granted to an employee of a subsidiary of the Company, it was valued at the closing unit price of the Partnership's common units on the date of grant and will be amortized to compensation expense on a straight-line basis over the vesting period of the award.

In June 2011, 2,956 fully vested common units were granted to certain board members of the general partner. The fair value of these awards was calculated using the closing price of the Partnership's common units on the date of grant. This amount was fully expensed at the time of grant.

In August 2011, 12,815 phantom units were granted to an employee of the general partner. These phantom units are expected to vest over three years on the basis of one-third of the award each year. As these phantom awards were made to an employee of the general partner, they are considered non-employee equity-based awards and are required to be marked-to-market each reporting period until they vest.

In December 2011, 9,672 fully vested common units were granted to certain board members of the general partner. The fair value of these awards was calculated using the closing price of the Partnership's common units on the date of the grant. The amount was fully expensed at the time of the grant.

In December 2011, 101,097 phantom units were granted to certain employees of the general partner and CRNF and one employee of CVR Energy who dedicated 100% of his time to CVR Partners' business in 2011. These phantom units are expected to vest over three years on the basis of one-third of the award each year. For the phantom unit awards made to employees of the general partner, they are considered non-employee equity-based awards and are required to be marked-to-market each reporting period until they vest. Awards made to employees of CRNF are valued on the grant date and amortized over the vesting period.

Compensation expense recorded for the years ended December 31, 2011, 2010 and 2009, related to the awards under the CVR Partners LTIP was approximately $1.2 million, $0 and $0, respectively. Compensation expense associated with the awards under the CVR Partners' LTIP has been recorded in selling, general and administrative expenses (exclusive of depreciation and amortization).

As of December 31, 2011, there were 4,799,353 common units available for issuance under the CVR Partners LTIP. Unrecognized compensation expense associated with the unvested phantom units at December 31, 2011 was approximately $3.6 million.

- 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, 2011

Inventories

Inventories

(5) Inventories

Inventories consisted of the following:

	December 31,

	2011		2010
	(in thousands)
Finished goods	$	323,315	$	110,788
Raw materials and precious metals		157,931		89,333
In-process inventories		115,372		22,931
Parts and supplies		39,603		24,120

	$	636,221	$	247,172

Property, Plant, and Equipment

12 Months Ended

Dec. 31, 2011

Property, Plant, and Equipment

Property, Plant, and Equipment

(6) Property, Plant, and Equipment

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

	December 31,

	2011		2010
	(in thousands)
Land and improvements	$	26,136	$	19,228
Buildings		37,289		25,663
Machinery and equipment		1,967,269		1,363,877
Automotive equipment		10,217		8,747
Furniture and fixtures		12,349		9,279
Leasehold improvements		1,445		1,253
Railcars		2,496		—
Construction in progress		94,085		42,674

		2,151,286		1,470,721
Accumulated depreciation		478,325		389,409

	$	1,672,961	$	1,081,312

Capitalized interest recognized as a reduction in interest expense for the years ended December 31, 2011, 2010 and 2009 totaled approximately $3.9 million, $1.8 million and $2.0 million, respectively. Land, building and equipment that are under a capital lease obligation had an original carrying value of approximately $24.9 million and $5.2 million as of December 31, 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 and Intangible Assets

12 Months Ended

Dec. 31, 2011

Goodwill and Intangible Assets

Goodwill and Intangible Assets

(7) Goodwill and Intangible Assets

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, 2011, 2010 and 2009. 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, 2011, 2010 and 2009, the annual test of impairment indicated that the goodwill, attributable to the nitrogen fertilizer segment, was not impaired. As of December 31, 2011 and 2010, goodwill included on the Consolidated Balance Sheets totaled approximately $41.0 million.

In 2011, CVR elected early adoption of ASU 2011-08, which allows an alternative in certain situations that simplifies the impairment testing of goodwill. The new 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. 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. 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.

The two-step annual review of impairment for 2010 and 2009 was performed by comparing the carrying value of the applicable reporting unit to its estimated fair value. The valuation analysis used in the analysis utilized a 50% weighting of both income and market approaches as described below:

•

Income Approach: To determine fair value, the Company discounted the expected future cash flows the nitrogen fertilizer segment utilizing observable market data to the extent available. The discount rates used for 2010 and 2009, were 14.6% and 13.4%, respectively, representing the estimated weighted-average costs of capital, which reflects the overall level of inherent risk involved in each reporting unit and the rate of return an outside investor would expect to earn.

•

Market-Based Approach: To determine the fair value of each reporting unit, the Company also utilized a market based approach. The Company used the guideline company method, which focuses on comparing the Company's risk profile and growth prospects to select reasonably similar publicly traded companies.

Other Intangible Assets

Contractual agreements with a fair market value of approximately $1.3 million were acquired in 2005 in connection with the acquisition by CALLC of all outstanding stock owned by Coffeyville Group Holdings, LLC. As of December 31, 2011, accumulated amortization related to these agreements totaled approximately $1.0 million. The intangible value of these agreements is amortized over the life of the agreements through June 2025. Amortization expense of approximately $33,000, $33,000 and $33,000 was recorded in depreciation and amortization for the years ended December 31, 2011, 2010 and 2009, respectively.

- Definition

The entire disclosure for the aggregate amount of goodwill and a description of intangible assets, which may include (a) for amortizable intangible assets (also referred to as finite-lived intangible assets), the carrying amount, the amount of any significant residual value, and the weighted-average amortization period, (b) for intangible assets not subject to amortization (also referred to as indefinite-lived intangible assets), the carrying amount, and (c) the amount of research and development assets acquired and written off in the period, including the line item in the income statement in which the amounts written off are aggregated, if not readily apparent from the income statement. Also discloses (a) for amortizable intangibles assets in total and by major class, the gross carrying amount and accumulated amortization, the total amortization expense for the period, and the estimated aggregate amortization expense for each of the five succeeding fiscal years, (b) for intangible assets not subject to amortization the carrying amount in total and by major class, and (c) for goodwill, in total and for each reportable segment, the changes in the carrying amount of goodwill during the period (including the aggregate amount of goodwill acquired, the aggregate amount of impairment losses recognized, and the amount of goodwill included in the gain (loss) on disposal of a reporting unit). If any part of goodwill has not been allocated to a reportable segment, discloses the unallocated amount and the reasons for not allocating. For each impairment loss recognized related to an intangible asset (excluding goodwill), discloses: (a) a description of the impaired intangible asset and the facts and circumstances leading to the impairment, (b) the amount of the impairment loss and the method for determining fair value, (c) the caption in the income statement or the statement of activities in which the impairment loss is aggregated, and (d) the segment in which the impaired intangible asset is reported. For each goodwill impairment loss recognized, discloses: (a) a description of the facts and circumstances leading to the impairment, (b) the amount of the impairment loss and the method of determining the fair value of the associated reporting unit, and (c) if a recognized impairment loss is an estimate not finalized and the reasons why the estimate is not final. May also disclose the nature and amount of any significant adjustments made to a previous estimate of an impairment loss.

+ References + Details

Deferred Financing Costs and Original Issue Discount

12 Months Ended

Dec. 31, 2011

Deferred Financing Costs and Original Issue Discount

Deferred Financing Costs and Original Issue Discount

(8) Deferred Financing Costs and Original Issue Discount

On December 15, 2011, CRLLC closed on the issuance of an additional $200.0 million of senior secured notes as described below. An original issue premium of $10.0 million was received related to the issuance and will be amortized to interest expense over the remaining term of the senior secured notes. In connection with this issuance, CRLLC incurred an underwriting discount of $4.0 million and third party costs of approximately $2.0 million which will be amortized as interest expense using the effective-interest method over the remaining term of the senior secured notes.

On May 16, 2011, CRLLC repurchased $2.7 million of the senior secured notes at a purchase price of 103% 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. The Company also recorded additional losses on extinguishment of debt of $81,000 in connection with premiums paid for the repurchase.

On April 6, 2010, CRLLC and its wholly-owned subsidiary, Coffeyville Finance Inc., completed a private offering of senior secured notes that had an aggregate principal amount of $500 million. See Note 13 ("Long-Term Debt") for further information regarding the issuance of the Company's senior secured notes. The proceeds of the offering were utilized to extinguish the existing long-term debt under the first priority credit facility. As a result of the extinguishment, CRLLC wrote-off approximately $5.4 million of previously deferred financing costs. In connection with this issuance of the senior secured notes, CRLLC incurred approximately $3.9 million of third party costs. Of these costs, approximately $30,000 was immediately expensed and the remaining approximately $3.9 million was deferred and will be amortized as interest expense using the effective-interest method. In addition, CRLLC incurred an underwriting discount of $10 million. Of these costs approximately $76,000 were immediately expensed at the time of issuance following the accounting standards relating to the modification of debt instruments by debtors. The remaining balance of approximately $9.9 million will be amortized as interest expense using the effective-interest method over the term of the senior secured notes. On December 30, 2010, CRLLC made an unscheduled voluntary prepayment of its senior secured notes of approximately $27.5 million. In connection with the voluntary prepayment, CRLLC wrote off a portion of previously deferred financing costs and unamortized original issue discount of approximately $770,000. As a result of the extinguishment of CRLLC's long-term debt under the first priority credit facility, the issuance of senior secured notes and voluntary unscheduled prepayment on the senior secured notes, the Company recorded a total loss on extinguishment of debt of approximately $6.3 million for the year ended December 31, 2010. In addition, as described in further detail in Note 13 ("Long-Term Debt"), the Company also recorded additional losses on extinguishment of debt of approximately $10.4 million in connection with premiums paid for the early extinguishment of debt for the year ended December 31, 2010.

On March 12, 2010, CRLLC entered into a fourth amendment to its outstanding first priority credit facility. In connection with this amendment, the Company paid approximately $6.0 million of lender and third party costs. CRLLC recorded an expense of approximately $1.1 million primarily associated with third party costs in 2010. The remaining costs incurred of approximately $4.9 million were deferred to be amortized as interest expense using the effective-interest method for the first priority credit facility long-term debt and the straight-line method for the first priority revolving credit facility.

On October 2, 2009, CRLLC entered into a third amendment to its outstanding first priority credit facility. In connection with this amendment, the Company paid approximately $4.0 million of lender and third party costs. CRLLC recorded an expense of approximately $1.0 million primarily associated with third party costs in 2009. The remaining costs incurred of approximately $3.0 million were deferred and amortized as interest expense using the effective-interest method for the first priority credit facility long-term debt and the straight-line method for the first priority revolving credit facility. In connection with the reduction and eventual termination of the first priority funded letter of credit facility on October 15, 2009, CRLLC recorded a loss on the extinguishment of debt of approximately $2.1 million for the year ended December 31, 2009. The loss on extinguishment is attributable to amounts previously deferred at the time of the original credit facility, as well as amounts deferred at the time of the second and third amendments.

For the years ended December 31, 2011, 2010 and 2009, amortization of deferred financing costs reported as interest expense and other financing costs totaled approximately $4.9 million, $3.7 million and $1.9 million, respectively.

Estimated amortization of deferred financing costs is as follows:

Year Ending December 31,	Deferred Financing

	(in thousands)
2012		7,382
2013		7,373
2014		7,373
2015		4,189
2016		1,151
Thereafter		233

	$	27,701

Note Payable and Capital Lease Obligations

12 Months Ended

Dec. 31, 2011

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 $8.8 million related to this note. The Company entered into an insurance premium finance agreement in July 2010 to finance a portion of the purchase of its 2010/2011 property insurance policies. The original balance of the note provided by the Company under such agreement was $5.0 million. The Company began to repay this note in equal installments commencing October 1, 2010. As of December 31, 2010, the Company owed approximately $3.1 million related to this note.

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. During 2010, the Company entered two lease agreements for information technology equipment that are accounted for as capital leases. The initial capital lease obligation of these agreements totaled approximately $0.4 million. The two capital leases entered into during 2010 have terms of 12 and 36 months. As of December 31, 2011, the outstanding capital lease obligation associated with these leases totaled $0.1 million.

The Company also entered into a capital lease for real property used for corporate purposes on May 29, 2008. The lease had an initial lease term of one year with an option to renew for three additional one-year periods. During the second quarter of 2010, the Company renewed the lease for a one-year period commencing June 5, 2010. The Company was obligated to make quarterly lease payments that totaled approximately $0.1 million annually. The Company also had the option to purchase the property during the term of the lease, including the renewal periods. The capital lease obligation was approximately $4.6 million as of December 31, 2010. In March 2011, the Company exercised its purchase option and paid approximately $4.7 million to satisfy the lease obligation.

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 213 and 214 months, respectively. As of December 31, 2011, the outstanding obligation associated with these arrangements totaled approximately $53.2 million. See Note 13 ("Long-Term Debt") for additional information.

Flood

12 Months Ended

Dec. 31, 2011

Flood

Flood

(10) Flood

For the years ended December 31, 2011, 2010 and 2009, the Company recorded pre-tax expenses, net of anticipated insurance recoveries of approximately $1.5 million, $(1.0) million and $0.6 million, respectively, associated with the June/July 2007 flood and associated crude oil discharge. The costs are reported in direct operating expenses in the Consolidated Statements of Operations. With the final insurance proceeds received under the Company's property insurance policy and builders' risk policy during the first quarter of 2009, in the amount of approximately $11.8 million, all property insurance claims and builders' risk claims were fully settled, with all remaining claims closed under these policies only.

At December 31, 2011, the remaining receivable from the environmental insurance carriers was not anticipated to be collected in the next twelve months, and therefore has been classified as a non-current asset. See Note 17 ("Commitments and Contingencies") for additional information regarding environmental and other contingencies related to the crude oil discharge that occurred on July 1, 2007.

Insurance Claims

12 Months Ended

Dec. 31, 2011

Insurance Claims

Insurance Claims

(11) 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. All operations at the nitrogen fertilizer facility were immediately shut down. No one was injured in the incident. Repairs to the facility as a result of the rupture were substantially complete as of December 31, 2010.

Total gross costs recorded as of December 31, 2011 due to the incident were approximately $11.4 million for repairs and maintenance and other associated costs. Approximately $10.5 million of these costs were recognized in the year ended December 31, 2010 and approximately $0.9 million of these costs was recognized during the year ended December 31, 2011. The repairs and maintenance costs incurred are included in direct operating expenses (exclusive of depreciation and amortization). Of the gross costs incurred, approximately $4.5 million was capitalized in 2010 and approximately $0.1 million was capitalized in 2011.

The Company maintains property damage insurance under CVR Energy's insurance policies which have an associated deductible of $2.5 million. The Company anticipates that substantially all of the repair costs in excess of the $2.5 million deductible should be covered by insurance. As of December 31, 2011, approximately $7.0 million of insurance proceeds have been received related to this incident. Approximately $2.7 million of these proceeds were received during the year ended December 31, 2011. The remaining $4.3 million was received during December 2010. The recording of the insurance proceeds resulted in a reduction of direct operating expenses (exclusive of depreciation and amortization).

The insurance policies also provide coverage for interruption to the business, including lost profits, and reimbursement for other expenses and costs the Company has incurred relating to the damage and losses suffered for business interruption. This coverage, however, only applies to losses incurred after a business interruption of 45 days. A partial business interruption claim was filed during 2011 resulting in receipt of proceeds totaling $3.4 million for the year ended December 31, 2011. The proceeds associated with the business interruption claim are included on the Consolidated Statements of Operations under Insurance recovery — business interruption.

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. As discussed above, the Company maintains property damage insurance policies which have an associated deductible of $2.5 million. The Company anticipates that substantially all of the costs in excess of the deductible should be covered by insurance. As of December 31, 2011, the Company has received $4.0 million of insurance proceeds and has recorded an insurance receivable related to the incident of approximately $1.2 million. 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).

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. 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. As of December 31, 2011, the Company has 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).

Income Taxes

12 Months Ended

Dec. 31, 2011

Income Taxes

Income Taxes

(12) Income Taxes

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

	Year Ended December 31,

	2011		2010			2009
	(in thousands)
Current
Federal	$	141,305	$	13,434		$	33,651
State		7,972		1,262			2,866

Total current		149,277		14,696			36,517

Deferred
Federal		40,350		808			(6,613	)
State		19,936		(1,721	)		(669	)

Total deferred		60,286		(913	)		(7,282	)

Total income tax expense	$	209,563	$	13,783		$	29,235

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,

	2011			2010			2009
	(in thousands)
Tax computed at federal statutory rate	$	205,843		$	9,826		$	34,506
State income taxes, net of federal tax benefit		20,600			1,923			5,402
State tax incentives, net of federal tax expense		(3,174	)		(2,382	)		(3,205	)
Domestic production activities deduction		(10,562	)		(2,025	)		(3,798	)
Federal tax credit for production of ultra-low sulfur diesel fuel		—			—			(4,783	)
Non-deductible share-based compensation		2,000			6,747			1,457
IRS interest (income)/expense, net		34			(814	)		—
Noncontrolling interest		(11,474	)		—			—
Partnership basis adjustment		4,174			—			—
Other, net		2,122			508			(344	)

Total income tax expense	$	209,563		$	13,783		$	29,235

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 $3.2 million, $2.4 million and $3.2 million on a credit of approximately $4.9 million, $3.7 million and $4.9 million for the years ended December 31, 2011, 2010 and 2009, respectively.

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, 2011 and 2010 are as follows:

	Year Ended December 31,

	2011			2010
	(in thousands)
Deferred income tax assets:
Allowance for doubtful accounts	$	475		$	286
Personnel accruals		6,437			10,389
Inventories		2,097			469
Unrealized derivative losses, net		—			1,604
Low sulfur diesel fuel credit carry forward and other general business credit carryforward		—			23,653
Accrued expenses		101			199
State tax credit carryforward, net of federal expense		17,682			29,955
Deferred financing		76			101
Other		2,695			3,018

Total gross deferred income tax assets		29,563			69,674

Deferred income tax liabilities:
Unrealized derivative gains, net		(31,990	)		—
Property, plant, and equipment		(224,452	)		(323,839	)
Investment in CVR Partners		(134,920	)		—
Prepaid expenses		(4,945	)		(1,427	)

Total gross deferred income tax liabilities		(396,307	)		(325,266	)

Net deferred income tax liabilities	$	(366,744	)	$	(255,592	)

At December 31, 2011, CVR has Kansas state income tax credits of approximately $27.2 million, which are available to reduce future Kansas state regular income taxes. These credits, if not used, will expire in 2024 to 2027.

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, 2011 and 2010.

As a result of the sale of common stock of the Company's two largest shareholders through a registered public offering in February 2011, a change of ownership occurred as described in Internal Revenue Code ("IRC") Sections 382 and 383. As a result of this ownership change, it is estimated that the annual limitation for the use of general business federal tax credit carryforwards approximates $24.0 million. CVR believes that all credits subject to this limitation will be fully utilized and no valuation allowance is needed.

During 2011, CVR recognized income tax benefits related to the deductibility of stock-based compensation in the amount $2.3 million, which was recorded as an increase in additional paid-in capital and a reduction of income taxes payable.

CVR recognizes interest expense (income) and penalties on uncertain tax positions and income tax deficiencies (refunds) in income tax expense. CVR recognized interest expense in 2011 of approximately $0.1 million of federal and state interest expense and penalties. CVR recognized interest income in 2010 of approximately $1.3 million related to 2005 and 2006 amended returns to carryback 2007 losses. CVR recognized other immaterial amounts of state interest and penalties in 2010 and 2009 for uncertain tax positions or income tax deficiencies. At December 31, 2011, the Company's tax filings are generally open to examination in the United States for the tax years ended December 31, 2008 through December 31, 2011 and in various individual states for the tax years ended December 31, 2007 through December 31, 2011.

During 2011, CVR recognized a net increase in unrecognized tax benefits of approximately $17.5 million which, if recognized, would not impact the Company's effective tax rate. No amounts for interest or penalties related to uncertain tax positions have been accrued.

A reconciliation of the unrecognized tax benefits for the years ended December 31, 2011, 2010 and 2009 is as follows:

	Year Ended December 31,

	2011		2010		2009
	(in thousands)
Balance beginning of year	$	245	$	—	$	—
Increase based on prior year tax positions		—		245		—
Decrease based on prior year tax positions		—		—		—
Increases and decrease in current year tax positions		17,467		—		—
Settlements		—		—		—
Reductions related to expirations of statute of limitations		—		—		—

Balance end of year	$	17,712	$	245	$	—

- 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, 2011

Long-Term Debt

Long-Term Debt

(13) Long-Term Debt

Long-term debt was as follows:

	December 31,

	2011		2010
	(in thousands)
9.0% Senior Secured Notes, due 2015, net of unamortized premium of $9,003(1) as of December 31, 2011 and unamortized discount of $1,065 as of December 31, 2010	$	456,053	$	246,435
10.875% Senior Secured Notes, due 2017, net of unamortized discount of $2,159 and $2,481 as of December 31, 2011 and December 31, 2010, respectively		220,591		222,519
CRNF credit facility		125,000		—
Capital lease obligations		52,259		—

Long-term debt	$	853,903	$	468,954

(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.

Senior Secured Notes

On April 6, 2010, CRLLC and its wholly-owned subsidiary, Coffeyville Finance Inc. (together the "Issuers"), completed a private offering of $275 million aggregate principal amount of 9.0% First Lien Senior Secured Notes due 2015 (the "First Lien Notes") and $225 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 "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 Notes is amortized to interest expense and other financing costs over the respective term of the Notes. On December 30, 2010, CRLLC made a voluntary unscheduled principal payment of approximately $27.5 million on the First Lien Notes that resulted in a premium payment of 3.0% and a partial write-off of previously deferred financing costs and unamortized original issue discount totaling approximately $1.6 million, which was recognized as a loss on extinguishment of debt in the Consolidated Statements of Operations for the year ended December 31, 2010. On May 16, 2011, CRLLC repurchased $2.7 million of the Notes at a purchase price of 103.0% of the outstanding principal amount, which resulted in a premium payment of 3.0% and a partial write-off of previously deferred financing costs and unamortized issue discount. See Note 8 ("Deferred Financing Costs, Underwriting and Original Issue Discount") for further discussion of the related debt issuance costs. At December 31, 2011, the carrying value of the original First Lien Notes was $246.2 million, net of unamortized discount of approximately $0.8 million. At December 31, 2010, the carrying value of the original First Lien Notes was $246.4 million, net of unamortized discount of $1.1 million.

CRLLC received total net proceeds from the offering of approximately $485.7 million, net of underwriter fees of $10 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. 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. The related original issue discount and debt issuance costs of the Notes are being amortized over the term of the applicable Notes.

On December 15, 2011, the Issuers closed on the issuance of an additional $200.0 million aggregate principal amount of 9% First Lien Senior Secured Notes due 2015 ("New Notes"). The New Notes were sold at an issue price of 105%, plus accrued interest from October 1, 2011 of $3.7 million. The associated original issue premium of the New Notes is amortized to interest expense and other financing costs over the respective term of the New Notes. The New Notes were issued as "Additional Notes" pursuant to an indenture dated April 6, 2010 (the "Indenture") and, together with the existing first lien notes, are treated as a single class for all purposes under the Indenture including, without limitation, waivers, amendments, redemptions and other offers to purchase. Unless otherwise indicated, the New Notes and the existing first lien notes are collectively referred to herein as the "First Lien Notes". The New Notes were offered in connection with CRLLC's acquisition of GWEC. Proceeds of the New 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 New Notes was not closed by the date of closing of the Wynnewood Acquisition. Due to the closing of the issuance of the New Notes, the bridge loan was terminated. At the closing of the issuance of the New 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 New 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. At December 31, 2011, the carrying value of the additional First Lien Notes was $209.9 million, net of unamortized premium of $9.9 million.

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, ABL commitment fee of $2.6 million, New 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 New Notes are being 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 mature on April 1, 2015, unless earlier redeemed or repurchased by the Issuers. The Second Lien Notes mature on April 1, 2017, unless earlier redeemed or repurchased by the Issuers. Interest is payable on the Notes semi-annually on April 1 and October 1 of each year, commencing on October 1, 2010. Included in other current liabilities on the Consolidated Balance Sheet is accrued interest payable totaling approximately $16.1 million and $11.8 million for the years ended December 31, 2011 and 2010, respectively, related to the Notes. Of this amount, $3.7 million represents cash received from the New Notes offering for accrued interest for the period October 1, 2011 through December 15, 2011. At December 31, 2011, the estimated fair value of the First and Second Lien Notes was approximately $473.9 million and $249.5 million, respectively. These estimates of fair value were determined by quotations obtained from a broker-dealer who makes a market in these and similar securities. The Notes are fully and unconditionally guaranteed by each of CRLLC's subsidiaries that also guarantee the first priority credit facility.

Senior Notes Tender Offer

The completion of the initial public offering of the 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 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, as required by the indentures governing the Notes. Holders of the Notes had until May 16, 2011 to properly tender Notes they wished to have repurchased. Approximately $2.7 million of the Notes were repurchased, including approximately $0.5 million of First Lien Notes and $2.2 million of Second Lien Notes.

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 is scheduled to mature in August 2015 and replaced the $150.0 million first priority credit facility which was terminated. The ABL credit facility will be 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 New Notes issuance as discussed above. Terms of the ABL credit facility did not change as a result of the additional availability. As of December 31, 2011, CRLLC had availability under the ABL credit facility of $313.9 million and had letters of credit outstanding of approximately $86.1 million. There were no borrowings outstanding under the ABL credit facility as of December 31, 2011.

Borrowings under the facility bear interest based on a pricing grid determined by the previous quarter's excess availability. The pricing for borrowings under the ABL credit facility can 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 is determined by a borrowing base formula supported primarily by cash and cash equivalents, certain accounts receivable and inventory.

The ABL credit facility contains customary covenants for a financing of this type that limit, subject to certain exceptions, the incurrence of additional indebtedness, creation of liens on assets, the ability to dispose assets, make restricted payments, investments or acquisitions, enter into sales lease back transactions or enter into affiliate transactions. The ABL credit facility also contains a fixed charge coverage ratio financial covenant that is triggered when borrowing base excess availability is less than certain thresholds, as defined under the facility. As of December 31, 2011, CRLLC was in compliance with the covenants of the ABL credit facility.

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 will be 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 will continue to be amortized over the term of the ABL credit facility.

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

Partnership Credit Facility

On April 13, 2011, CRNF, as borrower, and the 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, 2011, with an uncommitted incremental facility of up to $50.0 million. No amounts were outstanding under the revolving credit facility at December 31, 2011. There is no scheduled amortization of the credit facility with it being due and payable in full at its April 2016 maturity. The 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 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 Partnership and all of the capital stock of CRNF and each domestic subsidiary owned by the Partnership or CRNF.

The credit facility requires the 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 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, 2011, CRNF was in compliance with the covenants of the credit facility.

In connection with the credit facility, CRNF has incurred lender and other third party costs of approximately $4.8 million. 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.

Lease Obligations

As a result of the Wynnewood Acquisition, the Company acquired certain lease assets and assumed related capital lease obligations. See Note 3 ("Wynnewood Acquisition") for further discussion. 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 214 months remaining through September 2029. See Note 17 ("Commitments and Contingencies") for further discussion.

The financing agreement relates to the Magellan Pipeline terminals, bulk terminal and loading facility. The lease has 213 months remaining and will expire in September 2029.

Future payments required under capital lease at December 31, 2011 are as follows:

	Capital Lease

	(in thousands)
2012	$	6,239
2013		6,269
2014		6,312
2015		6,355
2016		6,412
2017 and thereafter		83,199

Total future payments		114,786
Less: amount representing interest		61,567

Present value of future minimum payments		53,219
Less: current portion		960

Long-term portion	$	52,259

First Priority Credit Facility

Until April 6, 2010, CRLLC maintained the tranche D term loan totaling approximately $453.3 million. As discussed above, this amount was paid in full with the proceeds of the issuance of the Notes. As of December 31, 2010, the first priority credit facility consisted of a $150.0 million revolving credit facility. As of December 31, 2010, CRLLC had approximately $70.4 million of outstanding letters of credit consisting of approximately $0.2 million in letters of credit in support of certain environmental obligations and approximately $30.6 million in letters of credit to secure transportation services for crude oil and two standby letters of credit totaling approximately $39.7 million issued in support of the purchase of feedstocks. As discussed above the first priority credit facility was terminated on February 22, 2011 and was replaced with an ABL credit facility. As of December 31, 2010, the Company had no borrowings outstanding under the first priority revolving credit facility and had aggregate availability of approximately $79.6 million under the first priority revolving credit facility.

CRLLC's first priority credit facility contained customary restrictive covenants applicable to CRLLC, including, but not limited to, limitations on the level of additional indebtedness, commodity agreements, capital expenditures, payment of dividends, creation of liens, and sale of assets.

Earnings Per Share

12 Months Ended

Dec. 31, 2011

Earnings Per Share

Earnings Per Share

(14) Earnings Per Share

The computations of the basic and diluted earnings per share for the year ended December 31, 2011, 2010 and 2009 are as follows:

	For the Year Ended December 31,

	2011		2010		2009
	(in thousands, except share data)
Net income attributable to CVR Energy stockholders	$	345,776	$	14,290	$	69,354
Weighted-average number of shares of common stock outstanding		86,493,735		86,340,342		86,248,205
Effect of dilutive securities:
Non-vested common stock		1,268,471		448,837		94,228
Stock options		4,367		—		—

Weighted-average number of shares of common stock outstanding assuming dilution		87,766,573		86,789,179		86,342,433

Basic earnings per share	$	4.00	$	0.17	$	0.80
Diluted earnings per share	$	3.94	$	0.16	$	0.80

Outstanding stock options totaling 18,533, 22,900 and 32,350 common shares were excluded from the diluted earnings per share calculation for the years ended December 31, 2011, 2010 and 2009, respectively, as they were antidilutive.

Comprehensive Income (Loss)

12 Months Ended

Dec. 31, 2011

Comprehensive Income (Loss)

Comprehensive Income (Loss)

(15) Comprehensive Income (Loss)

The Company has other comprehensive income (loss) resulting from unrealized gains and losses related to its available-for-sale securities and hedging instruments. The comprehensive income is as follows:

	Year Ended December 31,

	2011			2010		2009
	(in thousands)
Net income	$	378,559		$	14,290	$	69,354
Other comprehensive income (loss):
Net unrealized gain (loss) on available-for-sale securities, net of tax of $(1), $2, $0		(1	)		2		—
Change in fair value of cash flow hedge, net of tax of $(1,235), $0, $0		(1,899	)		—		—
Reclassification adjustment to net income on partial settlement of cash flow hedge		167			—		—

Other comprehensive income (loss)		376,826			14,292		69,354
Less: Other comprehensive income (loss) attributable to noncontrolling interest		32,060			—		—

Comprehensive income attributable to CVR stockholders	$	344,766		$	14,292	$	69,354

- Definition

The entire disclosure for comprehensive income. Includes, but is not limited to, the following: 1) the amount of income tax expense or benefit allocated to each component of other comprehensive income, including reclassification adjustments, 2) the reclassification adjustments for each classification of other comprehensive income and 3) the ending accumulated balances for each component of comprehensive income. Components of comprehensive income include: (1) foreign currency translation adjustments; (2) gains (losses) on foreign currency transactions that are designated as, and are effective as, economic hedges of a net investment in a foreign entity; (3) gains (losses) on intercompany foreign currency transactions that are of a long-term-investment nature, when the entities to the transaction are consolidated, combined, or accounted for by the equity method in the reporting enterprise's financial statements; (4) change in the market value of a futures contract that qualifies as a hedge of an asset reported at fair value; (5) unrealized holding gains (losses) on available-for-sale securities and that resulting from transfers of debt securities from the held-to-maturity category to the available-for-sale category; (6) a net loss recognized as an additional pension liability not yet recognized as net periodic pension cost; and (7) the net gain (loss) and net prior service cost or credit for pension plans and other postretirement benefit plans.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 130
-Paragraph 14-26
-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 220
-SubTopic 10
-Section 45
-Paragraph 11
-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e637-108580

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 14
-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e681-108580

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 13
-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e653-108580

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.3-04)
-URI http://asc.fasb.org/extlink&oid=6959260&loc=d3e187085-122770

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 16
-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e709-108580

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 55
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6920433&loc=d3e998-108581

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 12
-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e640-108580

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Reclassification Adjustments
-URI http://asc.fasb.org/extlink&oid=6522872

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 17
-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e716-108580

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 15
-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e689-108580

+ Details

Benefit Plans

12 Months Ended

Dec. 31, 2011

Benefit Plans

Benefit Plans

(16) Benefit Plans

CVR sponsors 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 75% of the first 6% of the participant's contribution for the nonunion plan, 75% 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 are 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 $2.3 million, $2.2 million and $2.1 million for the years ended December 31, 2011, 2010 and 2009, 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.

Commitments and Contingencies

12 Months Ended

Dec. 31, 2011

Commitments and Contingencies

Commitments and Contingencies

(17) Commitments and Contingencies

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

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

	(in thousands)
2012	$	8,793	$	102,164
2013		8,022		101,164
2014		6,076		101,244
2015		4,566		93,819
2016		3,776		94,155
Thereafter		8,332		411,408

	$	39,565	$	903,954

(1)

This amount includes approximately $500.9 million payable ratably over ten years pursuant to petroleum transportation service agreements between CRRM and TransCanada Keystone Pipeline, LP ("TransCanada"). Under the agreements, CRRM would receive transportation of at least 25,000 barrels per day of crude oil with a delivery point at Cushing, Oklahoma for a term of ten 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, 2011, 2010 and 2009, lease expense totaled approximately $5.1 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. As a result of the amendment, the annual committed contractual payments are estimated to be approximately $1.9 million and the estimated remaining obligation of CRNF totaled approximately $14.9 million through July 1, 2019. These estimates are subject to change based upon the Company's actual usage.

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 transported 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, 2011, 2010 and 2009, totaled approximately $9.8 million, $11.4 million and $11.0 million, respectively.

During 2005, CRRM entered into a Pipeage Contract with Mid-American 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 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 2011, MAPL filed an application with KCC to increase rates, as discussed in further detail below in the Litigation section. Lease expense associated with this contract agreement and included in cost of product sold (exclusive of depreciation and amortization) for the years ended December 31, 2011, 2010 and 2009, totaled approximately $1.3 million, $2.4 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, 2011, 2010 and 2009, totaled approximately $8.4 million, $16.6 million and $9.7 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, 2011, 2010 and 2009, totaled approximately $2.4 million, $2.5 million and $2.6 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 $3.3 million, $3.1 million and $3.5 million for 2011, 2010 and 2009, 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, 2011, 2010 and 2009, totaled approximately $4.2 million, $4.7 million and $4.1 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, 2011, 2010 and 2009, totaled approximately $1.8 million, $1.3 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, 2011, 2010 and 2009, totaled $0.7 million, $0.6 million and $60,000, respectively.

CRNF entered into a sales agreement with Cominco Fertilizer Partnership on November 20, 2007 to purchase equipment and materials which comprise a nitric acid plant. CRNF's obligation related to the execution of the agreement in 2007 for the purchase of the assets was approximately $3.5 million. On May 25, 2009, CRNF and Cominco amended the contract increasing the liability to approximately $4.3 million, of which approximately $2.3 million has been paid. In consideration of the increased liability, the timeline for removal of the equipment and payment schedule was extended. The amendment sets forth payment milestones based upon the timing of removal of identified assets. The balance of the assets purchased is now anticipated to be removed during the first quarter of 2012. Additionally, as of December 31, 2011, approximately $2.9 million was accrued for the dismantling and removal of the unit. As of December 31, 2011, the Partnership had accrued a total of $4.9 million with respect to the nitric acid plant and the related dismantling obligation, which was included in accrued expenses and other current liabilities. The related asset amounts are included in construction-in-progress at December 31, 2011.

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 are estimated to be approximately $4.0 million per year.

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 Sem Group bankruptcy resides. In March 2011, CRRM was dismissed without prejudice from the New Mexico suits. 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. Samson and CRRM have 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. The dismissal does not pertain to the Anstine and Arrow cases.

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 and $11.4 million for the year ended December 31, 2011. CRNF does not agree with the county's classification of its nitrogen fertilizer plant and has been disputing it before the Kansas Court of Tax Appeals ("COTA"). However, CRNF has fully accrued and paid the property taxes the county claims are owed for the years ended December 31, 2010, 2009 and 2008, and has fully accrued such amounts for the year ended December 31, 2011. The first payment in respect of CRNF's 2011 property taxes was paid in December 2011 and the second payment will be made in May 2012. This property tax expense is reflected as a direct operating expense in our financial results. In January 2012 COTA issued a ruling indicating that the assessment in 2008 of CRNF's fertilizer plant as almost entirely real property instead of almost entirely personal property was appropriate. CRNF disagrees with the ruling and filed a petition for reconsideration with COTA (which was denied) and plans to file an appeal to the Kansas Court of Appeals. CRNF is also protesting the valuation of the CRNF fertilizer plant for tax years 2009 through 2011, which cases remain pending before COTA. If CRNF is successful in having the nitrogen fertilizer plant reclassified as personal property, in whole or in part, then a portion of the accrued and paid expenses would be refunded to CRNF, which could have a material positive effect on CRNF's and the Company's results of operations. If CRNF is not successful in having the nitrogen fertilizer plant reclassified as personal property, in whole or in part, then CRNF expects that it will continue to pay property taxes at elevated rates.

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 currently ships refined fuels on the Outbound Line pursuant to transportation rates established by a pipeline capacity lease with MAPL which expired September 30, 2011 and CRRM currently ships natural gas liquids on the Inbound Line pursuant to a pipeage contract which also expired September 30, 2011. Although CRRM intends to vigorously contest the New Rates at the KCC, if MAPL is successful in obtaining the entirety of its proposed rate increase, under CRRM's historic pipeline usage patterns, the New Rates would result in a total annual increase of approximately $14.75 million for CRRM's use of the Inbound and the Outbound Lines. On September 30, 2011, the KCC issued an order continuing, on an interim basis, the existing rates for the Inbound Line and the Outbound Line from October 1, 2011 until the KCC issues its final rate order in the second quarter of 2012. The interim rates are subject to a true-up based upon the difference, if any, between the interim rates and the final rates approved by the KCC. In addition, on September 21, 2011, MAPL filed an application with the U.S. Federal Energy Regulatory Commission ("FERC") for a rate increase on the Outbound Line with respect to shipments with an interstate destination. On October 28, 2011 FERC issued an order allowing MAPL to place its increased rate into effect October 1, 2011 with respect to interstate shipments, subject to refund based on the final outcome of the FERC proceedings. Historically, the majority of CRRM's shipments on the Outbound Line are to Kansas intrastate destinations and therefore, are subject to KCC and not FERC rate regulation.

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 ("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 (i) recovery from CRRM of EPA's oversight costs, (ii) a civil penalty under the Clean Water Act (as amended by the OPA) and (iii) recovery from CRRM related to alleged non-compliance with the Clean Air Act's Risk Management Program ("RMP"). (See "Environmental, Health and Safety ("EHS") Matters" below.)

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 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.

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 CVR, 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.

CRRM and CRT have agreed to perform corrective actions at the Coffeyville, Kansas refinery and the Phillipsburg, Kansas terminal facility, pursuant to Administrative Orders on Consent issued under the Resource Conservation and Recovery Act ("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, 2011 and 2010, environmental accruals of approximately $1.9 million and $4.1 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 $0.5 million and $1.5 million, respectively, are included in other current liabilities. The Company's accruals were determined based on an estimate of payment costs through 2031, for which the scope of remediation was arranged with the EPA, and were discounted at the appropriate risk free rates at December 31, 2011 and 2010, respectively. The accruals include estimated closure and post-closure costs of approximately $0.9 million and $0.9 million for two landfills at December 31, 2011 and 2010, respectively. The estimated future payments for these required obligations are as follows:

Year Ending December 31,	Amount

	(in thousands)
2012	$	493
2013		166
2014		166
2015		166
2016		109
Thereafter		1,077

Undiscounted total		2,177
Less amounts representing interest at 1.69%		225

Accrued environmental liabilities at December 31, 2011	$	1,952

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.

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. Capital expenditures to comply with the rule are expected to be approximately $10.0 million.

CRRM's refinery 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 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. Thus, in 2011, about 8% of all fuel used will be "renewable fuel." In 2012, the EPA has proposed to raise the renewable fuel percentage standards to about 9%. 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. In addition, CRRM may be impacted by increased capital expenses and production costs to accommodate mandated renewable fuel volumes to the extent that these increased costs cannot be passed on to the consumers. CRRM's small refiner status under the original RFS expired on December 31, 2010. Beginning on January 1, 2011, CRRM was required to blend renewable fuels into its gasoline and diesel fuel or purchase renewable energy credits, known as Renewable Identification Numbers (RINs) in lieu of blending. For the year ended December 31, 2011, CRRM incurred approximately $19.0 million of expense associated with the purchasing RINs which was included in cost of product sold in the Consolidated Statements of Operations. To achieve compliance with the renewable fuel standard for the remainder of 2011, CRRM is able to blend a small amount of ethanol into gasoline sold at its refinery loading rack, but otherwise will have to purchase RINs to comply with the rule. CRRM has requested "hardship relief" from EPA based on the disproportionate economic impact of the rule on CRRM, but the EPA denied CRRM's request on February 17, 2012. CRRM may appeal the denial of its hardship petition.

WRC's refinery is a small refinery under the RFS and has received a two year extension of time to comply. Therefore, WRC will have to begin complying with the RFS in 2013 unless a further extension is requested and granted.

In March 2004, CRRM and CRT entered into a Consent Decree (the "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 ("Farmland") prior ownership and operation of the Coffeyville crude oil refinery and the now-closed Phillipsburg terminal facilities. Under the 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 Consent Decree, CRRM and CRT assumed cleanup obligations at the Coffeyville refinery and the now-closed Phillipsburg terminal facilities. The remaining costs of complying with the Consent Decree are expected to be approximately $49 million, of which approximately $47 million is expected to be capital expenditures which does not include the cleanup obligations for historic contamination at the site that are being addressed pursuant to administrative orders issued under RCRA. To date, CRRM and CRT have materially complied with the Consent Decree. On June 30, 2009, CRRM submitted a force majeure notice to the EPA and KDHE in which CRRM indicated that it may be unable to meet the Consent Decree's January 1, 2011 deadline related to the installation of controls on the FCCU to reduce emissions of sulfur dioxide and nitrogen oxides because of delays caused by the June/July 2007 flood. In February 2010, CRRM and the EPA agreed to a fifteen month extension of the January 1, 2011, deadline for the installation of controls which was approved by the Court as a material modification to the existing Consent Decree. Pursuant to this agreement, CRRM agreed to offset any incremental emissions resulting from the delay by providing additional controls to existing emission sources over a set timeframe.

In the meantime, CRRM has been negotiating with the EPA and KDHE to replace the current Consent Decree, including the fifteen month extension, with a global settlement under the National Petroleum Refining Initiative. Over the course of the last decade, the EPA has embarked on a national Petroleum Refining Initiative alleging industry-wide noncompliance 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 entering into consent decrees imposing civil penalties and requiring the installation of expenditures for pollution control equipment and enhanced operating procedures. The EPA has indicated that it will seek to have all refiners enter into "global settlements" pertaining to all "marquee" issues. The Consent Decree covers some, but not all, of the "marquee" issues. The Company has been negotiating with the EPA to expand the 2004 Consent Decree obligations to include all of the "marquee" issues under the Petroleum Refining Initiative, and have reached an agreement which includes an agreement to further extend the deadline for the installation of controls on the FCCU. Under the global settlement, the Company will be required to pay a civil penalty, but the incremental capital expenditures would not be material and would be limited primarily to the retrofit and replacement of heaters and boilers over a five to seven year timeframe. The new Consent Decree is awaiting EPA final approval after which it will be lodged with the court and then submitted for public notice and comment before it becomes final.

On February 24, 2010, the Company received a letter from the DOJ on behalf of the EPA seeking an approximately $0.9 million civil penalty related to alleged late and incomplete reporting of air releases in violation of the Comprehensive Environmental Response, Compensation, and Liability Act ("CERCLA") and the Emergency Planning and Community Right-to-Know Act ("EPCRA"). The Company has reached an agreement with EPA to resolve these claims. The resolution will be included in the Consent Decree under the National Petroleum Refining Initiative described in the previous paragraph.

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.

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.

Environmental expenditures are capitalized when such expenditures are expected to result in future economic benefits. For the years ended December 31, 2011, 2010 and 2009, capital expenditures were approximately $7.6 million, $13.7 million and $24.4 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.

- 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
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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
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Reference 3: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.25)
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Reference 4: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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-Section 50
-Paragraph 4
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Reference 5: http://www.xbrl.org/2003/role/presentationRef
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-SubTopic 20
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-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6449706&loc=d3e16207-108621

+ Details

Fair Value Measurements

12 Months Ended

Dec. 31, 2011

Fair Value Measurements

Fair Value Measurements

(18) Fair Value Measurements

In September 2006, the FASB issued ASC Topic 820 — Fair Value Measurements and Disclosures ("ASC 820"). 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 that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants.

ASC 820 discusses valuation techniques, such as the market approach (prices and other relevant information generated by market conditions involving identical or comparable assets or liabilities), the income approach (techniques to convert future amounts to single present amounts based on market expectations including present value techniques and option-pricing), and the cost approach (amount that would be required to replace the service capacity of an asset which is often referred to as 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 market 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, 2011 and 2010:

	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	)

	December 31, 2010

	Level 1		Level 2			Level 3		Total
	(in thousands)
Location and Description
Cash equivalents	$	70,052	$	—		$	—	$	70,052
Other current assets (marketable securities)		26		—			—		26

Total Assets	$	70,078	$	—		$	—	$	70,078

Other current liabilities (Other derivative agreements)		—		(4,043	)		—		(4,043	)

Total Liabilities	$	—	$	(4,043	)	$	—	$	(4,043	)

As of December 31, 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 Notes is disclosed in Note 13 ("Long-Term Debt"). The Company's commodity derivative contracts giving rise to an asset under Level 2 are valued using broker quoted market prices of similar commodity contracts. The 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 had no transfers of assets or liabilities between any of the above levels during the year ended December 31, 2011.

- 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
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Reference 6: http://www.xbrl.org/2003/role/presentationRef
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Reference 7: http://www.xbrl.org/2003/role/presentationRef
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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, 2011

Derivative Financial Instruments

Derivative Financial Instruments

(19) Derivative Financial Instruments

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

	Year Ended December 31,

	2011			2010			2009
	(in thousands)
Realized gain (loss) on swap agreements	$	—		$	—		$	(14,331	)
Unrealized gain (loss) on swap agreements		—			—			(40,903	)
Realized gain (loss) on other derivative agreements		(7,182	)		721			(6,646	)
Unrealized gain (loss) on other derivative agreements		85,262			(2,196	)		(1,847	)
Realized gain (loss) on interest rate swap agreements		—			(2,860	)		(6,518	)
Unrealized gain (loss) on interest rate swap agreements		—			2,830			4,959

Total gain (loss) on derivatives, net	$	78,080		$	(1,505	)	$	(65,286	)

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. Dependant 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.

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, 2011, the Company had open commodity hedging instruments consisting of 13 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, 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. 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 designed as a hedge by either company.

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 its $125 million floating rate term debt which matures in April 2016. The aggregate notional amount covered under these agreements totals $62.5 million (split evenly between the two agreement dates) and commences on August 12, 2011 and expires on February 12, 2016. 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, 2011, the effective rate was approximately 4.69%. 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 interest expense was $0.4 million for the year ended December 31, 2011.

Cash Flow Swap

Until October 8, 2009, CRLLC had been a party to commodity derivative contracts (referred to as the "Cash Flow Swap") that were originally executed on June 16, 2005. The swap agreements were executed at the prevailing market rate at the time of execution and were to provide an economic hedge on future transactions. The Cash Flow Swap resulted in unrealized gains (losses), using a valuation method that utilized quoted market prices. All of the activity related to the Cash Flow Swap is reported in the Petroleum Segment. On October 8, 2009, CRLLC and J. Aron, the swap counterparty and a related party, mutually agreed to terminate the Cash Flow Swap. The Cash Flow Swap was originally expected to terminate in 2010; however, an amendment to the Company's credit facility completed on October 2, 2009, permitted early termination. As a result of the early termination, a settlement totaling approximately $3.9 million was paid to CRLLC by J. Aron. See Note 20 ("Related Party Transactions") for further discussion of the Cash Flow Swap.

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 19, "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 in income. 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

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+ Details

Related Party Transactions

12 Months Ended

Dec. 31, 2011

Related Party Transactions

Related Party Transactions

(20) Related Party Transactions

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.

Cash Flow Swap

CRLLC entered into the Cash Flow Swap with J. Aron, a subsidiary of GS. These agreements were entered into on June 16, 2005, with an expiration date of June 30, 2010. As described in Note 19 ("Derivative Financial Instruments"), the Cash Flow Swap was terminated by the parties effective October 8, 2009. The termination resulted in a settlement payment received by CRLLC from J. Aron totaling approximately $3.9 million. Amounts totaling approximately $0.0, $0.0 and $(55.3) million were reflected in gain (loss) on derivatives, net, related to these swap agreements for the years ended December 31, 2011, 2010 and 2009, respectively.

J. Aron Deferrals

As a result of the June/July 2007 flood and the related temporary cessation of business operations, the Company entered into deferral agreements for amounts owed to J. Aron under the Cash Flow Swap discussed above. The amount deferred, excluding accrued interest, totaled approximately $123.7 million. Of the deferred balances, approximately $61.3 million had been repaid as of December 31, 2008 and the remaining deferral obligation of approximately $62.4 million, including accrued interest of approximately $0.5 million, was paid in the first quarter of 2009, resulting in the Company being unconditionally and irrevocably released from any and all of its obligations under the deferred agreements. In addition, J. Aron released the Goldman Sachs Funds and the Kelso Funds from any and all of their obligations to guarantee the deferred payment obligations. Interest relating to the deferred payment agreements is reflected in interest expense and other financing costs. As the obligation was settled in 2009, there was no financial statement impact for the years ended December 31, 2010 and 2011. For the year ended December 31, 2009, interest expense associated with the deferral agreement totaled approximately $0.3 million.

Interest Rate Swap

On June 30, 2005, the Company entered into three Interest Rate Swap agreements with J. Aron. Amounts totaling $0.0, $(16,000) and approximately $(0.8) million are recognized in gain (loss) on derivatives, net, related to these swap agreements for the years ended December 31, 2011, 2010 and 2009, respectively. The Interest Rate Swap expired June 30, 2010.

Cash and Cash Equivalents

The Company holds a portion of its cash balance in a highly liquid money market account with average maturities of less than 90 days with the Goldman Sachs Fund family. As of December 31, 2011 and 2010, the balance in the account was approximately $0 and $70.1 million, respectively. For the years ended December 31, 2011, 2010 and 2009, this account earned interest income of approximately $26,000, $29,000 and $74,000, respectively.

Financing and Other

In connection with the 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 13 ("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. See Note 13 ("Long-Term Debt") for further discussion. 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 Notes (as described in Note 13 "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.

The Company recognized approximately $0.5 million for the year ended December 31, 2009 in registration expenses relating to the secondary offering that occurred in 2009 for the benefit of GS in connection with CVR's Registration Rights Agreement. These amounts included registration and filing fees, printing fees, external accounting fees, and external legal fees.

In October 2009, CRLLC amended its outstanding first priority credit facility. See Note 13 ("Long-Term Debt") for further discussion. In connection with the amendment, CRLLC paid a subsidiary of GS a fee of $0.9 million for their services as lead bookrunner. Additionally, CRLLC paid a lender fee of approximately $7,000 in conjunction with this amendment to a different subsidiary of GS. The affiliate was one of the many lenders under the first priority credit facility.

- 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
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Reference 2: http://www.xbrl.org/2003/role/presentationRef
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+ Details

Business Segments

12 Months Ended

Dec. 31, 2011

Business Segments

Business Segments

(21) 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 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 $11.4 million, $4.3 million and $6.1 million for the years ended December 31, 2011, 2010 and 2009, respectively.

The Petroleum Segment recorded intercompany cost of product sold (exclusive of depreciation and amortization) for the hydrogen sales described below under "Nitrogen Fertilizer" of approximately $13.2 million, $(1.6) million and $(0.8) million for the years ended December 31, 2011, 2010 and 2009, 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 $10.7 million, $4.0 million and $7.9 million for the years ended December 31, 2011, 2010 and 2009, respectively.

Pursuant to the feedstock agreement, the Company's segments have the right to transfer excess hydrogen to one another 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, 2011, 2010 and 2009, the net sales generated from intercompany hydrogen sales were $14.2 million, $0.1 million and $0.8 million, respectively. For the year ended December 31, 2011, 2010 and 2009, the nitrogen fertilizer segment also recognized approximately $1.0 million, $1.8 million and $1.6 million, respectively, of cost of product sold related to the transfer of excess hydrogen. As these intercompany sales and cost of product sold are eliminated, there is no financial statement impact on the consolidated financial statements.

Other Segment

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

	Year Ended December 31,

	2011			2010			2009
	(in thousands)
Net sales
Petroleum	$	4,751,826		$	3,903,826		$	2,934,904
Nitrogen Fertilizer		302,867			180,468			208,371
Other		—			—			—
Intersegment elimination		(25,580	)		(4,526	)		(6,946	)

Total	$	5,029,113		$	4,079,768		$	3,136,329

Cost of product sold (exclusive of depreciation and amortization)
Petroleum	$	3,926,632		$	3,538,017		$	2,514,293
Nitrogen Fertilizer		42,511			34,328			42,158
Other		—			—			—
Intersegment elimination		(25,629	)		(4,227	)		(8,756	)

Total	$	3,943,514		$	3,568,118		$	2,547,695

Direct operating expenses (exclusive of depreciation and amortization)
Petroleum	$	247,665		$	153,112		$	142,204
Nitrogen Fertilizer		86,491			86,679			84,453
Other		(104	)		—			—

Total	$	334,052		$	239,791		$	226,657

Depreciation and amortization
Petroleum	$	69,852		$	66,391		$	64,424
Nitrogen Fertilizer		18,869			18,463			18,685
Other		1,600			1,907			1,764

Total	$	90,321		$	86,761		$	84,873

Operating income
Petroleum		465,710			104,564			170,184
Nitrogen Fertilizer		136,198			20,356			48,863
Other		(35,312	)		(31,856	)		(10,861	)

Total	$	566,596		$	93,064		$	208,186

Capital expenditures
Petroleum	$	68,612		$	19,761		$	34,018
Nitrogen fertilizer		19,144			10,117			13,389
Other		3,468			2,531			1,366

Total	$	91,224		$	32,409		$	48,773

Total assets
Petroleum	$	2,322,148		$	1,049,361		$	1,082,707
Nitrogen Fertilizer		659,309			452,165			702,929
Other		137,834			238,658			(171,142	)

Total	$	3,119,291		$	1,740,184		$	1,614,494

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

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-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 33
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Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
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-Paragraph 26
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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
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-Paragraph 32
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8933-108599

+ Details

Major Customers and Suppliers

12 Months Ended

Dec. 31, 2011

Major Customers and Suppliers

Major Customers and Suppliers

(22) Major Customers and Suppliers

Sales to major customers were as follows:

	Year Ended December 31,

	2011			2010			2009
Petroleum
Customer A		15	%		14	%		14	%
Customer B		12	%		11	%		10	%
Customer C		9	%		10	%		11	%

		36	%		35	%		35	%

Nitrogen Fertilizer
Customer D		17	%		12	%		15	%
Customer E		12	%		10	%		9	%

		29	%		22	%		24	%

In connection with an agreement entered into on December 31, 2008, the Petroleum Segment obtained crude oil from one supplier for 2009, 2010 and 2011. 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,

	2011			2010			2009
Petroleum
Supplier A		65	%		64	%		69	%

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,

	2011			2010			2009
Nitrogen Fertilizer
Supplier B		5	%		5	%		5	%

Selected Quarterly Financial Information (unaudited)

12 Months Ended

Dec. 31, 2011

Selected Quarterly Financial Information (unaudited)

Selected Quarterly Financial Information (unaudited)

(23) Selected Quarterly Financial Information (unaudited)

Summarized quarterly financial data for December 31, 2011 and 2010.

	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		274			211			93			(89	)
Gain (loss) on derivatives, net		(22,106	)		6,932			(9,925	)		103,179
Loss on extinguishment of debt		(1,908	)		(170	)		—			—
Other income, net		231			246			243			124

Total other income		(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

	Year Ended December 31, 2010

	Quarter
	First			Second			Third			Fourth
	(in thousands, except share data)
Net sales	$	894,512		$	1,005,898		$	1,031,174		$	1,148,184
Operating costs and expenses:
Cost of product sold (exclusive of depreciation and amortization)		802,890			891,652			889,850			983,726
Direct operating expenses (exclusive of depreciation and amortization)		60,562			62,479			52,534			64,216
Selling, general and administrative (exclusive of depreciation and amortization)		21,394			10,793			16,397			43,450
Depreciation and amortization		21,260			21,553			21,943			22,005

Total operating costs and expenses		906,106			986,477			980,724			1,113,397

Operating income (loss)		(11,594	)		19,421			50,450			34,787
Other income (expense):
Interest expense and other financing costs		(9,922	)		(12,766	)		(13,863	)		(13,717	)
Interest income		416			643			549			603
Gain (loss) on derivatives, net		1,490			7,339			(1,014	)		(9,320	)
Loss on extinguishment of debt		(500	)		(14,552	)		—			(1,595	)
Other income, net		42			642			17			517

Total other income (expense)		(8,474	)		(18,694	)		(14,311	)		(23,512	)

Income (loss) before income tax (benefit)		(20,068	)		727			36,139			11,275
Income tax expense (benefit)		(7,705	)		(425	)		12,932			8,981

Net income (loss)	$	(12,363	)	$	1,152		$	23,207		$	2,294

Net earnings (loss) per share
Basic	$	(0.14	)	$	0.01		$	0.27		$	0.03
Diluted	$	(0.14	)	$	0.01		$	0.27		$	0.03
Weighted-average common shares outstanding
Basic		86,329,237			86,336,125			86,343,102			86,352,627
Diluted		86,329,237			86,506,590			87,013,575			87,121,094

- 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

Dec. 31, 2011

Subsequent Events

Subsequent Events

(24) Subsequent Events

Distribution

On January 26, 2012, the Board of Directors of the Partnership's general partner declared a cash distribution for the fourth quarter of 2011 to the Partnership's unitholders of $0.588 per unit, or $42.9 million in aggregate. The cash distribution was paid on February 14, 2012, to unitholders of record at the close of business on February 7, 2012.

Turnaround

The Coffeyville refinery commenced the actual maintenance work of the second phase of a planned turnaround during the third week of February 2012. The refinery expects to begin the start up of units mid March 2012 and anticipates that all units will be in full operation by the end of March.

Sale of Partnership Interests

On February 13, 2012, CVR announced its intention to sell a portion of its investment in the Partnership and use the proceeds to pay a special dividend to holders of its common stock and to strengthen CVR's balance sheet. There can be no assurance as to the terms, conditions, amount or timing of such sale or dividend, or whether such sale or dividend will take place at all. This announcement does not constitute an offer of any securities for sale and is being made in accordance with Rule 135 under the Securities Act.

Dividend

The Board of Directors of the Company has approved a regular quarterly cash dividend of $0.08 per common share, the first of which will be paid following the end of the Company's first quarter in 2012 on a date to be set by the Board of Directors.

Shareholder Proposal and Tender Offer

CVR recently received a notice from certain funds affiliated with Carl Icahn disclosing their intent to nominate nine individuals for election to CVR's board of directors. In addition, on February 23, 2012, certain funds affiliated with Carl Icahn commenced a tender offer for control of the Company with the intention, following completion of such tender offer, to seek to sell CVR to a strategic acquirer.

Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2011

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

Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2011

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, 2011

Wynnewood Acquisition

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

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


Cash and cash equivalents	$	6.3
Accounts receivable		158.5
Inventories		213.5
Prepaid expenses and other current assets		6.0
Property, plant and equipment		574.5
Accounts payable and accrued liabilities		(314.2	)
Long-term debt		(52.3	)

Total fair values of net assets acquired		592.3

Less: cash acquired		6.3

Total consideration transferred, net of cash acquired	$	586.0

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		473.8		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, 2011

Share-based Compensation

Schedule of service phantom interest and performance phantom interest values

	December 31,

	2010		2009
Service Phantom interest (per point)	$	14.64	$	11.37
Performance Phantom interest (per point)	$	21.25	$	5.48

Summary of the status of non-vested shares

			Weighted- Average Grant-Date Fair Value		Aggregate Intrinsic Value (in thousands)

Non-vested at December 31, 2008	78,666		$	6.62	$	315

Granted	202,257			6.68
Vested	(100,763	)		6.86
Forfeited	(3,100	)		4.14

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		$	14.62	$	23,887

Summary of activity and price information regarding stock options granted

			Weighted- Average Exercise Price

Outstanding, December 31, 2008	32,350		$	19.08	9.21

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

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

Exercisable at December 31, 2011	22,900		$	18.03	7.35

CALLC, CALLC II and CALLC III

Share-based Compensation

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

						Compensation Expense Increase (Decrease) for the Year Ended December 31,

	Benchmark Value (per Unit)		Original Awards Issued
Award Type	Benchmark Value (per Unit)		Original Awards Issued		Grant Date	2011		2010		2009
						(in thousands)
Override Operating Units(a)	$	11.31		919,630	June 2005	$	—	$	338	$	1,369
Override Operating Units(b)	$	34.72		72,492	December 2006		—		13		36
Override Value Units(c)	$	11.31		1,839,265	June 2005		4,960		17,586		2,690
Override Value Units(d)	$	34.72		144,966	December 2006		451		581		37
Override Units(e)	$	10.00		642,219	February 2008		184		772		26

					Total	$	5,595	$	19,290	$	4,158

Schedule of significant assumption used in the valuation of the Units

	December 31,

	2010	2009
Estimated forfeiture rate	None	None
Derived Service Period	Based on forfeiture schedule	Based on forfeiture schedule
Estimated fair value (per unit)	$2.60	$0.08
Marketability and minority interest discount	10.0%	20.0%
Volatility	47.6%	59.7%

Override Operating Units | CALLC and CALLC II

Share-based Compensation

Schedule of significant assumption used in the valuation of the Units

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

	2009			2009
Estimated forfeiture rate		None			None
CVR closing stock price	$	6.86		$	6.86
Estimated weighted-average fair value (per unit)	$	11.95		$	1.40
Marketability and minority interest discounts		20.0	%		20.0	%
Volatility		50.7	%		50.7	%

Override Value Units | CALLC and CALLC II

Share-based Compensation

Schedule of significant assumption used in the valuation of the Units

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

	2009			2009
Estimated forfeiture rate		None			None
CVR closing stock price	$	6.86		$	6.86
Estimated weighted-average fair value (per unit)	$	11.95		$	1.40
Marketability and minority interest discounts		20.0	%		20.0	%
Volatility		50.7	%		50.7	%

Inventories (Tables)

12 Months Ended

Dec. 31, 2011

Inventories

Schedule of inventories

	December 31,

	2011		2010
	(in thousands)
Finished goods	$	323,315	$	110,788
Raw materials and precious metals		157,931		89,333
In-process inventories		115,372		22,931
Parts and supplies		39,603		24,120

	$	636,221	$	247,172

Property, Plant, and Equipment (Tables)

12 Months Ended

Dec. 31, 2011

Property, Plant, and Equipment

Summary of costs for property, plant, and equipment

	December 31,

	2011		2010
	(in thousands)
Land and improvements	$	26,136	$	19,228
Buildings		37,289		25,663
Machinery and equipment		1,967,269		1,363,877
Automotive equipment		10,217		8,747
Furniture and fixtures		12,349		9,279
Leasehold improvements		1,445		1,253
Railcars		2,496		—
Construction in progress		94,085		42,674

		2,151,286		1,470,721
Accumulated depreciation		478,325		389,409

	$	1,672,961	$	1,081,312

Deferred Financing Costs and Original Issue Discount (Tables)

12 Months Ended

Dec. 31, 2011

Deferred Financing Costs and Original Issue Discount

Schedule of estimated amortization of deferred financing costs

Year Ending December 31,	Deferred Financing

	(in thousands)
2012		7,382
2013		7,373
2014		7,373
2015		4,189
2016		1,151
Thereafter		233

	$	27,701

Income Taxes (Tables)

12 Months Ended

Dec. 31, 2011

Income Taxes

Schedule of income tax expense (benefit)

	Year Ended December 31,

	2011		2010			2009
	(in thousands)
Current
Federal	$	141,305	$	13,434		$	33,651
State		7,972		1,262			2,866

Total current		149,277		14,696			36,517

Deferred
Federal		40,350		808			(6,613	)
State		19,936		(1,721	)		(669	)

Total deferred		60,286		(913	)		(7,282	)

Total income tax expense	$	209,563	$	13,783		$	29,235

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,

	2011			2010			2009
	(in thousands)
Tax computed at federal statutory rate	$	205,843		$	9,826		$	34,506
State income taxes, net of federal tax benefit		20,600			1,923			5,402
State tax incentives, net of federal tax expense		(3,174	)		(2,382	)		(3,205	)
Domestic production activities deduction		(10,562	)		(2,025	)		(3,798	)
Federal tax credit for production of ultra-low sulfur diesel fuel		—			—			(4,783	)
Non-deductible share-based compensation		2,000			6,747			1,457
IRS interest (income)/expense, net		34			(814	)		—
Noncontrolling interest		(11,474	)		—			—
Partnership basis adjustment		4,174			—			—
Other, net		2,122			508			(344	)

Total income tax expense	$	209,563		$	13,783		$	29,235

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,

	2011			2010
	(in thousands)
Deferred income tax assets:
Allowance for doubtful accounts	$	475		$	286
Personnel accruals		6,437			10,389
Inventories		2,097			469
Unrealized derivative losses, net		—			1,604
Low sulfur diesel fuel credit carry forward and other general business credit carryforward		—			23,653
Accrued expenses		101			199
State tax credit carryforward, net of federal expense		17,682			29,955
Deferred financing		76			101
Other		2,695			3,018

Total gross deferred income tax assets		29,563			69,674

Deferred income tax liabilities:
Unrealized derivative gains, net		(31,990	)		—
Property, plant, and equipment		(224,452	)		(323,839	)
Investment in CVR Partners		(134,920	)		—
Prepaid expenses		(4,945	)		(1,427	)

Total gross deferred income tax liabilities		(396,307	)		(325,266	)

Net deferred income tax liabilities	$	(366,744	)	$	(255,592	)

Schedule of reconciliation of the unrecognized tax benefits

	Year Ended December 31,

	2011		2010		2009
	(in thousands)
Balance beginning of year	$	245	$	—	$	—
Increase based on prior year tax positions		—		245		—
Decrease based on prior year tax positions		—		—		—
Increases and decrease in current year tax positions		17,467		—		—
Settlements		—		—		—
Reductions related to expirations of statute of limitations		—		—		—

Balance end of year	$	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, 2011

Long-Term Debt

Schedule of long-term debt

	December 31,

	2011		2010
	(in thousands)
9.0% Senior Secured Notes, due 2015, net of unamortized premium of $9,003(1) as of December 31, 2011 and unamortized discount of $1,065 as of December 31, 2010	$	456,053	$	246,435
10.875% Senior Secured Notes, due 2017, net of unamortized discount of $2,159 and $2,481 as of December 31, 2011 and December 31, 2010, respectively		220,591		222,519
CRNF credit facility		125,000		—
Capital lease obligations		52,259		—

Long-term debt	$	853,903	$	468,954

(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.

Schedule of future payments required under capital lease

	Capital Lease

	(in thousands)
2012	$	6,239
2013		6,269
2014		6,312
2015		6,355
2016		6,412
2017 and thereafter		83,199

Total future payments		114,786
Less: amount representing interest		61,567

Present value of future minimum payments		53,219
Less: current portion		960

Long-term portion	$	52,259

- 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, 2011

Earnings Per Share

Schedule of computations of the basic and diluted earnings per share

	For the Year Ended December 31,

	2011		2010		2009
	(in thousands, except share data)
Net income attributable to CVR Energy stockholders	$	345,776	$	14,290	$	69,354
Weighted-average number of shares of common stock outstanding		86,493,735		86,340,342		86,248,205
Effect of dilutive securities:
Non-vested common stock		1,268,471		448,837		94,228
Stock options		4,367		—		—

Weighted-average number of shares of common stock outstanding assuming dilution		87,766,573		86,789,179		86,342,433

Basic earnings per share	$	4.00	$	0.17	$	0.80
Diluted earnings per share	$	3.94	$	0.16	$	0.80

Comprehensive Income (Loss) (Tables)

12 Months Ended

Dec. 31, 2011

Comprehensive Income (Loss)

Schedule of other comprehensive income (loss) resulting from unrealized gains and losses related to available-for-sale securities and hedging instruments

	Year Ended December 31,

	2011			2010		2009
	(in thousands)
Net income	$	378,559		$	14,290	$	69,354
Other comprehensive income (loss):
Net unrealized gain (loss) on available-for-sale securities, net of tax of $(1), $2, $0		(1	)		2		—
Change in fair value of cash flow hedge, net of tax of $(1,235), $0, $0		(1,899	)		—		—
Reclassification adjustment to net income on partial settlement of cash flow hedge		167			—		—

Other comprehensive income (loss)		376,826			14,292		69,354
Less: Other comprehensive income (loss) attributable to noncontrolling interest		32,060			—		—

Comprehensive income attributable to CVR stockholders	$	344,766		$	14,292	$	69,354

Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2011

Commitments and Contingencies

Schedule of minimum required payments for lease agreements and unconditional purchase obligations

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

	(in thousands)
2012	$	8,793	$	102,164
2013		8,022		101,164
2014		6,076		101,244
2015		4,566		93,819
2016		3,776		94,155
Thereafter		8,332		411,408

	$	39,565	$	903,954

(1)

This amount includes approximately $500.9 million payable ratably over ten years pursuant to petroleum transportation service agreements between CRRM and TransCanada Keystone Pipeline, LP ("TransCanada"). Under the agreements, CRRM would receive transportation of at least 25,000 barrels per day of crude oil with a delivery point at Cushing, Oklahoma for a term of ten 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)
2012	$	493
2013		166
2014		166
2015		166
2016		109
Thereafter		1,077

Undiscounted total		2,177
Less amounts representing interest at 1.69%		225

Accrued environmental liabilities at December 31, 2011	$	1,952

Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2011

Fair Value Measurements

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

	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	)

	December 31, 2010

	Level 1		Level 2			Level 3		Total
	(in thousands)
Location and Description
Cash equivalents	$	70,052	$	—		$	—	$	70,052
Other current assets (marketable securities)		26		—			—		26

Total Assets	$	70,078	$	—		$	—	$	70,078

Other current liabilities (Other derivative agreements)		—		(4,043	)		—		(4,043	)

Total Liabilities	$	—	$	(4,043	)	$	—	$	(4,043	)

Derivative Financial Instruments (Tables)

12 Months Ended

Dec. 31, 2011

Derivative Financial Instruments

Components of gain (loss) on derivatives, net

	Year Ended December 31,

	2011			2010			2009
	(in thousands)
Realized gain (loss) on swap agreements	$	—		$	—		$	(14,331	)
Unrealized gain (loss) on swap agreements		—			—			(40,903	)
Realized gain (loss) on other derivative agreements		(7,182	)		721			(6,646	)
Unrealized gain (loss) on other derivative agreements		85,262			(2,196	)		(1,847	)
Realized gain (loss) on interest rate swap agreements		—			(2,860	)		(6,518	)
Unrealized gain (loss) on interest rate swap agreements		—			2,830			4,959

Total gain (loss) on derivatives, net	$	78,080		$	(1,505	)	$	(65,286	)

- 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, 2011

Business Segments

Schedule of segment information

	Year Ended December 31,

	2011			2010			2009
	(in thousands)
Net sales
Petroleum	$	4,751,826		$	3,903,826		$	2,934,904
Nitrogen Fertilizer		302,867			180,468			208,371
Other		—			—			—
Intersegment elimination		(25,580	)		(4,526	)		(6,946	)

Total	$	5,029,113		$	4,079,768		$	3,136,329

Cost of product sold (exclusive of depreciation and amortization)
Petroleum	$	3,926,632		$	3,538,017		$	2,514,293
Nitrogen Fertilizer		42,511			34,328			42,158
Other		—			—			—
Intersegment elimination		(25,629	)		(4,227	)		(8,756	)

Total	$	3,943,514		$	3,568,118		$	2,547,695

Direct operating expenses (exclusive of depreciation and amortization)
Petroleum	$	247,665		$	153,112		$	142,204
Nitrogen Fertilizer		86,491			86,679			84,453
Other		(104	)		—			—

Total	$	334,052		$	239,791		$	226,657

Depreciation and amortization
Petroleum	$	69,852		$	66,391		$	64,424
Nitrogen Fertilizer		18,869			18,463			18,685
Other		1,600			1,907			1,764

Total	$	90,321		$	86,761		$	84,873

Operating income
Petroleum		465,710			104,564			170,184
Nitrogen Fertilizer		136,198			20,356			48,863
Other		(35,312	)		(31,856	)		(10,861	)

Total	$	566,596		$	93,064		$	208,186

Capital expenditures
Petroleum	$	68,612		$	19,761		$	34,018
Nitrogen fertilizer		19,144			10,117			13,389
Other		3,468			2,531			1,366

Total	$	91,224		$	32,409		$	48,773

Total assets
Petroleum	$	2,322,148		$	1,049,361		$	1,082,707
Nitrogen Fertilizer		659,309			452,165			702,929
Other		137,834			238,658			(171,142	)

Total	$	3,119,291		$	1,740,184		$	1,614,494

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, 2011

Major Customers and Suppliers

Schedule of sales to major customers

	Year Ended December 31,

	2011			2010			2009
Petroleum
Customer A		15	%		14	%		14	%
Customer B		12	%		11	%		10	%
Customer C		9	%		10	%		11	%

		36	%		35	%		35	%

Nitrogen Fertilizer
Customer D		17	%		12	%		15	%
Customer E		12	%		10	%		9	%

		29	%		22	%		24	%

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,

	2011			2010			2009
Petroleum
Supplier A		65	%		64	%		69	%

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,

	2011			2010			2009
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, 2011

Selected Quarterly Financial Information (unaudited)

Summary of quarterly financial data

	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		274			211			93			(89	)
Gain (loss) on derivatives, net		(22,106	)		6,932			(9,925	)		103,179
Loss on extinguishment of debt		(1,908	)		(170	)		—			—
Other income, net		231			246			243			124

Total other income		(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

	Year Ended December 31, 2010

	Quarter
	First			Second			Third			Fourth
	(in thousands, except share data)
Net sales	$	894,512		$	1,005,898		$	1,031,174		$	1,148,184
Operating costs and expenses:
Cost of product sold (exclusive of depreciation and amortization)		802,890			891,652			889,850			983,726
Direct operating expenses (exclusive of depreciation and amortization)		60,562			62,479			52,534			64,216
Selling, general and administrative (exclusive of depreciation and amortization)		21,394			10,793			16,397			43,450
Depreciation and amortization		21,260			21,553			21,943			22,005

Total operating costs and expenses		906,106			986,477			980,724			1,113,397

Operating income (loss)		(11,594	)		19,421			50,450			34,787
Other income (expense):
Interest expense and other financing costs		(9,922	)		(12,766	)		(13,863	)		(13,717	)
Interest income		416			643			549			603
Gain (loss) on derivatives, net		1,490			7,339			(1,014	)		(9,320	)
Loss on extinguishment of debt		(500	)		(14,552	)		—			(1,595	)
Other income, net		42			642			17			517

Total other income (expense)		(8,474	)		(18,694	)		(14,311	)		(23,512	)

Income (loss) before income tax (benefit)		(20,068	)		727			36,139			11,275
Income tax expense (benefit)		(7,705	)		(425	)		12,932			8,981

Net income (loss)	$	(12,363	)	$	1,152		$	23,207		$	2,294

Net earnings (loss) per share
Basic	$	(0.14	)	$	0.01		$	0.27		$	0.03
Diluted	$	(0.14	)	$	0.01		$	0.27		$	0.03
Weighted-average common shares outstanding
Basic		86,329,237			86,336,125			86,343,102			86,352,627
Diluted		86,329,237			86,506,590			87,013,575			87,121,094

Organization and History of the Company (Details) $ / shares in Units, barrel in Millions, $ in Millions	1 Months Ended			12 Months Ended
	Dec. 31, 2011 barrelperday barrel shares	Apr. 30, 2011 USD ($) $ / shares shares	Oct. 31, 2007 entity	Dec. 31, 2011 USD ($) Segment type shares	Dec. 15, 2011 USD ($)	Dec. 31, 2010
Number of reportable segments \| Segment				2
Percentage of outstanding shares beneficially owned						40.00%
GWEC
Acquisition cost of the issued and outstanding shares of acquiree					$ 592.3
Initial cash payment					525.0
Capital expenditure adjustment					1.5
Working capital adjustment					$ 65.8
Capacity of refinery acquired by the entity in Wynnewood, Oklahoma (in bpd) \| barrelperday	70,000
Capacity of refinery owned by acquiree in Wynnewood, Oklahoma (in bpd) \| barrel	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 GP, LLC
Percentage of CVR's ownership interest in CVR GP, LLC	100.00%			100.00%
CVR Partners, LP
Percentage of CVR's indirect ownership in CVR Partners, LP	70.00%			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	73,030,936			73,030,936
Common units owned by the public (in shares) \| shares	22,110,936			22,110,936
Percentage of common units owned by the public	30.00%			30.00%
Common units owned by general partner (in units) \| shares	50,920,000			50,920,000
Percentage of common units owned by the general partner				70.00%
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				135.0
Amount spent for UAN expansion				43.6
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

Summary of Significant Accounting Policies (Details)	12 Months Ended
Summary of Significant Accounting Policies (Details)	Dec. 31, 2011 month officer	Dec. 31, 2010 customer
Principles of Consolidation
Number of officers of general partner who are not also officers of entity \| officer	1
Percentage of holders of the outstanding common units required to vote for removal of the general partner	66.667%
Cash and Cash Equivalents
Maximum original maturity in order to classify highly liquid money market accounts and debt instruments as cash equivalents (in months) \| month	3
Accounts receivable \| Customer concentration
Accounts Receivable, net
Number of customers		2
Accounts receivable \| Customer concentration \| One customer with largest risk concentration
Accounts Receivable, net
Number of customers		1
Accounts receivable \| Customer concentration \| Two customers with largest risk concentration, collectively
Accounts Receivable, net
Number of customers		2
Customers individually representing greater than this percentage for disclosure	10.00%	10.00%
Percentage of concentration risk		22.00%
Accounts receivable \| Credit concentration \| One customer with largest risk concentration
Accounts Receivable, net
Customers individually representing greater than this percentage for disclosure	9.00%	12.00%

Summary of Significant Accounting Policies (Details 2) $ in Millions	12 Months Ended
	Dec. 31, 2011 USD ($) $ / shares year month component
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) \| month	6
Goodwill and Intangible Assets
Number of components contained in each operating segment \| component	1
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) \| $ / shares	5
Useful life, high end of range (in years) \| $ / shares	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) \| $ / shares	25
Useful life, high end of range (in years) \| $ / shares	40

Summary of Significant Accounting Policies (Details 3) $ in Millions	12 Months Ended
	Dec. 31, 2011 USD ($) month year phase	Dec. 31, 2010 USD ($) year	Dec. 31, 2009 USD ($)
Cost Classifications
Depreciation and amortization not included in cost of product sold	$ 2.5	$ 2.8	$ 2.9
Depreciation and amortization not included in direct operating expenses	86.0	81.8	79.9
Depreciation and amortization not included in selling, general and administrative expenses	$ 1.8	2.1	$ 2.0
Revenue Recognition
Expected period of delivery of deferred revenue (in months) \| month	12
Share-Based Compensation
Vesting period (in years)	3 years
Coffeyville refinery
Planned Major Maintenance Costs
Number of phases \| phase	2
Turnaround costs	$ 66.4	1.2
Coffeyville refinery \| Minimum
Planned Major Maintenance Costs
Frequency of planned major maintenance activities (in years) \| year	4
Coffeyville refinery \| Maximum
Planned Major Maintenance Costs
Frequency of planned major maintenance activities (in years) \| year	5
Nitrogen fertilizer plant
Planned Major Maintenance Costs
Turnaround costs		$ 3.5
Frequency of planned major maintenance activities (in years) \| year		2

Summary of Significant Accounting Policies (Details 4) - Designated as hedges - CRNF $ in Millions	12 Months Ended
	Dec. 31, 2011 USD ($) agreement D	Jun. 30, 2011 agreement
Interest rate swap agreements
Derivative Financial Instruments
Borrowing capacity on credit facility \| $	$ 125.0
Aggregate notional amount \| $	$ 62.5
Average fixed rate of interest (as a percent)	1.96%
Number of Interest Rate Swap 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

Wynnewood Acquisition (Details) $ in Thousands, barrel in Millions	1 Months Ended	2 Months Ended	12 Months Ended
	Dec. 31, 2011 USD ($) year D barrelperday barrel subsidiary	Dec. 31, 2011 USD ($) year D	Dec. 31, 2011 USD ($) year D	Dec. 31, 2010 USD ($)	Dec. 15, 2011 USD ($)
Purchase Price Allocation
Total consideration transferred, net of cash acquired			$ 585,987
9.0% Senior Secured Notes, due 2015
Acquisition
Stated interest rate (as a percent)	9.00%	9.00%	9.00%
GWEC
Acquisition
Number of wholly-owned subsidiaries of acquired entity \| subsidiary	2
Acquisition cost of the issued and outstanding shares of acquiree					$ 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) \| barrelperday	70,000
Number of barrels of storage tanks owned by the entity included in the refinery of the acquiree \| barrel	2.0
Purchase Price Allocation
Cash and cash equivalents					6,300
Accounts Receivable					158,500
Inventories					213,500
Prepaid expenses and other current assets					6,000
Property, plant and equipment					574,500
Accounts payable and accrued liabilities					(314,200)
Long-term debt					(52,300)
Total fair values of net assets acquired					$ 592,300
Less: cash acquired	$ 6,300
Total consideration transferred, net of cash acquired	586,000
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	$ 15,800
Number of days seller has to review Post-Closing Statement \| D	30	30	30
Transaction fees and expenses included in selling, general and administrative expense		$ 5,200
Period of bridge loan (in years) \| year	1	1	1
Commitment fee and other third party costs			$ 3,900
GWEC \| 9.0% Senior Secured Notes, due 2015
Acquisition
Stated interest rate (as a percent)	9.00%	9.00%	9.00%

Share-Based Compensation (Details)	1 Months Ended						2 Months Ended	12 Months Ended
Share-Based Compensation (Details)	May 31, 2011 shares	Feb. 28, 2011 shares	Feb. 29, 2008 shares	Oct. 31, 2007 entity	Dec. 31, 2006 shares	Jun. 30, 2005 shares	Feb. 28, 2011 shares	Dec. 31, 2011 USD ($) $ / shares	Dec. 31, 2010 USD ($) $ / shares	Dec. 31, 2009 USD ($) $ / 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 common stocks sold into the public market (in shares) \| shares	7,988,179	11,759,023
CALLC II
Share-based Compensation
Number of common stocks sold into the public market (in shares) \| shares							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 Increase (Decrease) \| $								$ 5,595,000	$ 19,290,000	$ 4,158,000
Override Operating Units (a) \| CALLC and CALLC II
Key information for the share-based compensation plans related to the override units of CALLC, CALLC II and CALLC III
Benchmark Value (per Unit)								$ 11.31
Original Award Issued (in shares) \| shares						919,630
Compensation Expense Increase (Decrease) \| $									338,000	$ 1,369,000
Valuation Assumptions
CVR closing stock price (in dollars per share)										$ 6.86
Estimated fair value (per unit)										$ 11.95
Marketability and minority interest discounts (as a percent)										20.00%
Volatility (as a percent)										50.70%
Override Operating Units (b) \| CALLC and CALLC II
Key information for the share-based compensation plans related to the override units of CALLC, CALLC II and CALLC III
Benchmark Value (per Unit)								34.72
Original Award Issued (in shares) \| shares					72,492
Compensation Expense Increase (Decrease) \| $									13,000	$ 36,000
Valuation Assumptions
CVR closing stock price (in dollars per share)										$ 6.86
Estimated fair value (per unit)										$ 1.4
Marketability and minority interest discounts (as a percent)										20.00%
Volatility (as a percent)										50.70%
Override Value Units (c) \| CALLC and CALLC II
Key information for the share-based compensation plans related to the override units of CALLC, CALLC II and CALLC III
Benchmark Value (per Unit)								$ 11.31
Original Award Issued (in shares) \| shares						1,839,265
Compensation Expense Increase (Decrease) \| $								$ 4,960,000	$ 17,586,000	$ 2,690,000
Valuation Assumptions
Derived service period (in years)									6 years	6 years
CVR closing stock price (in dollars per share)									$ 15.18	$ 6.86
Estimated fair value (per unit)									$ 22.39	$ 5.63
Marketability and minority interest discounts (as a percent)									20.00%	20.00%
Volatility (as a percent)									43.00%	50.70%
Override Value Units (d) \| CALLC and CALLC II
Key information for the share-based compensation plans related to the override units of CALLC, CALLC II and CALLC III
Benchmark Value (per Unit)								$ 34.72
Original Award Issued (in shares) \| shares					144,966
Compensation Expense Increase (Decrease) \| $								$ 451,000	$ 581,000	$ 37,000
Valuation Assumptions
Derived service period (in years)									6 years	6 years
CVR closing stock price (in dollars per share)									$ 15.18	$ 6.86
Estimated fair value (per unit)									$ 6.56	$ 1.39
Marketability and minority interest discounts (as a percent)									20.00%	20.00%
Volatility (as a percent)									43.00%	50.70%
Override Units (e) \| 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)								$ 10.00
Original Award Issued (in shares) \| shares			642,219
Compensation Expense Increase (Decrease) \| $								$ 184,000	$ 772,000	$ 26,000
Valuation Assumptions
Estimated fair value (per unit)									$ 2.6	$ 0.08
Marketability and minority interest discounts (as a percent)									10.00%	20.00%
Volatility (as a percent)									47.60%	59.70%
Information of all overrides value units that are initially subject to forfeiture
Estimated grant date fair value \| $								$ 3,000
Number of units vested upon issuance (in shares) \| shares			109,720

Share-Based Compensation (Details 2) $ / shares in Units, $ in Thousands	1 Months Ended		3 Months Ended		12 Months Ended
	Nov. 30, 2010 USD ($)	Nov. 30, 2009 USD ($)	Jun. 30, 2011 USD ($)	Mar. 31, 2011 USD ($)	Dec. 31, 2011 USD ($) plan	Dec. 31, 2010 USD ($) $ / shares	Dec. 31, 2009 USD ($) $ / shares
Share-based Compensation
Personnel accruals					$ 20,849	$ 29,151
Phantom Unit Appreciation Plan
Share-based Compensation
Number of Phantom Unit Appreciation Plans \| plan					2
Payments to phantom unit holders	$ 3,600	$ 900	$ 9,200	$ 20,100
Personnel accruals					$ 0	18,700
Compensation expense					$ 10,600	$ 15,500	$ 3,700
Service Phantom interest
Share-based Compensation
Interest (per point) \| $ / shares						$ 14.64	$ 11.37
Performance Phantom interest
Share-based Compensation
Interest (per point) \| $ / shares						$ 21.25	$ 5.48

- 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)	12 Months Ended
Share-Based Compensation (Details 3)	Dec. 31, 2011 USD ($) year $ / shares shares	Dec. 31, 2010 USD ($) year $ / shares shares	Dec. 31, 2009 USD ($) year $ / shares shares	Dec. 31, 2008 USD ($) year $ / shares shares
Other disclosures
Vesting period (in years)	3 years
Long-Term Incentive Plan
Share-based Compensation
Common stock authorized for issuance (in shares)	7,500,000
Shares available for issuance	5,176,087
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	32,350	32,350
Forfeited (in shares)		(3,149)
Expired (in shares)		(6,301)
Options outstanding at the end of the period (in shares)	22,900	22,900	32,350	32,350
Exercisable at the end of the period (in shares)	22,900
Weighted-Average Exercise Price
Options outstanding at the beginning of the period (in dollars per share) \| $ / shares	$ 18.03	$ 19.08	$ 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	$ 19.08	$ 19.08
Exercisable at the end of the period (in dollars per share) \| $ / shares	$ 18.03
Weighted-Average Remaining Contractual Term
Options outstanding at the end of the period (in years) \| year	7.35	8.35	8.21	9.21
ShareBasedCompensationArrangementByShareBasedPaymentAwardOptionsExercisableWeightedAverageRemainingContractualTerm \| year	7.35
Other disclosures
Weighted-average grant-date fair value of options granted (in dollars per share) \| $ / shares				$ 8.97
Aggregate intrinsic value of options exercisable \| $	$ 70,000
Compensation expense \| $	$ 8,000	$ 9,000	$ 118,000
Long-Term Incentive Plan \| Restricted Stock
Non-vested shares activity
Non-vested at the beginning of the period (in shares)	1,369,182	177,060	78,666
Granted (in shares)	826,959	1,307,378	202,257
Vested (in shares)	(557,355)	(113,457)	(100,763)
Forfeited (in shares)	(4,632)	(1,799)	(3,100)
Non-vested at the end of the period (in shares)	1,634,154	1,369,182	177,060	78,666
Weighted-Average Grant-Date Fair Value
Non-vested at the beginning of the period (in dollars per share) \| $ / shares	$ 10.94	$ 6.59	$ 6.62
Granted (in dollars per share) \| $ / shares	18.79	11.42	6.68
Vested (in dollars per share) \| $ / shares	11.83	9.79	6.86
Forfeited (in dollars per share) \| $ / shares	8.67	4.14	4.14
Non-vested at the end of the period (in dollars per share) \| $ / shares	$ 14.61	$ 10.94	$ 6.59	$ 6.62
Other disclosures
Aggregate Intrinsic Value \| $	$ 30,608,000	$ 20,784,000	$ 1,215,000	$ 315,000
Unrecognized compensation cost \| $	$ 19,500,000
Weighted-average period for amortization of unrecognized compensation cost (in years) \| year	2
Aggregate fair value at the grant date of the shares that vested \| $	$ 6,600,000
Aggregate fair value at grant date of unvested stock outstanding \| $	23,900,000	15,000,000	1,200,000
Compensation expense \| $	$ 9,800,000	$ 2,400,000	$ 800,000

Share-Based Compensation (Details 4) $ in Thousands	1 Months Ended				12 Months Ended
Share-Based Compensation (Details 4) $ in Thousands	Dec. 31, 2011 USD ($) shares	Aug. 31, 2011 shares	Jun. 30, 2011 shares	Apr. 30, 2011 shares	Dec. 31, 2011 USD ($) employee shares	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)
Share-based Compensation
Vesting period (in years)					3 years
CVR Partners' Long-Term Incentive Plan \| Phantom stock units \| Employees of general partner
Share-based Compensation
Vesting period (in years)	3 years
CVR Partners' Long-Term Incentive Plan \| Common units \| Employees of general partner
Share-based Compensation
Number of units granted (in shares)	9,672
CVR Partners, LP \| CVR Partners' Long-Term Incentive Plan
Share-based Compensation
Common stock authorized for issuance (in shares)				5,000,000
Compensation expense \| $					$ 1,200	$ 0	$ 0
Shares available for issuance	4,799,353				4,799,353
CVR Partners, LP \| CVR Partners' Long-Term Incentive Plan \| Phantom stock units
Share-based Compensation
Unrecognized compensation cost \| $	$ 3,600				$ 3,600
CVR Partners, LP \| CVR Partners' Long-Term Incentive Plan \| Phantom stock units \| Board members of general partner
Share-based Compensation
Number of units granted (in shares)				23,448
CVR Partners, LP \| CVR Partners' Long-Term Incentive Plan \| Phantom stock units \| Employees of general partner
Share-based Compensation
Number of units granted (in shares)		12,815	50,659
Vesting period (in years)		3 years	3 years
Fraction of stock awards vested per year (as a percent)			33.00%
Fraction of stock awards vested per year (as a percent)		33.00%
CVR Partners, LP \| CVR Partners' Long-Term Incentive Plan \| Phantom stock units \| Employees of general partner and CRNF and employee of CVR Energy
Share-based Compensation
Number of units granted (in shares)	101,097
Vesting period (in years)	3 years
Fraction of stock awards vested per year (as a percent)	33.00%
Percentage of time dedicated by employee of CVR Energy to the business of CVR Partners					100.00%
Number of Employees of Reporting Entity Receiving Share-based Payment Award \| employee					1
CVR Partners, LP \| CVR Partners' Long-Term Incentive Plan \| Common units \| Board members of general partner
Share-based Compensation
Number of units granted (in shares)			2,956

Inventories (Details) - USD ($) $ in Thousands	Dec. 31, 2011	Dec. 31, 2010
Inventories
Finished goods	$ 323,315	$ 110,788
Raw materials and precious metals	157,931	89,333
In-process inventories	115,372	22,931
Parts and supplies	39,603	24,120
Inventories	$ 636,221	$ 247,172

Property, Plant, and Equipment (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Property, Plant, and Equipment
Gross property, plant and equipment	$ 2,151,286	$ 1,470,721
Accumulated depreciation	478,325	389,409
Property, plant, and equipment, net of accumulated depreciation	1,672,961	1,081,312
Capitalized interest	3,900	1,800	$ 2,000
Original carrying value of assets under capital lease obligations	24,900	5,200
Land and improvements
Property, Plant, and Equipment
Gross property, plant and equipment	26,136	19,228
Buildings
Property, Plant, and Equipment
Gross property, plant and equipment	37,289	25,663
Machinery and equipment
Property, Plant, and Equipment
Gross property, plant and equipment	1,967,269	1,363,877
Automotive equipment
Property, Plant, and Equipment
Gross property, plant and equipment	10,217	8,747
Furniture and fixtures
Property, Plant, and Equipment
Gross property, plant and equipment	12,349	9,279
Leasehold improvements
Property, Plant, and Equipment
Gross property, plant and equipment	1,445	1,253
Railcars
Property, Plant, and Equipment
Gross property, plant and equipment	2,496
Construction in progress
Property, Plant, and Equipment
Gross property, plant and equipment	$ 94,085	$ 42,674

Goodwill and Intangible Assets (Details) - USD ($)	12 Months Ended
Goodwill and Intangible Assets (Details) - USD ($)	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2005
Goodwill and Intangible Assets
Goodwill	$ 40,969,000	$ 40,969,000	$ 40,969,000
Estimated amortization of the contractual agreements
Weighting of both income and market approaches for determining the fair value of goodwill (as a percent)		50.00%	50.00%
Discount rate used to estimate fair value of goodwill (as a percent)		14.60%	13.40%
CALLC
Other Intangible Assets
Fair market value of contractual agreements acquired in connection with the acquisition				$ 1,300,000
Accumulated amortization related to contractual agreements	1,000,000
Amortization expense related to contractual agreements	33,000	$ 33,000	$ 33,000
Estimated amortization of the contractual agreements
2012	28,000
2013	27,000
2014	27,000
2015	27,000
2016	27,000
Thereafter	175,000
Total	$ 311,000

Deferred Financing Costs and Original Issue Discount (Details) - USD ($)	1 Months Ended							3 Months Ended					12 Months Ended
	Dec. 31, 2011	May 31, 2011	Dec. 31, 2010	Jul. 31, 2010	Apr. 30, 2010	Mar. 31, 2010	Oct. 31, 2009	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010	Jun. 30, 2010	Mar. 31, 2010	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009	Dec. 15, 2011	Apr. 06, 2010
Deferred Financing Costs and Original Issue Discount
Aggregate principal amount				$ 5,000,000									$ 8,800,000
Third party costs incurred													15,133,000	$ 8,775,000	$ 3,975,000
Deferred third party costs	$ 32,631,000		$ 18,029,000							$ 18,029,000			32,631,000	18,029,000
Loss on extinguishment of debt								$ 170,000	$ 1,908,000	1,595,000	$ 14,552,000	$ 500,000	2,078,000	16,647,000	2,101,000
Additional loss on extinguishment of debt														10,400,000
Amortization of deferred financing costs reported as interest expense and other financing costs													4,900,000	3,700,000	1,900,000
Estimated amortization of deferred financing costs
2012													7,382,000
2013													7,373,000
2014													7,373,000
2015													4,189,000
2016													1,151,000
Thereafter													233,000
Total													$ 27,701,000
Senior Secured Notes
Deferred Financing Costs and Original Issue Discount
Unscheduled voluntary prepayment		$ 2,700,000
Estimated amortization of deferred financing costs
Purchase price (as a percent)		103.00%
Senior Secured Notes \| CRLLC and Coffeyville Finance Inc. (Issuers)
Deferred Financing Costs and Original Issue Discount
Aggregate principal amount					$ 500,000,000
Third party costs incurred	2,000,000				3,900,000
Third party costs expensed					30,000
Deferred third party costs																	$ 3,900,000
Underwriter fees	4,000,000				10,000,000
Underwriting discount expensed	4,000,000				76,000
Deferred underwriting discounts																	$ 9,900,000
Senior Secured Notes \| CRLLC
Deferred Financing Costs and Original Issue Discount
Aggregate principal amount	$ 200,000,000
Unscheduled voluntary prepayment			27,500,000
Loss on extinguishment of debt														6,300,000	2,100,000
Write-off of deferred financing costs and original issue discount		$ 89,000	770,000
Additional loss on extinguishment of debt		81,000
Amount of debt repurchased		$ 2,700,000
Original issue premium																$ 10,000,000
Estimated amortization of deferred financing costs
Purchase price (as a percent)		103.00%
First Priority Credit Facility \| CRLLC
Deferred Financing Costs and Original Issue Discount
Write-off of deferred financing cost					5,400,000
Third party costs incurred						$ 6,000,000	$ 4,000,000
Third party costs expensed														1,100,000	1,000,000
Deferred third party costs			$ 4,900,000							$ 4,900,000				$ 4,900,000	$ 3,000,000
Tranche D term loan \| CRLLC
Deferred Financing Costs and Original Issue Discount
Unscheduled voluntary prepayment												$ 25,000,000
Amount of debt repurchased					$ 453,300,000

Note Payable and Capital Lease Obligations (Details) $ in Thousands	1 Months Ended				12 Months Ended
	Mar. 31, 2011 USD ($)	Jul. 31, 2010 USD ($)	Jun. 30, 2010 USD ($) year	May 31, 2008 year renewal	Dec. 31, 2011 USD ($) agreement month	Dec. 31, 2010 USD ($) agreement month	Dec. 31, 2009 USD ($)
Note Payable and Capital Lease Obligations
Note payable balance					$ 9,900	$ 3,100
Borrowings on note payable		$ 5,000			8,800
Capital lease obligations
Payment of capital lease obligations					4,897	193	$ 100
Outstanding obligation					$ 853,903	$ 468,954
Wynnewood Acquisition \| Capitial lease obligations assumed in acquisition
Capital lease obligations
Number of lease agreements assumed in acquisition \| agreement					2
Outstanding obligation					$ 53,200
Wynnewood Acquisition \| Capitial Lease related to Magellan Pipeline Terminals, L.P.
Capital lease obligations
Remaining term of leases (in months) \| month					213
Wynnewood Acquisition \| Capitial Lease related to Excel Pipeline
Capital lease obligations
Remaining term of leases (in months) \| month					214
Information technology equipment
Capital lease obligations
Number of capital lease agreements \| agreement						2
Capital lease obligation					$ 100
Capital lease obligations incurred						$ 400
Capital lease term for first agreement (in months) \| month						12
Capital lease term for second agreement (in months) \| month						36
Real property
Capital lease obligations
Capital lease obligation						$ 4,600
Initial contractual lease term (in years) \| year				1
Frequency of capital lease renewal \| renewal				3
Contractual lease renewal term (in years) \| year			1	1
Payment of capital lease obligations	$ 4,700
Total annual capital lease payments			$ 100

Flood (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
Flood (Details) - USD ($) $ in Millions	Mar. 31, 2009	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Flood
Pre-tax expenses, net of anticipated insurance recoveries		$ 1.5	$ (1.0)	$ 0.6
Final insurance proceeds received under the Company's property insurance policy and builders' risk policy	$ 11.8

- Definition

The gross income statement effect of insurance proceeds for each material event or transaction (that would not reasonably be expected to recur in the foreseeable future) that possesses a high degree of abnormality and are clearly unrelated to, or incidentally related to, the ordinary and typical activities of the entity.

+ References + Details

Insurance Claims (Details) $ in Thousands	1 Months Ended	12 Months Ended		13 Months Ended	15 Months Ended
Insurance Claims (Details) $ in Thousands	Dec. 31, 2010 USD ($)	Dec. 31, 2011 USD ($) D	Dec. 31, 2010 USD ($)	Dec. 31, 2011 USD ($)	Dec. 31, 2011 USD ($)
Insurance Claims
Property damage insurance deductible amount		$ 2,500		$ 2,500	$ 2,500
Minimum number of days of business interruption covered under the insurance policies \| D		45
Business interruption insurance proceeds		$ 3,360
Insurance proceeds on Coffeyville Refinery incident		4,000
Nitrogen Fertilizer Incident
Insurance Claims
Repairs and other associated costs recognized		900	$ 10,500
Repairs and other associated costs					11,400
Repairs and other associated costs capitalized	$ 4,500	100	$ 4,500	100	100
Insurance proceeds for UAN reactor rupture	$ 4,300	2,700		7,000
Business interruption insurance proceeds		3,400
Coffeyville refinery incident in connection with FCCU
Insurance Claims
Repairs and other associated costs		8,000
Insurance proceeds on Coffeyville Refinery incident		4,000
Insurance receivable		1,200		1,200	1,200
Coffeyville refinery incident at CCR
Insurance Claims
Repairs and other associated costs		3,200
Insurance receivable		$ 700		$ 700	$ 700

Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
Income Taxes (Details) - USD ($) $ in Thousands	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010	Sep. 30, 2010	Jun. 30, 2010	Mar. 31, 2010	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Current
Federal									$ 141,305	$ 13,434	$ 33,651
State									7,972	1,262	2,866
Total current									149,277	14,696	36,517
Deferred
Federal									40,350	808	(6,613)
State									19,936	(1,721)	(669)
Total deferred									60,286	(913)	(7,282)
Total income tax expense	$ 37,103	$ 68,603	$ 76,738	$ 27,119	$ 8,981	$ 12,932	$ (425)	$ (7,705)	$ 209,563	13,783	29,235
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									$ 205,843	9,826	34,506
State income taxes, net of federal tax benefit									20,600	1,923	5,402
State tax incentives, net of federal tax expense									(3,174)	(2,382)	(3,205)
Domestic production activities deduction									(10,562)	(2,025)	(3,798)
Federal tax credit for production of ultra-low sulfur diesel fuel											(4,783)
Non-deductible share-based compensation									2,000	6,747	1,457
IRS interest (income)/expense, net									34	(814)
Noncontrolling interest									(11,474)
Partnership basis adjustment									4,174
Other, net									2,122	508	(344)
Total income tax expense	37,103	$ 68,603	$ 76,738	$ 27,119	8,981	$ 12,932	$ (425)	$ (7,705)	209,563	13,783	29,235
Deferred income tax assets:
Allowance for doubtful accounts	475				286				475	286
Personnel accruals	6,437				10,389				6,437	10,389
Inventories	2,097				469				2,097	469
Unrealized derivative losses, net					1,604					1,604
Low sulfur diesel fuel credit carry forward and other general business credit carryforward					23,653					23,653
Accrued expenses	101				199				101	199
State tax credit carryforward, net of federal expense	17,682				29,955				17,682	29,955
Deferred financing	76				101				76	101
Other	2,695				3,018				2,695	3,018
Total gross deferred income tax assets	29,563				69,674				29,563	69,674
Deferred income tax liabilities:
Unrealized derivative gains, net	(31,990)								(31,990)
Property, plant, and equipment	(224,452)				(323,839)				(224,452)	(323,839)
Investment in Partnership	(134,920)								(134,920)
Prepaid expenses	(4,945)				(1,427)				(4,945)	(1,427)
Total gross deferred income tax liabilities	(396,307)				(325,266)				(396,307)	(325,266)
Net deferred income tax liabilities	$ (366,744)				$ (255,592)				(366,744)	(255,592)
Kansas state
Income Tax Credit Authority [Line Items]
Net income tax benefit recognized from Kansas High Performance Incentive Program									3,200	2,400	3,200
Kansas High Performance Incentive Program (HPIP) credits for qualified business facility investment earned									$ 4,900	$ 3,700	$ 4,900

Income Taxes (Details 2)	12 Months Ended
Income Taxes (Details 2)	Dec. 31, 2011 USD ($) shareholder	Dec. 31, 2010 USD ($)
Income taxes
Number of largest shareholders \| shareholder	2
Annual limitation for the use of general business federal tax credit carryforwards	$ 24,000,000
Tax benefits related to the deductibility of stock-based compensation	2,300,000
Federal and state interest expense and penalties	100,000
Interest income related to 2005 and 2006 amended returns to carryback 2007 losses		$ 1,300,000
Unrecognized tax benefits which, if recognized, would impact the Company's effective tax rate	17,500,000
Reconciliation of the unrecognized tax benefits
Balance beginning of year	245,000
Increase based on prior year tax positions		245,000
Increases and decrease in current year tax positions	17,467,000
Balance end of year	17,712,000	$ 245,000
Kansas state
Income taxes
Tax credit carryforwards	$ 27,200,000

Long-Term Debt (Details)	1 Months Ended							3 Months Ended						12 Months Ended
Long-Term Debt (Details)	Dec. 31, 2011 USD ($)	May 31, 2011 USD ($)	Apr. 30, 2011 USD ($)	Feb. 28, 2011	Dec. 31, 2010 USD ($) letter	Jul. 31, 2010 USD ($)	Apr. 30, 2010 USD ($)	Dec. 31, 2011 USD ($)	Jun. 30, 2011 USD ($)	Mar. 31, 2011 USD ($)	Dec. 31, 2010 USD ($) letter	Jun. 30, 2010 USD ($)	Mar. 31, 2010 USD ($)	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($) letter	Dec. 31, 2009 USD ($)	Dec. 15, 2011 USD ($)	Nov. 02, 2011 year	May 16, 2011	Apr. 14, 2011 USD ($)	Apr. 13, 2011 USD ($)	Feb. 22, 2011 USD ($)	Dec. 30, 2010	Apr. 06, 2010 USD ($)
Long-Term Debt
Capital lease obligations	$ 52,259,000							$ 52,259,000						$ 52,259,000
Long-term debt	853,903,000				$ 468,954,000			853,903,000			$ 468,954,000			853,903,000	$ 468,954,000
Aggregate principal amount						$ 5,000,000								8,800,000
Loss on extinguishment of debt									$ (170,000)	$ (1,908,000)	(1,595,000)	$ (14,552,000)	$ (500,000)	(2,078,000)	(16,647,000)	$ (2,101,000)
Total net proceeds from the offering														206,000,000
Lender and other third party costs incurred	32,631,000				18,029,000			32,631,000			18,029,000			32,631,000	18,029,000
CRLLC \| LIBOR
Long-Term Debt
Variable rate basis				LIBOR
CRLLC \| LIBOR \| Minimum
Long-Term Debt
Basis spread on variable rate (as a percent)																						2.75%
CRLLC \| LIBOR \| Maximum
Long-Term Debt
Basis spread on variable rate (as a percent)																						3.00%
CRLLC \| Prime
Long-Term Debt
Variable rate basis				prime rate
CRLLC \| Prime \| Minimum
Long-Term Debt
Basis spread on variable rate (as a percent)																						1.75%
CRLLC \| Prime \| Maximum
Long-Term Debt
Basis spread on variable rate (as a percent)																						2.00%
CVR Partners, LP
Long-Term Debt
Underwriter fees														24,700,000
First Priority Credit Facility \| CRLLC
Long-Term Debt
Lender and other third party costs incurred					4,900,000						4,900,000				4,900,000	3,000,000
Portion of unamortized deferred financing cost incurred written off							$ 5,400,000
First priority revolving credit facility \| CRLLC
Long-Term Debt
Borrowing capacity					150,000,000						150,000,000				150,000,000
Aggregate availability					79,600,000						79,600,000				79,600,000
Lender and other third party costs incurred										800,000
Letters of credit \| CRLLC
Long-Term Debt
Outstanding letters of credit					70,400,000						70,400,000				70,400,000
Letters of credit in support of certain environmental obligations \| CRLLC
Long-Term Debt
Outstanding letters of credit					200,000						200,000				200,000
Letters of credit to secure transportation services for crude oil \| CRLLC
Long-Term Debt
Outstanding letters of credit					30,600,000						30,600,000				30,600,000
Standby letters of credit issued in support of the purchase of feedstocks \| CRLLC
Long-Term Debt
Outstanding letters of credit					$ 39,700,000						$ 39,700,000				$ 39,700,000
Number of letters of credit \| letter					2						2				2
Tranche D term loan \| CRLLC
Long-Term Debt
Principal payment													$ 25,000,000
Prepayment premium percentage													2.00%											2.00%
Principal amount of debt extinguished							453,300,000
Prepayment Premium							9,100,000						$ 500,000
Senior Secured Notes
Long-Term Debt
Principal payment		$ 2,700,000
Accrued interest payable	16,100,000				$ 11,800,000			16,100,000			$ 11,800,000			16,100,000	$ 11,800,000
Purchase price as a percentage of the principal amount at which the entity is required to purchase a portion of the notes		103.00%
Senior Secured Notes \| Maximum
Long-Term Debt
Amount of debt to be purchased under a fertilizer event offer																				$ 100,000,000
Senior Secured Notes \| CRLLC and Coffeyville Finance Inc. (Issuers)
Long-Term Debt
Aggregate principal amount							500,000,000
Underwriter fees	4,000,000						10,000,000
Underwriting discount expensed	4,000,000						76,000
Lender and other third party costs incurred																								$ 3,900,000
Senior Secured Notes \| CRLLC
Long-Term Debt
Unamortized discount																								4,000,000
Unamortized premium																	$ 10,000,000
Aggregate principal amount	200,000,000
Principal payment					27,500,000
Prepayment premium percentage																			3.00%
Loss on extinguishment of debt															(6,300,000)	$ (2,100,000)
Total net proceeds from the offering							485,700,000
Original issue discount																								$ 4,000,000
Third party fees							287,000
Additional third party fees and expenses associated with the offering							3,600,000
Principal amount of debt extinguished		$ 2,700,000
Purchase price as a percentage of the principal amount at which the entity is required to purchase a portion of the notes		103.00%
9.0% Senior Secured Notes, due 2015
Long-Term Debt
Long-term debt	$ 456,053,000				246,435,000			$ 456,053,000			246,435,000			$ 456,053,000	246,435,000
Stated interest rate (as a percent)	9.00%							9.00%						9.00%
Net unamortized premium	$ 9,003,000							$ 9,003,000						$ 9,003,000
Principal payment		$ 500,000
9.0% Senior Secured Notes, due 2015 \| 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%
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					27,500,000
Prepayment premium percentage																							3.00%
Loss on extinguishment of debt					1,600,000
Estimated fair value	473,900,000							473,900,000						473,900,000
Original issue discount	900,000							900,000						900,000
10.875% Senior Secured Notes, due 2017
Long-Term Debt
Long-term debt	$ 220,591,000				222,519,000			$ 220,591,000			222,519,000			$ 220,591,000	222,519,000
Stated interest rate (as a percent)	10.875%							10.875%						10.875%
Unamortized discount	$ 2,159,000				2,481,000			$ 2,159,000			2,481,000			$ 2,159,000	2,481,000
Principal payment		$ 2,200,000
Estimated fair value	249,500,000							249,500,000						249,500,000
Original issue discount	2,159,000				2,481,000			2,159,000			2,481,000			2,159,000	2,481,000
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%
Original Notes \| CRLLC
Long-Term Debt
Long-term debt	246,200,000				246,400,000			246,200,000			246,400,000			246,200,000	246,400,000
Unamortized discount	900,000				1,065,000			900,000			1,065,000			900,000	1,065,000
Original issue discount	900,000				$ 1,065,000			900,000			$ 1,065,000			900,000	$ 1,065,000
New Notes \| CRLLC
Long-Term Debt
Long-term debt	$ 209,900,000							$ 209,900,000						$ 209,900,000
Stated interest rate (as a percent)	9.00%							9.00%						9.00%
Unamortized discount	$ 4,000,000							$ 4,000,000						$ 4,000,000
Unamortized premium	9,900,000							$ 9,900,000						$ 9,900,000
Aggregate principal amount	$ 200,000,000
Issue price as a percentage of principal amount	105.00%							105.00%						105.00%
Total net proceeds from the offering														$ 202,800,000
Original issue discount	$ 4,000,000							$ 4,000,000						4,000,000
Third party fees														800,000
Bridge loan commitment and other associated fees														3,300,000
Commitment fees														2,600,000
Structuring fees														200,000
Fees and third party costs														3,900,000
Accrued interest payable								3,700,000
Bridge loan \| CRLLC
Long-Term Debt
Period of bridge loan (in years) \| year																		1
ABL Credit Facility \| CRLLC
Long-Term Debt
Lender and other third party costs incurred	9,100,000							9,100,000						9,100,000
Portion of unamortized deferred financing cost incurred written off										$ 1,900,000
ABL Credit Facility \| CRLLC \| Prime
Long-Term Debt
Borrowing capacity																	$ 400,000,000					$ 250,000,000
Outstanding letters of credit	86,100,000							86,100,000						86,100,000
Aggregate availability	313,900,000							313,900,000						313,900,000
Letter of credit sublimit as a percentage of the total facility commitment																						90.00%
Maximum borrowing capacity optional expansion																						$ 250,000,000
Term loan facility \| CRNF
Long-Term Debt
Borrowing capacity																					$ 125,000,000
Partnership credit facility
Long-Term Debt
Long-term debt	125,000,000							125,000,000						125,000,000
Partnership credit facility \| CRNF \| Prime
Long-Term Debt
Variable rate basis			prime rate
Basis spread on variable rate (as a percent)																					2.50%
Partnership credit facility \| CRNF \| Eurodollar
Long-Term Debt
Variable rate basis			Eurodollar rate
Basis spread on variable rate (as a percent)																					3.50%
Partnership credit facility \| CVR Partners, LP
Long-Term Debt
Lender and other third party costs incurred	$ 4,800,000							$ 4,800,000						$ 4,800,000
Amount of special distribution made by the Partnership to CRLLC upon closing of credit facility			$ 87,200,000
Revolving credit facility \| CRNF
Long-Term Debt
Borrowing capacity																					$ 25,000,000
Uncommitted incremental facility			$ 50,000,000

Long-Term Debt (Details 2) $ in Thousands	12 Months Ended
Long-Term Debt (Details 2) $ in Thousands	Dec. 31, 2011 USD ($) month
Future payments required under capital leases
Long-term portion	$ 52,259
Wynnewood Acquisition \| Capital lease
Future payments required under capital leases
2012	6,239
2013	6,269
2014	6,312
2015	6,355
2016	6,412
2017 and thereafter	83,199
Total future payments	114,786
Less: amount representing interest	61,567
Present value of future minimum payments	53,219
Less: current portion	960
Long-term portion	$ 52,259
Wynnewood Acquisition \| Capitial Lease related to Magellan Pipeline Terminals, L.P.
Deferred Financing Costs and Original Issue Discount
Remaining term of leases (in months) \| month	213
Wynnewood Acquisition \| Capitial Lease related to Excel Pipeline LLC
Deferred Financing Costs and Original Issue Discount
Remaining term of leases (in months) \| month	214

Earnings Per Share (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010	Sep. 30, 2010	Jun. 30, 2010	Mar. 31, 2010	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Earnings Per Share
Net income attributable to CVR Energy Stockholders	$ 65,858	$ 109,265	$ 124,865	$ 45,788					$ 345,776	$ 14,290	$ 69,354
Weighted-average number of shares of common stock outstanding	86,852,800	86,549,846	86,422,881	86,413,781	86,352,627	86,343,102	86,336,125	86,329,237	86,493,735	86,340,342	86,248,205
Effect of dilutive securities:
Non-vested common stock (in shares)									1,268,471	448,837	94,228
Stock Options (in shares)									4,367
Weighted-average number of shares of common stock outstanding assuming dilution	87,746,843	87,743,600	87,789,351	87,783,857	87,121,094	87,013,575	86,506,590	86,329,237	87,766,573	86,789,179	86,342,433
Basic earnings per share (in dollars per share)	$ 0.76	$ 1.26	$ 1.44	$ 0.53	$ 0.03	$ 0.27	$ 0.01	$ (0.14)	$ 4.00	$ 0.17	$ 0.80
Diluted earnings per share (in dollars per share)	$ 0.75	$ 1.25	$ 1.42	$ 0.52	$ 0.03	$ 0.27	$ 0.01	$ (0.14)	$ 3.94	$ 0.16	$ 0.80
Antidilutive outstanding stock options excluded from the calculation of diluted earnings per share (in shares)									18,533	22,900	32,350

Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010	Sep. 30, 2010	Jun. 30, 2010	Mar. 31, 2010	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Comprehensive Income (Loss)
Net income	$ 78,334	$ 120,241	$ 134,196	$ 45,788	$ 2,294	$ 23,207	$ 1,152	$ (12,363)	$ 378,559	$ 14,290	$ 69,354
Other comprehensive income (loss):
Net unrealized gain (loss) on available-for-sale securities, net of tax of $(1), $2, $0									(1)	2
Net unrealized gain (loss) on available-for-sale tax securities, tax effect									(1)	2	0
Change in fair value of cash flow hedge, net of tax of $(1,235), $0, $0									(1,899)
Reclassification adjustment to net income on partial settlement of cash flow hedge									167
Net unrealized loss on hedging instruments, tax effect									(1,235)	0	0
Other comprehensive income (loss)									376,826	14,292	69,354
Less: Other comprehensive income (loss) attributable to non-controlling interest									32,060
Comprehensive income attributable to CVR stockholders									$ 344,766	$ 14,292	$ 69,354

Benefit Plans (Details) - Defined-contribution 401(k) plans $ in Millions	12 Months Ended
	Dec. 31, 2011 USD ($) year plan	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)
Benefit Plans
Number of defined-contribution 401(k) plans \| plan	3
Vesting schedule for employer's matching funds (in years) \| year	3
Matching contributions made by the company during the year \| $	$ 2.3	$ 2.2	$ 2.1
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)	75.00%
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)	75.00%
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, 2011 USD ($) year barrel	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)
Operating Leases
2012	$ 8,793
2013	8,022
2014	6,076
2015	4,566
2016	3,776
Thereafter	8,332
Operating leases	39,565
Unconditional Purchase Obligations
2012	102,164
2013	101,164
2014	101,244
2015	93,819
2016	94,155
Thereafter	411,408
Unconditional purchase obligations	903,954
Lease expenses	5,100	$ 5,100	$ 5,100
Petroleum transportation service agreement with TransCanada \| CRRM
Unrecorded purchase agreements
Amount payable related to petroleum transportation service agreements	$ 500,900
Term of agreement (in years) \| year	10
Minimum quantity of crude oil to be received per day (in barrels) \| barrel	25,000

Commitments and Contingencies (Details 2) barrelperyear in Millions	1 Months Ended					12 Months Ended
	Aug. 31, 2010 USD ($)	May 31, 2009 USD ($)	Oct. 31, 2008 year barrelperday	Aug. 31, 2008 USD ($)	Nov. 30, 2007 USD ($)	Dec. 31, 2011 USD ($) year barrelperday	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)	Dec. 31, 2007 year barrelperyear	Dec. 31, 2005 USD ($) barrelperyear	Dec. 31, 2004 barrelperday	Dec. 15, 2011 USD ($)
Long-term commitments
Amount paid under agreement						$ 91,224,000	$ 32,409,000	$ 48,773,000
City \| CRNF
Long-term commitments
Minimum committed contractual payment	$ 1,900,000
Estimated remaining obligation				$ 14,900,000
City \| Lawsuit under long-term purchase agreement \| CRNF
Long-term commitments
Receipt of refunds	$ 4,800,000
Throughput and deficiency agreement assumed \| Wynnewood Acquisition
Long-term commitments
Estimated annual expenses associated with agreement												$ 4,000,000
Material \| Plains Pipeline \| CRRM
Long-term commitments
Minimum barrels of crude oil to be transported per day \| barrelperday						80,000
Term of agreement (in years) \| year						5
Term of agreement over which a quantity of materials must be purchased to meet the capacity of the supplier (in years) \| year						15
Expenses related to agreement						$ 9,800,000	11,400,000	11,000,000
Material \| MAPL \| CRRM
Long-term commitments
Minimum barrels of crude oil to be transported per day \| barrelperyear										2.0
Expenses related to agreement						1,300,000	2,400,000	2,400,000
Material \| CCPS \| CRRM
Long-term commitments
Minimum barrels of crude oil to be transported per day \| barrelperday											10,000
Expenses related to agreement						8,400,000	16,600,000	9,700,000
Material \| Plains \| CRRM
Long-term commitments
Minimum barrels of crude oil to be transported per day \| barrelperyear									29.2
Expenses related to agreement						2,400,000	2,500,000	2,600,000
Annual automatic extension period of agreement (in years) \| year									1
Period after which agreement is subject to annual automatic extensions									2 years 1 day
Expenses related to separate Terminalling Agreement						3,300,000	3,100,000	3,500,000
Material \| Linde, Inc. \| CRNF
Long-term commitments
Minimum committed contractual payment										$ 300,000
Expenses related to agreement						$ 4,200,000	4,700,000	4,100,000
Material \| Enterprise \| CRRM
Long-term commitments
Term of agreement (in years) \| year						5
Expenses related to agreement						$ 1,800,000	1,300,000	1,300,000
Material \| Magellan
Long-term commitments
Minimum barrels of crude oil to be transported per day \| barrelperday			20,000
Term of agreement (in years) \| year			10
Expenses related to agreement						700,000	$ 600,000	$ 60,000
Equipment and Materials \| Cominco Fertilizer Partnership \| CRNF
Long-term commitments
Minimum committed contractual payment		$ 4,300,000			$ 3,500,000
Amount paid under agreement		$ 2,300,000
Amount accrued for dismantling and removal of unit						2,900,000
Amount accrued related to nitric acid plant and dismantling obligation						$ 4,900,000

Commitments and Contingencies (Details 3) $ in Thousands	1 Months Ended							3 Months Ended	12 Months Ended
Commitments and Contingencies (Details 3) $ in Thousands	Oct. 31, 2011 USD ($)	Jun. 30, 2010 USD ($)	May 31, 2010 lawsuit	Feb. 28, 2010 month year	Oct. 31, 2009 USD ($) plaintiff	May 31, 2008 USD ($) claimant	Mar. 31, 2004 USD ($)	Mar. 31, 2004 USD ($)	Dec. 31, 2011 USD ($) year landfill	Dec. 31, 2010 USD ($) landfill	Dec. 31, 2009 USD ($)	Dec. 31, 2008 USD ($)	Oct. 25, 2010 USD ($)	Feb. 24, 2010 USD ($)
Commitments and Contingencies
Insurance proceeds under primary environmental liability insurance policy										$ 3,161
Estimated future payments for environmental obligations
Expenses related to environmental, health and safety ("EHS") matters									$ 7,600	13,700	$ 24,400
Litigation \| CRRM
Commitments and Contingencies
Increase in expenses related to use of inbound and outbound lines	$ 14,750
Litigation \| CRNF
Commitments and Contingencies
Property tax abatement period (in years) \| year									10
Increase in property tax expenses									$ 11,400	11,700	$ 10,700	$ 10,700
Litigation \| Oklahoma and Kansas \| CRRM
Commitments and Contingencies
Number of lawsuits filed \| lawsuit			2
Flood, Crude Oil Discharge and Insurance
Commitments and Contingencies
Number of private claimants \| claimant						16
Aggregate amount of claims		$ 3,200			$ 3,200	$ 4,400
Number of additional plaintiffs \| plaintiff					3
Reimbursement of oversight cost													$ 1,800
Insurance proceeds under primary environmental liability insurance policy									25,000
EHS
Environmental, Health, and Safety ("EHS") Matters
Environmental accruals									1,900	4,100
Environmental accruals included in other current liabilities									500	1,500
Estimated closure and post-closure costs									$ 900	$ 900
Number of landfills \| landfill									2	2
Estimated future payments for environmental obligations
2012									$ 493
2013									166
2014									166
2015									166
2016									109
Thereafter									1,077
Undiscounted total									2,177
Less amounts representing interest at 1.69%									225
Accrued environmental liabilities at the end of the year									$ 1,952
Interest rate (as a percent)									1.69%
Environmental civil penalty														$ 900
EHS \| CRRM
Estimated future payments for environmental obligations
Expected capital expenditures related to environmental, health and safety ("EHS") matters									$ 10,000
Renewable fuel as percentage of all fuel used as required by the EPA under the Renewable Fuel Standard									8.00%
Proposed renewable fuel as percentage of all fuel used in 2012 under the EPA's Renewable Fuel Standard									9.00%
Expense associated with the purchasing of Renewable Identification Numbers									$ 19,000
Extension period for installation of controls (in months) \| month				15
EHS \| CRRM and CRT
Estimated future payments for environmental obligations
Remaining amount expected to be spent for environmental remediation compliance, including capital expenditures							$ 49,000
Expected capital expenditures related to environmental, health and safety ("EHS") matters								$ 47,000
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) \| year				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) \| year				5

Fair Value Measurements (Details) - Recurring - USD ($) $ in Thousands	Dec. 31, 2011	Dec. 31, 2010
Level 1
Fair value measurements
Cash equivalents	$ 187,327	$ 70,052
Other current assets (marketable securities)	25	26
Total Assets	187,352	70,078
Level 2
Fair value measurements
Total Assets	81,882
Total Liabilities	(2,388)	(4,043)
Level 2 \| Other derivative agreements
Fair value measurements
Other current assets	63,051
Other long-term assets	18,831
Other current liabilities		(4,043)
Level 2 \| Interest rate swap
Fair value measurements
Other current liabilities	(905)
Other long-term liabilities	(1,483)
Total
Fair value measurements
Cash equivalents	187,237	70,052
Other current assets (marketable securities)	25	26
Total Assets	269,234	70,078
Total Liabilities	(2,388)	(4,043)
Total \| Other derivative agreements
Fair value measurements
Other current assets	63,051
Other long-term assets	18,831
Other current liabilities		$ (4,043)
Total \| Interest rate swap
Fair value measurements
Other current liabilities	(905)
Other long-term liabilities	$ (1,483)

Derivative Financial Instruments (Details) barrel in Millions	1 Months Ended		3 Months Ended								12 Months Ended
	Jun. 30, 2010 USD ($)	Oct. 31, 2009 USD ($)	Dec. 31, 2011 USD ($) agreement D barrel	Sep. 30, 2011 USD ($)	Jun. 30, 2011 USD ($) agreement	Mar. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)	Sep. 30, 2010 USD ($)	Jun. 30, 2010 USD ($)	Mar. 31, 2010 USD ($)	Dec. 31, 2011 USD ($) agreement D barrel	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)	Apr. 13, 2011 USD ($)
Derivative Financial Instruments
Unrealized gain (loss)											$ 85,262,000	$ 634,000	$ (37,791,000)
Total gain (loss) on derivatives, net			$ 103,179,000	$ (9,925,000)	$ 6,932,000	$ (22,106,000)	$ (9,320,000)	$ (1,014,000)	$ 7,339,000	$ 1,490,000	78,080,000	(1,505,000)	(65,286,000)
CRNF \| Term loan facility
Derivative Financial Instruments
Borrowing capacity on credit facility														$ 125,000,000
Swap agreements
Derivative Financial Instruments
Realized gain (loss)													(14,331,000)
Unrealized gain (loss)													(40,903,000)
Other derivative agreements
Derivative Financial Instruments
Realized gain (loss)											(7,182,000)	721,000	(6,646,000)
Unrealized gain (loss)											$ 85,262,000	(2,196,000)	(1,847,000)
Interest rate swap agreements
Derivative Financial Instruments
Realized gain (loss)												(2,860,000)	(6,518,000)
Unrealized gain (loss)												$ 2,830,000	$ 4,959,000
Designated as hedges \| Interest rate swap agreements \| CRNF
Derivative Financial Instruments
Number of 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)			4.69%								4.69%
Interest expense											$ 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
Not designated as hedges \| Interest rate swap agreements \| CRLLC
Derivative Financial Instruments
Aggregate notional amount	$ 110,000,000								$ 110,000,000	$ 180,000,000
Floating rate basis	Three months LIBOR
Fixed rate (as a percent)	4.195%								4.195%
Not designated as hedges \| Commodity derivative contracts entered into during September 2011
Derivative Financial Instruments
Number of barrels \| barrel			13								13
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			$ 18,800,000								$ 18,800,000
Terminated derivative contract \| Commodity derivative contracts entered into on June 16, 2005 \| CRLLC
Derivative Financial Instruments
Settlement paid as a result of early termination		$ 3,900,000

Related Party Transactions (Details)	1 Months Ended				3 Months Ended									12 Months Ended
Related Party Transactions (Details)	Apr. 30, 2011 USD ($)	Apr. 30, 2010 USD ($)	Mar. 31, 2010 USD ($)	Oct. 31, 2009 USD ($)	Dec. 31, 2011 USD ($)	Sep. 30, 2011 USD ($)	Jun. 30, 2011 USD ($)	Mar. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)	Sep. 30, 2010 USD ($)	Jun. 30, 2010 USD ($)	Mar. 31, 2010 USD ($)	Mar. 31, 2009 USD ($)	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)	Dec. 31, 2008 USD ($)	Jul. 31, 2007 USD ($)	Jun. 30, 2005 agreement
Related Party Transactions
Percentage of outstanding shares beneficially owned									40.00%						40.00%
Cash Flow Swaps
Gain (loss) on derivatives, net					$ 103,179,000	$ (9,925,000)	$ 6,932,000	$ (22,106,000)	$ (9,320,000)	$ (1,014,000)	$ 7,339,000	$ 1,490,000		$ 78,080,000	$ (1,505,000)	$ (65,286,000)
Cash and Cash Equivalents
Balance in the highly liquid money market account					388,328,000				200,049,000					388,328,000	200,049,000	36,905,000	$ 8,923,000
Interest income					(89,000)	$ 93,000	$ 211,000	$ 274,000	$ 603,000	$ 549,000	$ 643,000	$ 416,000		$ 489,000	$ 2,211,000	1,717,000
CRLLC \| Terminated derivative contract \| Commodity derivative contracts entered into on June 16, 2005
Cash Flow Swaps
Settlement paid as a result of early termination				$ 3,900,000
Goldman Sachs Funds and Kelso Funds
Related Party Transactions
Percentage of outstanding shares beneficially owned									40.00%						40.00%
Goldman Sachs Funds
Cash and Cash Equivalents
Maximum average maturities of highly liquid money market account (in days)														90 days
Balance in the highly liquid money market account					$ 0				$ 70,100,000					$ 0	$ 70,100,000
Interest income														26,000	29,000	74,000
Financing and Other
Expenses related to Registration Rights Agreement																500,000
J. Aron
J. Aron Deferrals
Amount deferred, excluding accrued interest, under deferral agreement																		$ 123,700,000
Amount repaid under deferral agreement													$ 62,400,000				$ 61,300,000
Principle and interest paid under deferral agreement													$ 500,000
Interest expense associated with deferral agreement																300,000
J. Aron \| Terminated derivative contract \| Commodity derivative contracts entered into on June 16, 2005
Cash Flow Swaps
Settlement paid as a result of early termination				3,900,000
Gain (loss) on derivatives, net														0	0	(55,300,000)
J. Aron \| Terminated derivative contract \| Interest Rate Swap June 30 2005
Cash Flow Swaps
Gain (loss) on derivatives, net														0	(16,000)	$ (800,000)
Interest Rate Swap
Number of Interest Rate Swap Agreements \| agreement																			3
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
Underwriter fees				900,000
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
Different subsidiary of GS \| CRNF \| First Priority Credit Facility
Financing and Other
Underwriter fees				$ 7,000

Business Segments (Details) $ in Thousands	3 Months Ended								12 Months Ended
Business Segments (Details) $ in Thousands	Dec. 31, 2011 USD ($)	Sep. 30, 2011 USD ($)	Jun. 30, 2011 USD ($)	Mar. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)	Sep. 30, 2010 USD ($)	Jun. 30, 2010 USD ($)	Mar. 31, 2010 USD ($)	Dec. 31, 2011 USD ($) Segment	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)
Business Segments
Number of reportable segments \| Segment									2
Business Segments
Net sales	$ 1,062,168	$ 1,351,964	$ 1,447,716	$ 1,167,265	$ 1,148,184	$ 1,031,174	$ 1,005,898	$ 894,512	$ 5,029,113	$ 4,079,768	$ 3,136,329
Cost of product sold (exclusive of depreciation and amortization)	857,277	1,026,040	1,123,375	936,822	983,726	889,850	891,652	802,890	3,943,514	3,568,118	2,547,695
Direct operating expenses (exclusive of depreciation and amortization)	124,796	74,615	66,207	68,434	64,216	52,534	62,479	60,562	334,052	239,791	226,657
Depreciation and amortization	24,242	22,025	22,043	22,011	22,005	21,943	21,553	21,260	90,321	86,761	84,873
Operating income	26,880	$ 212,190	$ 217,920	$ 109,606	34,787	$ 50,450	$ 19,421	$ (11,594)	566,596	93,064	208,186
Capital expenditures									91,224	32,409	48,773
Total assets	3,119,291				1,740,184				3,119,291	1,740,184	1,614,494
Goodwill	40,969				40,969				40,969	40,969	40,969
Petroleum
Business Segments
Intercompany sales									11,400	4,300	6,100
Intercompany cost of product sold (exclusive of depreciation and amortization)									13,200	(1,600)	(800)
Net sales									4,751,826	3,903,826	2,934,904
Cost of product sold (exclusive of depreciation and amortization)									3,926,632	3,538,017	2,514,293
Direct operating expenses (exclusive of depreciation and amortization)									247,665	153,112	142,204
Depreciation and amortization									69,852	66,391	64,424
Operating income									465,710	104,564	170,184
Capital expenditures									68,612	19,761	34,018
Total assets	2,322,148				1,049,361				2,322,148	1,049,361	1,082,707
Nitrogen Fertilizer
Business Segments
Intercompany sales									14,200	100	800
Intercompany cost of product sold (exclusive of depreciation and amortization)									10,700	4,000	7,900
Cost of product sold related to the transfer of excess hydrogen									1,000	1,800	1,600
Net sales									302,867	180,468	208,371
Cost of product sold (exclusive of depreciation and amortization)									42,511	34,328	42,158
Direct operating expenses (exclusive of depreciation and amortization)									86,491	86,679	84,453
Depreciation and amortization									18,869	18,463	18,685
Operating income									136,198	20,356	48,863
Capital expenditures									19,144	10,117	13,389
Total assets	659,309				452,165				659,309	452,165	702,929
Goodwill	40,969				40,969				40,969	40,969	40,969
Other
Business Segments
Direct operating expenses (exclusive of depreciation and amortization)									(104)
Depreciation and amortization									1,600	1,907	1,764
Operating income									(35,312)	(31,856)	(10,861)
Capital expenditures									3,468	2,531	1,366
Total assets	$ 137,834				$ 238,658				137,834	238,658	(171,142)
Intersegment elimination
Business Segments
Net sales									(25,580)	(4,526)	(6,946)
Cost of product sold (exclusive of depreciation and amortization)									$ (25,629)	$ (4,227)	$ (8,756)

Major Customers and Suppliers (Details) - supplier	12 Months Ended
Major Customers and Suppliers (Details) - supplier	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Sales \| Customer concentration \| Petroleum
Major Customers and Suppliers
Concentration risk (as a percent)	36.00%	35.00%	35.00%
Sales \| Customer concentration \| Petroleum \| Customer A
Major Customers and Suppliers
Concentration risk (as a percent)	15.00%	14.00%	14.00%
Sales \| Customer concentration \| Petroleum \| Customer B
Major Customers and Suppliers
Concentration risk (as a percent)	12.00%	11.00%	10.00%
Sales \| Customer concentration \| Petroleum \| Customer C
Major Customers and Suppliers
Concentration risk (as a percent)	9.00%	10.00%	11.00%
Sales \| Customer concentration \| Nitrogen Fertilizer
Major Customers and Suppliers
Concentration risk (as a percent)	29.00%	22.00%	24.00%
Sales \| Customer concentration \| Nitrogen Fertilizer \| Customer D
Major Customers and Suppliers
Concentration risk (as a percent)	17.00%	12.00%	15.00%
Sales \| Customer concentration \| Nitrogen Fertilizer \| Customer E
Major Customers and Suppliers
Concentration risk (as a percent)	12.00%	10.00%	9.00%
Total cost of products sold (exclusive of depreciation and amortization) \| Supplier concentration \| Petroleum
Major Customers and Suppliers
Number of major suppliers	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)	65.00%	64.00%	69.00%
Direct operating expenses (exclusive of depreciation and amortization) \| Supplier concentration \| Nitrogen Fertilizer
Major Customers and Suppliers
Number of major suppliers	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, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010	Sep. 30, 2010	Jun. 30, 2010	Mar. 31, 2010	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Selected Quarterly Financial Information (unaudited)
Net sales	$ 1,062,168	$ 1,351,964	$ 1,447,716	$ 1,167,265	$ 1,148,184	$ 1,031,174	$ 1,005,898	$ 894,512	$ 5,029,113	$ 4,079,768	$ 3,136,329
Operating costs and expenses:
Cost of product sold (exclusive of depreciation and amortization)	857,277	1,026,040	1,123,375	936,822	983,726	889,850	891,652	802,890	3,943,514	3,568,118	2,547,695
Direct operating expenses (exclusive of depreciation and amortization)	124,796	74,615	66,207	68,434	64,216	52,534	62,479	60,562	334,052	239,791	226,657
Insurance recovery - business interruption		(490)		(2,870)					(3,360)
Selling, general and administrative (exclusive of depreciation and amortization)	28,973	17,584	18,171	33,262	43,450	16,397	10,793	21,394	97,990	92,034	68,918
Depreciation and amortization	24,242	22,025	22,043	22,011	22,005	21,943	21,553	21,260	90,321	86,761	84,873
Total operating costs and expenses	1,035,288	1,139,774	1,229,796	1,057,659	1,113,397	980,724	986,477	906,106	4,462,517	3,986,704	2,928,143
Operating income	26,880	212,190	217,920	109,606	34,787	50,450	19,421	(11,594)	566,596	93,064	208,186
Other income (expense):
Interest expense and other financing costs	(14,657)	(13,757)	(14,205)	(13,190)	(13,717)	(13,863)	(12,766)	(9,922)	(55,809)	(50,268)	(44,237)
Interest income	(89)	93	211	274	603	549	643	416	489	2,211	1,717
Gain (loss) on derivatives, net	103,179	(9,925)	6,932	(22,106)	(9,320)	(1,014)	7,339	1,490	78,080	(1,505)	(65,286)
Loss on extinguishment of debt			(170)	(1,908)	(1,595)		(14,552)	(500)	(2,078)	(16,647)	(2,101)
Other income, net	124	243	246	231	517	17	642	42	844	1,218	310
Total other income (expense)	88,557	(23,346)	(6,986)	(36,699)	(23,512)	(14,311)	(18,694)	(8,474)	21,526	(64,991)	(109,597)
Income before income taxes	115,437	188,844	210,934	72,907	11,275	36,139	727	(20,068)	588,122	28,073	98,589
Income tax expense	37,103	68,603	76,738	27,119	8,981	12,932	(425)	(7,705)	209,563	13,783	29,235
Net income	78,334	120,241	134,196	45,788	$ 2,294	$ 23,207	$ 1,152	$ (12,363)	378,559	14,290	69,354
Less: Net income attributable to noncontrolling interest	12,476	10,976	9,331						32,783
Net income attributable to CVR Energy Stockholders	$ 65,858	$ 109,265	$ 124,865	$ 45,788					$ 345,776	$ 14,290	$ 69,354
Net earnings (loss) per share
Basic (in dollars per share)	$ 0.76	$ 1.26	$ 1.44	$ 0.53	$ 0.03	$ 0.27	$ 0.01	$ (0.14)	$ 4.00	$ 0.17	$ 0.80
Diluted (in dollars per share)	$ 0.75	$ 1.25	$ 1.42	$ 0.52	$ 0.03	$ 0.27	$ 0.01	$ (0.14)	$ 3.94	$ 0.16	$ 0.80
Weighted-average common shares outstanding
Basic (in shares)	86,852,800	86,549,846	86,422,881	86,413,781	86,352,627	86,343,102	86,336,125	86,329,237	86,493,735	86,340,342	86,248,205
Diluted (in shares)	87,746,843	87,743,600	87,789,351	87,783,857	87,121,094	87,013,575	86,506,590	86,329,237	87,766,573	86,789,179	86,342,433

Subsequent Events. (Details) $ / shares in Units, $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2012 $ / shares	Dec. 31, 2011 $ / shares	Jan. 26, 2012 USD ($) $ / shares
Dividend declared
Dividend
Cash dividend of common stock approved (in dollars per share)		$ 0.08
Dividend declared \| CVR GP, LLC
Distribution
Cash distribution declared (in dollars per share)			$ 0.588
Cash distribution declared \| $			$ 42.9
Shareholder proposal and tender offer
Shareholder Proposal and Tender Offer
Number of individuals to be nominated for election to Board Of Directors from funds affiliated with prospective buyer	9

Label	Element	Value
Insurance proceeds For flood	cvi_InsuranceProceedsForFlood	$ (11,800,000)