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Document and Entity Information - shares	3 Months Ended
Document and Entity Information - shares	Mar. 31, 2018	Apr. 24, 2018
Document and Entity Information
Entity Registrant Name	CVR ENERGY INC
Entity Central Index Key	0001376139
Document Type	10-Q
Document Period End Date	Mar. 31, 2018
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		86,831,050
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	Q1

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents (including $168.0 and $223.0, respectively, of consolidated variable interest entities (VIEs))	$ 420.0	$ 481.8
Accounts receivable of VIEs, net of allowance for doubtful accounts of $0.9 and $1.1, respectively	179.3	178.7
Inventories of VIEs	424.4	385.2
Prepaid expenses and other current assets (including $111.4 and $30.0, respectively, of VIEs)	114.3	33.7
Income tax receivable (including $0.0 and $0.0, respectively, of VIEs)	9.1	9.7
Due from parent	0.0	5.1
Total current assets	1,147.1	1,094.2
Property, plant and equipment, net of accumulated depreciation (including $2,514.3 and $2,548.3, respectively, of VIEs)	2,537.6	2,571.8
Intangible assets of VIEs, net	0.1	0.2
Goodwill of VIEs	41.0	41.0
Equity method investments in affiliates of VIEs	83.5	82.8
Other long-term assets (including $11.0 and $13.3, respectively, of VIEs)	14.0	16.7
Total assets	3,823.3	3,806.7
Current liabilities:
Note payable and capital lease obligations of VIEs	2.2	2.1
Accounts payable (including $340.6 and $329.0, respectively, of VIEs)	343.7	333.9
Personnel accruals (including $17.4 and $29.9, respectively, of VIEs)	27.7	55.9
Accrued taxes other than income taxes ($23.8 and $26.5, respectively)	23.9	26.5
Deferred revenue of VIEs	24.2	12.9
Due to parent	14.3	0.0
Other current liabilities (including $85.7 and $111.8, respectively, of VIEs)	86.3	112.4
Total current liabilities	522.3	543.7
Long-term liabilities:
Long-term debt and capital lease obligations of VIEs, net of current portion	1,164.8	1,164.4
Deferred income taxes (including $0.9 and $1.0, respectively, of VIEs)	386.7	385.9
Other long-term liabilities (including $2.9 and $3.7, respectively, of VIEs)	7.9	8.7
Total long-term liabilities	1,559.4	1,559.0
Commitments and contingencies
CVR stockholders' equity:
Common stock $0.01 par value per share, 350,000,000 shares authorized, 86,929,660 shares issued	0.9	0.9
Additional paid-in-capital	1,197.6	1,197.6
Retained deficit	(254.6)	(277.4)
Treasury stock, 98,610 shares at cost	(2.3)	(2.3)
Accumulated other comprehensive income, net of tax	0.0	0.0
Total CVR stockholders' equity	941.6	918.8
Noncontrolling interest	800.0	785.2
Total equity	1,741.6	1,704.0
Total liabilities and equity	$ 3,823.3	$ 3,806.7

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents, consolidated VIEs	$ 420.0	$ 481.8
Prepaid expenses and other current assets, VIEs	114.3	33.7
Income tax receivable, VIEs	9.1	9.7
Property, plant and equipment, net of accumulated depreciation, VIEs	2,537.6	2,571.8
Other long-term assets, VIEs	14.0	16.7
Current liabilities:
Accounts payable, VIEs	343.7	333.9
Personnel accruals, VIEs	27.7	55.9
Accrued taxes other than income taxes, VIEs	23.9	26.5
Other current liabilities, VIEs	86.3	112.4
Long-term liabilities:
Deferred income taxes, VIEs	386.7	385.9
Other long-term liabilities, VIEs	$ 7.9	$ 8.7
Equity:
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, authorized (in shares)	350,000,000	350,000,000
Common stock, issued (in shares)	86,929,660	86,929,660
Treasury stock (in shares)	98,610	98,610
Variable Interest Entities
Current assets:
Cash and cash equivalents, consolidated VIEs	$ 168.0	$ 223.0
Accounts receivable of VIEs, allowance for doubtful accounts	0.9	1.1
Prepaid expenses and other current assets, VIEs	111.4	30.0
Income tax receivable, VIEs	0.0	0.0
Property, plant and equipment, net of accumulated depreciation, VIEs	2,514.3	2,548.3
Other long-term assets, VIEs	11.0	13.3
Current liabilities:
Accounts payable, VIEs	340.6	329.0
Personnel accruals, VIEs	17.4	29.9
Accrued taxes other than income taxes, VIEs	23.8	26.5
Other current liabilities, VIEs	85.7	111.8
Long-term liabilities:
Deferred income taxes, VIEs	0.9	1.0
Other long-term liabilities, VIEs	$ 2.9	$ 3.7

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Income Statement [Abstract]
Net sales	$ 1,536.5	$ 1,507.1
Operating costs and expenses:
Cost of materials and other	1,238.3	1,221.2
Direct operating expenses (exclusive of depreciation and amortization as reflected below)	131.9	138.1
Depreciation and amortization	49.1	48.6
Cost of sales	1,419.3	1,407.9
Selling, general and administrative expenses (exclusive of depreciation and amortization as reflected below)	23.9	29.1
Depreciation and amortization	2.8	2.5
Total operating costs and expenses	1,446.0	1,439.5
Operating income	90.5	67.6
Other income (expense):
Interest expense and other financing costs	(27.1)	(27.0)
Interest income	0.2	0.2
Gain on derivatives, net	59.3	12.2
Other income, net	1.5	0.0
Total other income (expense)	33.9	(14.6)
Income before income tax expense	124.4	53.0
Income tax expense	20.8	14.8
Net income	103.6	38.2
Less: Net income attributable to noncontrolling interest	37.4	16.0
Net income attributable to CVR Energy stockholders	$ 66.2	$ 22.2
Earnings per share:
Basic and diluted earnings per share (in dollars per share)	$ 0.76	$ 0.26
Dividends declared per share (in dollars per share)	$ 0.5	$ 0.5
Weighted-average common shares outstanding:
Basic and diluted (in shares)	86.8	86.8

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($)	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Statement of Comprehensive Income [Abstract]
Net income	$ 103,600,000	$ 38,200,000
Other comprehensive income	0	0
Comprehensive income	103,600,000	38,200,000
Less: Comprehensive income attributable to noncontrolling interest	37,400,000	16,000,000
Comprehensive income attributable to CVR Energy stockholders	$ 66,200,000	$ 22,200,000

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY - 3 months ended Mar. 31, 2018 - USD ($) $ in Millions	Total	Total CVR Stockholders' Equity	$0.01 Par Value Common Stock	Additional Paid-In Capital	Retained Deficit	Treasury Stock	Noncontrolling Interest
Beginning balance (in shares) at Dec. 31, 2017			86,929,660
Beginning balance at Dec. 31, 2017	$ 1,704.0	$ 918.8	$ 0.9	$ 1,197.6	$ (277.4)	$ (2.3)	$ 785.2
Increase (Decrease) in Stockholders' Equity
Dividends paid to CVR Energy stockholders	(43.4)	(43.4)			(43.4)
Distributions from CVR Refining to public unitholders	(22.6)						(22.6)
Net income	103.6	66.2			66.2		37.4
Ending balance (in shares) at Mar. 31, 2018			86,929,660
Ending balance at Mar. 31, 2018	$ 1,741.6	$ 941.6	$ 0.9	$ 1,197.6	$ (254.6)	$ (2.3)	$ 800.0

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY (Parenthetical) - $ / shares	Mar. 31, 2018	Dec. 31, 2017
Statement of Stockholders' Equity [Abstract]
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Cash flows from operating activities:
Net income	$ 103.6	$ 38.2
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	51.9	51.1
Allowance for doubtful accounts	(0.2)	0.7
Amortization of deferred financing costs and original issue discount	1.1	1.2
Deferred income taxes expense	0.9	12.5
Loss on disposition of assets	0.1	0.5
Share-based compensation	1.5	3.3
Gain on derivatives, net	(59.3)	(12.2)
Current period settlements on derivative contracts	13.7	1.2
Income from equity method investments, net of distributions	(0.7)	0.0
Changes in assets and liabilities:
Accounts receivable	0.3	8.0
Inventories	(37.1)	(1.9)
Income tax receivable	0.5	0.6
Prepaid expenses and other current assets	(77.4)	30.1
Due to/from parent	19.4	1.9
Other long-term assets	1.2	0.3
Accounts payable	10.7	(10.8)
Deferred revenue	10.6	19.3
Other current liabilities	(15.4)	(6.5)
Other long-term liabilities	(0.9)	(0.3)
Net cash provided by operating activities	24.5	137.2
Cash flows from investing activities:
Capital expenditures	(20.0)	(24.2)
Proceeds from sale of assets	0.2	0.0
Investment in affiliates, net of return of investment	0.0	(1.4)
Net cash used in investing activities	(19.8)	(25.6)
Cash flows from financing activities:
Payment of capital lease obligations	(0.5)	(0.4)
Dividends to CVR Energy's stockholders	(43.4)	(43.4)
Distributions to CVR Partners' noncontrolling interest holders	(22.6)	0.0
Net cash used in financing activities	(66.5)	(43.8)
Net increase (decrease) in cash and cash equivalents	(61.8)	67.8
Cash and cash equivalents, beginning of period	481.8	735.8
Cash and cash equivalents, end of period	420.0	803.6
Supplemental disclosures:
Cash paid (refunded) for income taxes, net of refunds	0.0	(0.2)
Cash paid for interest, net of capitalized interest of $0.5 and $0.3 in 2018 and 2017, respectively	3.0	2.8
Non-cash investing and financing activities:
Construction in progress additions included in accounts payable	7.0	11.5
Change in accounts payable related to construction in progress additions	(1.0)	(4.8)
Landlord incentives for leasehold improvements	$ 0.0	$ 1.2

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Statement of Cash Flows [Abstract]
Capitalized interest	$ 0.5	$ 0.3

Organization and Basis of Presentation	3 Months Ended
Organization and Basis of Presentation	Mar. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Basis of Presentation	(1) Organization and Basis of Presentation Organization The "Company," "CVR Energy" or "CVR" may be used to refer to CVR Energy, Inc. and, unless the context otherwise requires, its subsidiaries. CVR is a diversified holding company primarily engaged in the petroleum refining and nitrogen fertilizer manufacturing industries through its holdings in CVR Refining, LP ("CVR Refining" or the "Refining Partnership") and CVR Partners, LP ("CVR Partners" or the "Nitrogen Fertilizer Partnership"). The Refining Partnership is an independent petroleum refiner and marketer of high value transportation fuels. The Nitrogen Fertilizer Partnership produces and markets nitrogen fertilizers in the form of UAN and ammonia. The Company's operations include two business segments: the petroleum segment and the nitrogen fertilizer segment. CVR's common stock is listed on the New York Stock Exchange ("NYSE") under the symbol "CVI." As of March 31, 2018, Icahn Enterprises L.P. ("IEP") and its affiliates owned approximately 82% of the Company's outstanding shares. CVR Partners, LP On April 13, 2011, the Nitrogen Fertilizer Partnership completed the initial public offering (the "Nitrogen Fertilizer Partnership IPO") of its common units representing limited partnership interests. The common units, which are listed on the NYSE, began trading on April 8, 2011 under the symbol "UAN." On April 1, 2016, the Nitrogen Fertilizer Partnership completed the merger (the "East Dubuque Merger") with CVR Nitrogen, LP ("CVR Nitrogen") (formerly known as East Dubuque Nitrogen Partners, L.P. and also formerly known as Rentech Nitrogen Partners L.P.) and CVR Nitrogen GP, LLC ("CVR Nitrogen GP") (formerly known as East Dubuque Nitrogen GP, LLC and also formerly known as Rentech Nitrogen GP, LLC), whereby the Nitrogen Fertilizer Partnership acquired a nitrogen fertilizer manufacturing facility located in East Dubuque, Illinois (the "East Dubuque Facility"). As a result of the Nitrogen Fertilizer Partnership's acquisition of CVR Nitrogen and issuance of the unit consideration, the noncontrolling interest related to the Nitrogen Fertilizer Partnership reflected in our Consolidated Financial Statements on April 1, 2016 and from such date and as of March 31, 2018 was approximately 66%. In addition, CRLLC owns 100% of the Nitrogen Fertilizer Partnership's general partner, CVR GP, LLC, which only holds a non-economic general partner interest. The noncontrolling interest reflected on the Condensed Consolidated Balance Sheets of CVR is impacted by the net income of, and distributions from, the Nitrogen Fertilizer Partnership. CVR Refining, LP On January 23, 2013, the Refining Partnership completed the initial public offering (the "Refining Partnership IPO") of its common units representing limited partner interests. The common units, which are listed on the NYSE, began trading on January 17, 2013 under the symbol "CVRR." As of March 31, 2018, public security holders held approximately 34% of the Refining Partnership's outstanding common units (including units owned by affiliates of IEP, representing approximately 3.9% of the Refining Partnership's outstanding common units), and CVR Refining Holdings, LLC (“CVR Refining Holdings”) held approximately 66% of the Refining Partnership's outstanding common units. In addition, CVR Refining Holdings owns 100% of the Refining Partnership’s general partner, CVR Refining GP, LLC, which holds a non-economic general partner interest. The noncontrolling interest reflected on the Condensed Consolidated Balance Sheets of CVR is impacted by the net income of, and distributions from, the Refining Partnership. Basis of Presentation The accompanying condensed consolidated financial statements were prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") and in accordance with the rules and regulations of the Securities and Exchange Commission ("SEC"). The condensed consolidated financial statements include the accounts of CVR and its direct and indirect subsidiaries including the Nitrogen Fertilizer Partnership, the Refining Partnership and their respective subsidiaries, as discussed further below. The ownership interests of noncontrolling investors in CVR's subsidiaries are recorded as a noncontrolling interest included as a separate component of equity for all periods presented. All intercompany account balances and transactions have been eliminated in consolidation. Certain information and footnotes required for complete financial statements under GAAP have been condensed or omitted pursuant to SEC rules and regulations. These condensed consolidated financial statements should be read in conjunction with the December 31, 2017 audited consolidated financial statements and notes thereto included in CVR's Annual Report on Form 10-K for the year ended December 31, 2017, which was filed with the SEC on February 26, 2018 (the "2017 Form 10-K"). According to the Financial Accounting Standards Board ("FASB") Accounting Standards Codification ("ASC") Topic 810, Consolidations, the primary beneficiary of a variable interest entity's ("VIE") activities is required 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; limited partnerships and other similar entities are considered a VIE unless the limited partners hold substantive kick-out rights or participating rights; and an ongoing analysis is required to determine whether the variable interest gives rise to a controlling financial interest in the VIE, among other things. Management has determined that the Refining Partnership and the Nitrogen Fertilizer Partnership are VIEs because the limited partners of CVR Refining and CVR Partners lack both substantive kick-out rights and participating rights. Based upon the general partner’s roles and rights as afforded by the partnership agreements and its exposure to losses and benefits of each of the partnerships through its significant limited partner interests, intercompany credit facilities, and services agreements, CVR determined that it is the primary beneficiary of both the Refining Partnership and the Nitrogen Fertilizer Partnership. Based upon that determination, CVR consolidates both the Refining and Nitrogen Fertilizer Partnerships in its consolidated financial statements. In the opinion of the Company's management, the accompanying condensed consolidated financial statements reflect all adjustments (consisting only of normal recurring adjustments) that are necessary to fairly present the financial position of the Company as of March 31, 2018 and December 31, 2017, the results of operations and comprehensive income for the three month periods ended March 31, 2018 and 2017, changes in equity for the three month period ended March 31, 2018 and cash flows of the Company for the three month periods ended March 31, 2018 and 2017. The preparation of the condensed consolidated financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results could differ materially from those estimates. Results of operations and cash flows for the interim periods presented are not necessarily indicative of the results that will be realized for the year ending December 31, 2018 or any other interim or annual period.

Recent Accounting Pronouncements

3 Months Ended

Mar. 31, 2018

Accounting Policies [Abstract]

Recent Accounting Pronouncements

(2) Recent Accounting Pronouncements

Adoption of New Accounting Standard

On January 1, 2018, the Company adopted FASB ASC Topic 606, "Revenue from Contracts with Customers" (“ASC 606”) using the modified retrospective method applied to contracts which were not completed as of January 1, 2018. The standard was applied prospectively and the comparative information for 2017 has not been restated and continues to be reported under the accounting standards in effect for the period. The Company did not identify any material differences in its existing revenue recognition methods that require modification under the new standard and, as such, a cumulative effect adjustment of applying the standard using the modified retrospective method was not recorded.

Impact on Financial Statements

The Company identified presentation changes associated with contracts requiring customer prepayment prior to delivery and the need to gross up certain fees collected from customers. Prior to adoption of ASC 606, deferred revenue was recorded by the Nitrogen Fertilizer Partnership upon customer prepayment. Under the new revenue standard, a receivable and associated deferred revenue is recorded at the point in time in which a prepaid contract is legally enforceable and the associated right to consideration is unconditional. The adoption of ASC 606 resulted in a $21.4 million increase to deferred revenue and accounts receivable as of January 1, 2018. After the effect of adoption of the new revenue standard, deferred revenue and accounts receivable of the Nitrogen Fertilizer Partnership were $34.3 million and $31.2 million, respectively, as of January 1, 2018. Additionally, fees collected from certain customers were previously recorded as a reduction to cost of materials and other. The particular fee, the Oil Spill Liability Tax, relates to taxes imposed on refineries as part of the crude oil procurement process, is charged to certain of the Refining Partnership’s customers on product sales and is required under the new standard to be included in the transaction price.

The following tables display the effect of the change to the Condensed Consolidated Balance Sheet and the Condensed Consolidated Statement of Operations as of and for the three months ended March 31, 2018 for the adoption of ASC 606. The Company’s Condensed Consolidated Statement of Cash Flows was not impacted due to the adoption of ASC 606 for the three months ended March 31, 2018.



	March 31, 2018
Balance Sheet	As Reported		Balances Without Adoption of ASC 606		Effect of Change
			(in millions)
Assets
Accounts Receivable	$	179.3	$	178.6	$	0.7

Liabilities
Deferred Revenue	24.2		23.5		0.7



	Three Months Ended March 31, 2018
Statement of Operations	As Reported		Balances Without Adoption of ASC 606		Effect of Change
			(in millions)
Revenues
Net Sales	$	1,536.5	$	1,536.3	$	0.2

Operating Costs and Expenses
Cost of materials and other	1,238.3		1,238.1		0.2

New Accounting Standards Issued But Not Yet Implemented

In February 2016, the FASB issued ASU No. 2016-02, “Leases” (“ASU 2016-02”), creating a new topic, FASB ASC Topic 842, "Leases," which supersedes lease requirements in FASB ASC Topic 840, "Leases." The new standard revises accounting for operating leases by a lessee, among other changes, and requires a lessee to recognize a liability related to future lease payments and an asset representing its right to use the underlying asset for the lease term in the balance sheet. Quantitative and qualitative disclosures, including disclosures regarding significant judgments made by management, will be required. The standard is effective for the first interim and annual periods beginning after December 15, 2018, with early adoption permitted. At adoption, ASU 2016-02 will be applied using the modified retrospective application method and allows for certain practical expedients. The Company expects its assessment and implementation plan to be ongoing during 2018 and is currently unable to reasonably estimate the impact of adopting the new lease standard on its consolidated financial statements and related disclosures. The Company currently believes the most significant change will relate to the recognition of right-of-use assets and leases liability on the balance sheet for existing long-term operating leases, the majority of which are railcar leases, and the potential recognition for agreements that do not currently meet the definition of a lease under ASC Topic 840, which will require an evaluation of the Company's unconditional purchase obligations primarily related to petroleum transportation and storage service agreements. The impact of the new standard on right-of-use assets, leases liability and related disclosures resulting from adoption of the new standard could be material.

Revenue

3 Months Ended

Mar. 31, 2018

Revenue from Contract with Customer [Abstract]

Revenue

(3) Revenue

The following table presents the Company’s revenue disaggregated by major product. The table includes a reconciliation of the disaggregated revenue with the reportable segments.



	Three Months Ended March 31, 2018
	Petroleum		Nitrogen Fertilizer		Other / Eliminations			Consolidated
	(in millions)
Major Product
Gasoline	$	711.7	$	—	$	—		$	711.7
Distillates	652.2		—		—			652.2
Ammonia	—		11.6		—			11.6
UAN	—		52.8		—			52.8
Urea products	—		4.9		—			4.9
Freight revenue	5.5		8.7		—			14.2
Other (a)	87.3		1.9		(1.6		)	87.6
Revenue from product sales	1,456.7		79.9		(1.6		)	1,535.0

Other revenue (b)	1.5		—		—			1.5
Total revenue	$	1,458.2	$	79.9	$	(1.6	)	$	1,536.5

(a) Other product sales primarily include crude oil, feedstocks and asphalt sales attributable to the petroleum segment and nitric acid and carbon dioxide sales attributable to the nitrogen fertilizer segment.
(b) Other revenue consists primarily of Cushing, OK storage tank lease revenue.

Petroleum

The petroleum segment’s revenue from product sales is recorded upon delivery of the products to customers, which is the point at which title is transferred and the customer has assumed the risk of loss. This generally takes place as product passes into the pipeline, as a product transfer order occurs within a pipeline system, or as product enters equipment or locations supplied or designated by the customer. The petroleum segment has elected to apply the sales tax practical expedient, whereby qualifying excise and other taxes collected from customers and remitted to governmental authorities are not included in reported revenues.

Many of the petroleum segment’s contracts have index-based pricing which is considered variable consideration that should be estimated in determining the transaction price. The petroleum segment determined that it does not need to estimate the variable consideration because the uncertainty related to the consideration is resolved on the pricing date or the date when the product is delivered.

The petroleum segment may incur broker commissions or transportation costs prior to product transfer on some of its sales. The petroleum segment has elected to apply the practical expedient allowing it to expense the broker costs since the contract durations are less than a year in length. Transportation costs are accounted for as fulfillment costs and are expensed as incurred since they do not meet the requirement for capitalization.

The petroleum segment’s contracts with its customers state the terms of the sale, including the description, quantity, and price of each product sold. Depending on the product sold, payment from customers is generally due in full within 2 to 32 days of product delivery or invoice date. The petroleum segment’s contracts with customers commonly include a provision which states that the Company will accept customer returns of off-spec product, refund the customer (or provide on-spec product), and pay for damages to any customer equipment which resulted from the off-spec product. Typically, if the customer is not satisfied with the product, the price is adjusted downward instead of the product being returned or exchanged. The petroleum segment has determined that product returns or refunds are very rare and will account for them as they occur. The petroleum segment generally provides no warranty other than the implicit promise that goods delivered are free of liens and encumbrances and meet the agreed upon specification.

Freight revenue recognized by the petroleum segment is primarily tariff and line loss charges rebilled to customers to reimburse the petroleum segment for expenses incurred from a pipeline operator. An offsetting expense is included in cost of materials and other.

Nitrogen Fertilizer

The nitrogen fertilizer segment sells its products on a wholesale basis under a contract or by purchase order. The nitrogen fertilizer segment's contracts with customers, including purchase orders, generally contain fixed pricing and most have terms of less than one year. The nitrogen fertilizer segment recognizes revenue at the point in time at which the customer obtains control of the product, which is generally upon delivery and acceptance by the customer. The customer acceptance point is stated in the contract and may be at one of the nitrogen fertilizer segment’s manufacturing facilities, at one of the nitrogen fertilizer segment’s off-site loading facilities, or at the customer's designated facility. Freight revenue recognized by the nitrogen fertilizer segment represents the pass-through finished goods delivery costs incurred prior to customer acceptance and is reimbursed by customers. An offsetting expense is included in cost of materials and other. Qualifying taxes collected from customers and remitted to governmental authorities are not included in reported revenues.

Depending on the product sold and the type of contract, payments from customers are generally either due prior to delivery or within 15 to 30 days of product delivery.

The nitrogen fertilizer segment generally provides no warranty other than the implicit promise that goods delivered are free of liens and encumbrances and meet the agreed upon specifications. Product returns are rare, and as such, the nitrogen fertilizer segment does not record a specific warranty reserve or consider activities related to such warranty, if any, to be a separate performance obligation.

The nitrogen fertilizer segment has an immaterial amount of variable consideration for contracts with an original duration of less than a year. A small portion of the nitrogen fertilizer partnership's revenue includes contracts extending beyond one year, some of which contain variable pricing in which the majority of the variability is attributed to the market-based pricing. The nitrogen fertilizer segment's contracts do not contain a significant financing component.

The nitrogen fertilizer segment has certain fee-based revenue, included in other revenue in the table above, that is recognized based on the net amount of the proceeds received, consistent with prior accounting practice.

Transaction price allocated to remaining performance obligations

As of March 31, 2018, the Nitrogen Fertilizer Partnership had approximately $13.3 million of remaining performance obligations for contracts with an original expected duration of more than one year. The Nitrogen Fertilizer Partnership expects to recognize approximately 64% of these performance obligations as revenue by the end of 2019, an additional 22% by 2020 and the remaining balance thereafter. The Nitrogen Fertilizer Partnership has elected to not disclose the amount of transaction price allocated to remaining performance obligations for contracts with an original expected duration of less than one year. The Nitrogen Fertilizer Partnership has elected to not disclose variable consideration allocated to wholly unsatisfied performance obligations that are based on market prices that have not yet been determined.

Contract balances

The Nitrogen Fertilizer Partnership’s deferred revenue is a contract liability that primarily relates to fertilizer sales contracts requiring customer prepayment prior to product delivery to guarantee a price and supply of nitrogen fertilizer. Deferred revenue is recorded at the point in time in which a prepaid contract is legally enforceable and the associated right to consideration is unconditional prior to transferring product to the customer. An associated receivable is recorded for uncollected prepaid contract amounts. Contracts requiring prepayment are generally short-term in nature and, as discussed above, revenue is recognized at the point in time in which the customer obtains control of the product.

A summary of the deferred revenue activity during the three months ended March 31, 2018 is presented below:



	Three Months Ended March 31, 2018
	(in millions)
Balance at January 1, 2018	$	34.2
Add:
New prepay contracts entered into during the period	3.4
Less:
Revenue recognized that was included in the contract liability balance at the beginning of the period	11.6
Revenue recognized related to contracts entered into during the period	1.7
Other changes	0.1
Balance at March 31, 2018	$	24.2

Share-Based Compensation

3 Months Ended

Mar. 31, 2018

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Share-Based Compensation

(4) Share-Based Compensation

Long-Term Incentive Plan – CVR Energy

CVR has a Long-Term Incentive Plan ("LTIP") that permits the grant of options, stock appreciation rights ("SARs"), restricted shares, restricted stock units, dividend equivalent rights, share awards and performance awards (including performance share units, performance units and performance-based restricted stock). As of March 31, 2018, only performance units under the LTIP remain outstanding. Individuals who are eligible to receive awards and grants under the LTIP include the Company's employees, officers, consultants, advisors and directors. The LTIP 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.

Performance Unit Awards

In December 2016, the Company entered into a performance unit award agreement (the "2016 Performance Unit Award Agreement") with Jack Lipinski, the Company's then Chief Executive Officer and President. Compensation cost for the 2016 Performance Unit Award Agreement of $1.8 million was recognized over the performance cycle from January 1, 2017 to December 31, 2017. As of December 31, 2017, the Company had an outstanding liability of $1.8 million related to the 2016 Performance Unit Award Agreement. During the three months ended March 31, 2018, $1.8 million was paid by the Company related to the 2016 Performance Unit Award Agreement.

In November 2017, the Company entered into a performance unit agreement (the "2017 Performance Unit Agreement") with David Lamp, the Company's current Chief Executive Officer and President. Compensation cost for the 2017 Performance Unit Agreement will be recognized over the performance cycle from January 1, 2018 to December 31, 2018. The performance unit award of 1,500 performance units under the 2017 Performance Unit Agreement represents the right to receive, upon vesting, a cash payment equal to $1,000 multiplied by the applicable performance factor. The performance factor is determined based on the level of attainment of the applicable performance objective, and both the performance factor and performance objective(s) will be determined by CVR Energy's compensation committee. The amount paid pursuant to the award, if any, will be paid following the end of the performance cycle for the award, but no later than March 6, 2019. Total compensation expense for the three months ended March 31, 2018 was approximately $0.4 million. As of March 31, 2018, the Company had a liability of $0.4 million for the performance unit award, which is recorded in personnel accruals on the Condensed Consolidated Balance Sheets.

In November 2017, the Company entered into a performance unit award agreement (the "2017 Performance Unit Award Agreement") with Mr. Lamp. The performance unit award represents the right to receive upon vesting, a cash payment equal to $10.0 million if the average closing price of CVR Energy's common stock over the 30-trading day period from January 4, 2022 to February 15, 2022 is equal to or greater than $60 per share. At March 31, 2018, there was approximately $9.4 million of total unrecognized compensation cost related to the 2017 Performance Unit Award Agreement to be recognized over a period of 3.8 years. Total compensation expense for the three months ended March 31, 2018 was approximately $0.6 million. As of March 31, 2018, the Company had a liability of $0.6 million for the performance unit award, which is recorded in personnel accruals on the Condensed Consolidated Balance Sheets.

Long-Term Incentive Plan – CVR Partners

CVR Partners has a long-term incentive plan ("CVR Partners LTIP") that provides for the grant of options, unit appreciation rights, distribution equivalent rights, restricted units, phantom units and other unit-based awards, each in respect of common units. Individuals eligible to receive awards pursuant to the CVR Partners LTIP include (i) employees of the Nitrogen Fertilizer Partnership and its subsidiaries, (ii) employees of its general partner, (iii) members of its board of directors of the general partner, and (iv) certain employees, consultants and directors of CVR Energy who perform services for the benefit of the Nitrogen Fertilizer Partnership.

Through the CVR Partners LTIP, phantom and common units have been awarded to employees of both CVR Partners and its general partner. Phantom unit awards made to employees of its general partner are considered non-employee equity based-awards. Awards to employees of CVR Partners and employees of the general partner vest over a three-year period. The maximum number of common units issuable under the CVR Partners LTIP is 5,000,000. As of March 31, 2018, there were 4,820,215 common units available for issuance under the CVR Partners LTIP. As all phantom unit awards discussed below are cash settled awards, they do not reduce the number of common units available for issuance.

Each phantom unit and distribution equivalent right represents the right to receive, upon vesting, a cash payment equal to (i) the average fair market value of one unit of the Nitrogen Fertilizer Partnership's common units in accordance with the award agreement, plus (ii) the per unit cash value of all distributions declared and paid by the Nitrogen Fertilizer Partnership from the grant date to and including the vesting date. The awards, which are liability-classified, will be remeasured at each subsequent reporting date until they vest. The phantom unit awards are generally graded-vesting awards, which are expected to vest over three years with one-third of each award vesting each year. Compensation expense is recognized on a straight-line basis over the vesting period of the respective tranche of the award.

A summary of the phantom unit activity and changes under the CVR Partners LTIP during the three months ended March 31, 2018 is presented below:



	Phantom Units		Weighted-Average Grant-Date Fair Value
Non-vested at December 31, 2017	1,188,206		$	4.35
Granted	18,262		3.29
Vested	—		—
Forfeited	(23,320	)	4.26
Non-vested at March 31, 2018	1,183,148		$	4.34

As of March 31, 2018, unrecognized compensation expense associated with the unvested phantom units was approximately $2.4 million and is expected to be recognized over a weighted-average period of 1.5 years. Compensation expense recorded for the three months ended March 31, 2018 and 2017 related to the awards under the CVR Partners LTIP was approximately $0.4 million and $0.3 million, respectively.

As of March 31, 2018 and December 31, 2017, CVR Partners had liabilities of $1.1 million and $0.7 million, respectively, for cash settled non-vested phantom unit awards and associated distribution equivalent rights, which are recorded in personnel accruals on the Condensed Consolidated Balance Sheets.

Long-Term Incentive Plan – CVR Refining

CVR Refining has a long-term incentive plan ("CVR Refining LTIP") that provides for the grant of options, unit appreciation rights, restricted units, phantom units, unit awards, substitute awards, other-unit based awards, cash awards, performance awards, and distribution equivalent rights, each in respect of common units. The maximum number of common units issuable under the CVR Refining LTIP is 11,070,000. Individuals who are eligible to receive awards under the CVR Refining, LP Long-Term Incentive Plan (the "CVR Refining LTIP") include (i) employees of the Refining Partnership and its subsidiaries, (ii) employees of the general partner, (iii) members of the board of directors of the general partner and (iv) certain employees, consultants and directors of Coffeyville Resources, LLC ("CRLLC") and CVR Energy who perform services for the benefit of the Refining Partnership.

Awards of phantom units and distribution equivalent rights have been granted to employees of the Refining Partnership and its subsidiaries, its general partner and certain employees of CRLLC and CVR Energy who perform services solely for the benefit of the Refining Partnership. The awards are generally graded-vesting awards, which are expected to vest over three years with one-third of each award vesting each year. Compensation expense is recognized on a straight-line basis over the vesting period of the respective tranche of the award. Each phantom unit and distribution equivalent right represents the right to receive, upon vesting, a cash payment equal to (i) the average fair market value of one unit of the Refining Partnership's common units in accordance with the award agreement, plus (ii) the per unit cash value of all distributions declared and paid by the Refining Partnership from the grant date to and including the vesting date. The awards, which are liability-classified, will be remeasured at each subsequent reporting date until they vest.

A summary of phantom unit activity and changes under the CVR Refining LTIP during the three months ended March 31, 2018 is presented below:



	Phantom Units		Weighted-Average Grant-Date Fair Value
Non-vested at December 31, 2017	986,480		$	12.03
Granted	6,658		15.02
Vested	—		—
Forfeited	(7,835	)	12.37
Non-vested at March 31, 2018	985,303		$	12.05

As of March 31, 2018, there was approximately $8.7 million of total unrecognized compensation cost related to the awards under the CVR Refining LTIP to be recognized over a weighted-average period of 1.4 years. Total compensation expense recorded for the three months ended March 31, 2018 and 2017 related to the awards under the CVR Refining LTIP was approximately $0.8 million and $1.0 million, respectively.

As of March 31, 2018 and December 31, 2017, the Refining Partnership had liabilities of approximately $4.6 million and $3.7 million, respectively, for non-vested phantom unit awards and associated distribution equivalent rights, which are recorded in personnel accruals on the Condensed Consolidated Balance Sheets.

Incentive Unit Awards

The Company granted awards of incentive units and distribution equivalent rights to certain employees of CRLLC, CVR Energy and CVR GP, LLC. The awards are generally graded-vesting awards, which are expected to vest over three years with one-third of each award vesting each year. Compensation expense is recognized on a straight-line basis over the vesting period of the respective tranche of the award. Each incentive unit and distribution equivalent right represents the right to receive, upon vesting, a cash payment equal to (i) the average fair market value of one unit of the Refining Partnership's common units in accordance with the award agreement, plus (ii) the per unit cash value of all distributions declared and paid by the Refining Partnership from the grant date to and including the vesting date. The awards, which are liability-classified, will be remeasured at each subsequent reporting date until they vest.

A summary of incentive unit activity and changes during the three months ended March 31, 2018 is presented below:



	Incentive Units		Weighted-Average Grant-Date Fair Value
Non-vested at December 31, 2017	779,261		$	12.14
Granted	—		—
Vested	(1,445	)	13.65
Forfeited	(38,569	)	11.63
Non-vested at March 31, 2018	739,247		$	12.18

As of March 31, 2018, there was approximately $4.0 million of total unrecognized compensation cost related to incentive unit awards to be recognized over a weighted-average period of approximately 1.4 years. Total compensation expense (benefit) for the three months ended March 31, 2018 and 2017 related to the awards was approximately $(0.7) million and $1.2 million, respectively.

As of March 31, 2018 and December 31, 2017, the Company had liabilities of approximately $2.5 million and $3.3 million, respectively, for non-vested incentive units and associated distribution equivalent rights, which are recorded in personnel accruals on the Condensed Consolidated Balance Sheets.

Inventories

3 Months Ended

Mar. 31, 2018

Inventory Disclosure [Abstract]

Inventories

(5) Inventories

Inventories consisted of the following:



	March 31, 2018		December 31, 2017
	(in millions)
Finished goods	$	177.5	$	172.0
Raw materials and precious metals	133.6		113.8
In-process inventories	36.3		22.4
Parts and supplies	77.0		77.0
Total Inventories	$	424.4	$	385.2

Property, Plant and Equipment

3 Months Ended

Mar. 31, 2018

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

(6) Property, Plant and Equipment

Property, plant and equipment consisted of the following:



	March 31, 2018		December 31, 2017
	(in millions)
Land and improvements	$	47.4	$	47.4
Buildings	83.9		83.3
Machinery and equipment	3,741.4		3,733.8
Automotive equipment	24.8		24.7
Furniture and fixtures	33.0		32.4
Leasehold improvements	4.6		4.6
Aircraft	3.6		3.6
Railcars	16.8		16.8
Construction in progress	64.7		56.2
	4,020.2		4,002.8
Less: Accumulated depreciation	1,482.6		1,431.0
Total property, plant and equipment, net	$	2,537.6	$	2,571.8

Capitalized interest recognized as a reduction in interest expense for the three months ended March 31, 2018 and 2017 totaled approximately $0.5 million and $0.3 million, respectively. Land, buildings and equipment that are under a capital lease obligation had an original carrying value of approximately $24.8 million at both March 31, 2018 and December 31, 2017. Amortization of assets held under capital leases is included in depreciation expense.

Equity Method Investment	3 Months Ended
Equity Method Investment	Mar. 31, 2018
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investment	(7) Equity Method Investments VPP Joint Venture On September 19, 2016, Coffeyville Resources Pipeline, LLC ("CRPLLC"), an indirect wholly-owned subsidiary of the Refining Partnership, entered into an agreement with Velocity Central Oklahoma Pipeline LLC ("Velocity") related to their joint ownership of Velocity Pipeline Partners, LLC ("VPP"), which is a pipeline company that operates a 12-inch crude oil pipeline with a capacity of 65,000 barrels per day and an estimated length of 25 miles with a connection to the Refining Partnership's Wynnewood refinery and a trucking terminal at Lowrance, Oklahoma. CRPLLC holds a 40% interest in VPP. Velocity holds a 60% interest in VPP and serves as the day-to-day operator of VPP. As of both March 31, 2018 and December 31, 2017, the carrying value of CRPLLC's investment in VPP was $6.1 million, which is recorded in equity method investments in affiliates on the Condensed Consolidated Balance Sheets. Contribution by CRPLLC to VPP during the pipeline construction totaled $7.0 million, of which $1.4 million was contributed during 2017. The pipeline commenced operations in April 2017 following completion of construction. Equity income from VPP for the three months ended March 31, 2018 was $0.4 million, which is recorded in other income, net on the Condensed Consolidated Statements of Operations. For the three months ended March 31, 2018, the Refining Partnership received cash distributions of $0.4 million from VPP. Coffeyville Resources Refining & Marketing, LLC ("CRRM") is party to a transportation agreement with VPP for an initial term of 20 years under which VPP provides CRRM with crude oil transportation services for crude oil shipped within a defined geographic area, and CRRM entered into a terminalling services agreement with Velocity under which it receives access to Velocity's terminal in Lowrance, Oklahoma to unload and pump crude oil into VPP's pipeline for an initial term of 20 years. For the three months ended March 31, 2018, CRRM incurred costs of $1.5 million under the transportation agreement with VPP. CRRM's crude shipments on the pipeline for the three months ended March 31, 2018 averaged approximately 41,000 bpd. As of March 31, 2018 and December 31, 2017, the Condensed Consolidated Balance Sheets included a liability of $0.5 million and $0.3 million, respectively, to VPP. Midway Joint Venture On October 31, 2017, subsidiaries of CVR Refining and Plains All American Pipeline, L.P. ("Plains") formed a 50/50 joint venture, Midway Pipeline LLC ("Midway"), which acquired the approximately 100-mile, 16-inch Cushing to Broome pipeline system from Plains. The Cushing to Broome pipeline system connects CVR Refining's Coffeyville, Kansas refinery to the Cushing, Oklahoma oil hub. Midway has a contract with Plains pursuant to which Plains will continue its role as operator of the pipeline. In November 2017, CVR Refining contributed $76.0 million to Midway. During the three months ended March 31, 2018, CVR Refining recognized equity income from Midway of $1.1 million, which is recorded in other income, net on the Condensed Consolidated Statements of Operations. For the three months ended March 31, 2018, the Refining Partnership received a cash distribution of $0.5 million from Midway. As of March 31, 2018 and December 31, 2017, the carrying value of CVR Refining's investment in Midway was $77.3 million and $76.7 million, respectively, which is recorded in equity method investments in affiliates on the Condensed Consolidated Balance Sheets. For the three months ended March 31, 2018, CVR Refining incurred costs of $3.1 million with Midway for crude oil transportation services. Crude shipments on the pipeline for the three months ended March 31, 2018 averaged approximately 73,000 barrels per day.

Income Taxes	3 Months Ended
Income Taxes	Mar. 31, 2018
Income Tax Disclosure [Abstract]
Income Taxes	(8) Income Taxes CVR is a member of the consolidated federal tax group of American Entertainment Properties Corporation ("AEPC"), an affiliate of IEP, and is party to a tax allocation agreement with AEPC (the "Tax Allocation Agreement"). The Tax Allocation Agreement provides that AEPC will pay all consolidated federal income taxes on behalf of the consolidated tax group. CVR is required to make payments to AEPC in an amount equal to the tax liability, if any, that it would have paid if it were to file as a consolidated group separate and apart from AEPC. As of March 31, 2018, the Company's Condensed Consolidated Balance Sheet reflected a payable of $14.3 million for federal income taxes due to AEPC. During the three months ended March 31, 2018 and 2017, no payments were made to AEPC under the Tax Allocation Agreement. The Company recognizes liabilities, interest and penalties for potential tax issues based on its estimate of whether, and the extent to which, additional taxes may be due as determined under FASB ASC Topic 740 — Income Taxes. As of March 31, 2018, the Company had unrecognized tax benefits of approximately $28.7 million, of which $22.7 million, if recognized, would impact the Company’s effective tax rate. Approximately $25.8 million of unrecognized tax benefits were netted with deferred tax asset carryforwards. The remaining unrecognized tax benefits are included in other long-term liabilities in the Condensed Consolidated Balance Sheets. The Company has accrued interest of $1.1 million related to uncertain tax positions. The Company's accounting policy with respect to interest and penalties related to tax uncertainties is to classify these amounts as income taxes. The Company's effective tax rate for the three months ended March 31, 2018 and 2017 was 16.7% and 27.9%, respectively, as compared to the Company's combined federal and state expected statutory tax rate of 26.1% and 39.3% for each of the three months ended March 31, 2018 and 2017, respectively. The Company's effective tax rate for the three months ended March 31, 2018 and 2017 varies from the statutory rate primarily due to the reduction of income subject to tax associated with the noncontrolling ownership interests of CVR Refining's and CVR Partners' earnings (loss) and state income tax credits. The effective tax rate for the three months ended March 31, 2018 varies from the three months ended March 31, 2017 due to the reduction of the federal income tax rate from 35% to 21% as a result of the Tax Cuts and Jobs Act legislation that was signed into law in December 2017.

Long-Term Debt

3 Months Ended

Mar. 31, 2018

Debt Disclosure [Abstract]

Long-Term Debt

(9) Long-Term Debt

Long-term debt consisted of the following:



	March 31, 2018			December 31, 2017
	(in millions)
6.5% Senior Notes due 2022	$	500.0		$	500.0
9.25% Senior Secured Notes due 2023	645.0			645.0
6.5% Senior Notes due 2021	2.2			2.2
Capital lease obligations	44.5			45.0
Total debt	1,191.7			1,192.2
Unamortized debt issuance cost	(11.7		)	(12.2		)
Unamortized debt discount	(13.0		)	(13.5		)
Current portion of capital lease obligations	(2.2		)	(2.1		)
Long-term debt, net of current portion	$	1,164.8		$	1,164.4

2022 Senior Notes

On October 23, 2012, CVR Refining, LLC ("Refining LLC") and Coffeyville Finance Inc. ("Coffeyville Finance") issued $500.0 million aggregate principal amount of the 6.5% Second Lien Senior Notes due 2022 (the "2022 Notes"). The debt issuance costs of the 2022 Notes totaled approximately $8.7 million and are being amortized over the term of the 2022 Notes as interest expense using the effective-interest amortization method. As of March 31, 2018, the 2022 Notes had an aggregate principal balance and a net carrying value of $500.0 million.

The indenture governing the 2022 Notes imposes covenants that restrict the ability of the issuers and subsidiary guarantors to (i) issue debt, (ii) incur or otherwise cause liens to exist on any of its property or assets, (iii) declare or pay dividends, repurchase equity, or make payments on subordinated or unsecured debt, (iv) make certain investments, (v) sell certain assets, (vi) merge, consolidate with or into another entity, or sell all or substantially all of its assets, and (vii) enter into certain transactions with affiliates. Most of the foregoing covenants would cease to apply at such time that the 2022 Notes are rated investment grade by both Standard & Poor's Financial Services LLC and Moody's Investors Service, Inc. However, such covenants would be reinstituted if the 2022 Notes subsequently lost their investment grade rating. In addition, the indenture contains customary events of default, the occurrence of which would result in, or permit the trustee or the holders of at least 25% of the 2022 Notes to cause, the acceleration of the 2022 Notes, in addition to the pursuit of other available remedies.

The indenture governing the 2022 Notes prohibits the Refining Partnership from making distributions to its unitholders if any default or event of default (as defined in the indenture) exists. In addition, the indenture limits the Refining Partnership's ability to pay distributions to unitholders. The covenants will apply differently depending on the Refining Partnership's fixed charge coverage ratio (as defined in the indenture). If the fixed charge coverage ratio is not less than 2.5 to 1.0, the Refining Partnership will generally be permitted to make restricted payments, including distributions to its unitholders, without substantive restriction. If the fixed charge coverage ratio is less than 2.5 to 1.0, the Refining Partnership will generally be permitted to make restricted payments, including distributions to unitholders, up to an aggregate $100.0 million basket plus certain other amounts referred to as "incremental funds" under the indenture. The Refining Partnership was in compliance with the covenants as of March 31, 2018, and the ratio was satisfied (not less than 2.5 to 1.0).

At March 31, 2018, the estimated fair value of the 2022 Notes was approximately $510.0 million. This estimate of fair value is Level 2 as it was determined by quotations obtained from a broker-dealer who makes a market in these and similar securities.

Amended and Restated Asset Based (ABL) Credit Facility

On November 14, 2017, CRLLC, CVR Refining, Refining LLC and each of the operating subsidiaries of Refining LLC (collectively, the "Credit Parties") entered into Amendment No. 1 to the Amended and Restated ABL Credit Agreement (the "Amendment") with a group of lenders and Wells Fargo Bank, National Association ("Wells Fargo"), as administrative agent and collateral agent. The Amendment amends certain provisions of the Amended and Restated ABL Credit Agreement, dated December 20, 2012, by and among Wells Fargo, the group of lenders party thereto and the Credit Parties (the "Existing Credit Agreement" and as amended by the Amendment, the "Amended and Restated ABL Credit Facility"), which was otherwise scheduled to mature on December 20, 2017. The Amended and Restated ABL Credit Facility is scheduled to mature on November 14, 2022.

The Amended and Restated ABL Credit Facility is a $400.0 million asset-based revolving credit facility, with sub-limits for letters of credit and swingline loans of $60.0 million and $40.0 million, respectively. The Amended and Restated ABL Credit Facility permits the payment of distributions, subject to the following conditions: (i) no default or event of default exists, (ii) excess availability exceeds 15% of the lesser of the borrowing base and the total commitments and (iii) the fixed charge coverage ratio for the immediately preceding twelve-month period shall be equal to or greater than 1.00 to 1.00. The Amended and Restated ABL Credit Facility has a five-year maturity and may be used for working capital and other general corporate purposes (including permitted acquisitions).

Borrowings under the Amended and Restated ABL Credit Facility bear interest at either a base rate or London Interbank Offered Rate ("LIBOR") plus an applicable margin. The applicable margin is (i) (a) 1.50% for LIBOR borrowings and (b) 0.50% for prime rate borrowings, in each case if quarterly average excess availability exceeds 50% of the lesser of the borrowing base and the total commitments and (ii) (a) 1.75% for LIBOR borrowings and (b) 0.75% for prime rate borrowings, in each case if quarterly average excess availability is less than or equal to 50% of the lesser of the borrowing base and the total commitments. The Amended and Restated ABL Credit Facility also requires the payment of customary fees, including an unused line fee of (i) 0.375% if the daily average amount of loans and letters of credit outstanding is less than 50% of the lesser of the borrowing base and the total commitments and (ii) 0.25% if the daily average amount of loans and letters of credit outstanding is equal to or greater than 50% of the lesser of the borrowing base and the total commitments. The Credit Parties are also required to pay customary letter of credit fees equal to, for standby letters of credit, the applicable margin on LIBOR loans on the maximum amount available to be drawn under and, for commercial letters of credit, the applicable margin on LIBOR loans less 0.50% on the maximum amount available to be drawn under, and customary facing fees equal to 0.125% of the face amount of, each letter of credit.

The lenders under the Amended and Restated ABL Credit Facility were granted a perfected, first priority security interest (subject to certain customary exceptions) in the ABL Priority Collateral (as defined in the ABL Intercreditor Agreement) and a second priority lien (subject to certain customary exceptions) and security interest in the Note Priority Collateral (as defined in the ABL Intercreditor Agreement).

The Amended and Restated ABL Credit Facility also contains customary covenants for a financing of this type that limit the ability of the Credit Parties and their respective subsidiaries to, among other things, incur liens, engage in a consolidation, merger, purchase or sale of assets, pay dividends, incur indebtedness, make advances, investments and loans, enter into affiliate transactions, issue equity interests, or create subsidiaries and unrestricted subsidiaries. The Amended and Restated ABL Credit Facility also contains a fixed charge coverage ratio financial covenant, as defined under the facility. The Credit Parties were in compliance with the covenants of the Amended and Restated ABL Credit Facility as of March 31, 2018.

As of March 31, 2018, the Refining Partnership had availability under the Amended and Restated ABL Credit Facility of $297.9 million and had letters of credit outstanding of approximately $6.4 million. There were no borrowings outstanding under the Amended and Restated ABL Credit Facility as of March 31, 2018. Availability under the Amended and Restated ABL Credit Facility was limited by borrowing base conditions as of March 31, 2018.

2023 Senior Notes

On June 10, 2016, CVR Partners and CVR Nitrogen Finance Corporation ("CVR Nitrogen Finance"), an indirect wholly-owned subsidiary of CVR Partners, certain subsidiary guarantors named therein and Wilmington Trust, National Association, as trustee and as collateral trustee, completed a private offering of $645.0 million aggregate principal amount of 9.250% Senior Secured Notes due 2023 (the "2023 Notes"). The 2023 Notes mature on June 15, 2023, unless earlier redeemed or repurchased by the issuers. Interest on the 2023 Notes is payable semi-annually in arrears on June 15 and December 15 of each year. The 2023 Notes are guaranteed on a senior secured basis by all of the Nitrogen Fertilizer Partnership’s existing subsidiaries.

The 2023 Notes were issued at a $16.1 million discount, which is being amortized over the term of the 2023 Notes as interest expense using the effective-interest method. As a result of the issuance, approximately $9.4 million of debt issuance costs were incurred, which are being amortized over the term of the 2023 Notes as interest expense using the effective-interest method.

The 2023 Notes contain customary covenants for a financing of this type that, among other things, restrict the Nitrogen Fertilizer Partnership’s ability and the ability of certain of its subsidiaries to: (i) sell assets; (ii) pay distributions on, redeem or repurchase the Nitrogen Fertilizer Partnership’s units or redeem or repurchase its subordinated debt; (iii) make investments; (iv) incur or guarantee additional indebtedness or issue preferred units; (v) create or incur certain liens; (vi) enter into agreements that restrict distributions or other payments from the Nitrogen Fertilizer Partnership’s restricted subsidiaries to the Nitrogen Fertilizer Partnership; (vii) consolidate, merge or transfer all or substantially all of the Nitrogen Fertilizer Partnership’s assets; (viii) engage in transactions with affiliates; and (ix) create unrestricted subsidiaries.

The indenture governing the 2023 Notes prohibits the Nitrogen Fertilizer Partnership from making distributions to unitholders if any default or event of default (as defined in the indenture) exists. In addition, the indenture limits the Nitrogen Fertilizer Partnership's ability to pay distributions to unitholders. The covenants will apply differently depending on the Nitrogen Fertilizer Partnership's fixed charge coverage ratio (as defined in the indenture). If the fixed charge coverage ratio is not less than 1.75 to 1.0, the Nitrogen Fertilizer Partnership will generally be permitted to make restricted payments, including distributions to its unitholders, without substantive restriction. If the fixed charge coverage ratio is less than 1.75 to 1.0, the Nitrogen Fertilizer Partnership will generally be permitted to make restricted payments, including distributions to its unitholders, up to an aggregate $75.0 million basket plus certain other amounts referred to as "incremental funds" under the indenture. As of March 31, 2018, the ratio was less than 1.75 to 1.0. Restricted payments have been made, and $72.7 million of the basket was available as of March 31, 2018. As of March 31, 2018, the Nitrogen Fertilizer Partnership was in compliance with the covenants contained in the 2023 Notes.

Included in other current liabilities on the Condensed Consolidated Balance Sheets is accrued interest payable totaling approximately $17.6 million and $2.7 million, respectively, as of March 31, 2018 and December 31, 2017 related to the 2023 Notes. At March 31, 2018 and December 31, 2017, respectively, the estimated fair value of the 2023 Notes was approximately $686.7 million and $694.2 million. This estimate of fair value is Level 2 as it was determined by quotations obtained from a broker-dealer who makes a market in these and similar securities.

Asset Based (ABL) Credit Facility

On September 30, 2016, the Nitrogen Fertilizer Partnership entered into a senior secured asset based revolving credit facility (the "ABL Credit Facility") with a group of lenders and UBS AG, Stamford Branch, as administrative agent and collateral agent. The ABL Credit Facility has an aggregate principal amount of availability of up to $50.0 million with an incremental facility, which permits an increase in borrowings of up to $25.0 million in the aggregate subject to additional lender commitments and certain other conditions. The proceeds of the loans may be used for capital expenditures and working capital and general corporate purposes of the Nitrogen Fertilizer Partnership and its subsidiaries. The ABL Credit Facility provides for loans and standby letters of credit in an amount up to aggregate availability under the facility, subject to meeting certain borrowing base conditions, with sub-limits of the lesser of 10% of the total facility commitment and $5.0 million for swingline loans and $10.0 million for letters of credit. The ABL Credit Facility is scheduled to mature on September 30, 2021.

At the option of the borrowers, loans under the ABL Credit Facility initially bear interest at an annual rate equal to (i) 2.00% plus LIBOR or (ii) 1.00% plus a base rate, subject to a 0.50% step-down based on the previous quarter’s excess availability. The borrowers must also pay a commitment fee on the unutilized commitments and also pay customary letter of credit fees.

The ABL Credit Facility also contains customary covenants for a financing of this type that limit the ability of the Nitrogen Fertilizer Partnership and its subsidiaries to, among other things, incur liens, engage in a consolidation, merger, purchase or sale of assets, pay dividends, incur indebtedness, make advances, investments and loans, enter into affiliate transactions, issue equity interests or create subsidiaries and unrestricted subsidiaries. The ABL Credit Facility also contains a fixed charge coverage ratio financial covenant, as defined therein. The Nitrogen Fertilizer Partnership was in compliance with the covenants of the ABL Credit Facility as of March 31, 2018.

As of March 31, 2018, the Nitrogen Fertilizer Partnership and its subsidiaries had availability under the ABL Credit Facility of $49.2 million. There were no borrowings outstanding under the ABL Credit Facility as of March 31, 2018.

Capital Lease Obligations

CVR Refining maintains two leases, accounted for as a capital lease and a financial obligation, related to Magellan Pipeline Terminals, L.P. ("Magellan Pipeline") and Excel Pipeline LLC ("Excel Pipeline"). The underlying assets and related depreciation are included in property, plant and equipment, net of accumulated depreciation on the Condensed Consolidated Balance Sheets. The capital lease, which relates to a sales-lease back agreement with Sunoco Pipeline, L.P. for its membership interest in the Excel Pipeline, has 139 months remaining of its term and will expire in September 2029. The financing agreement, which relates to the Magellan Pipeline terminals, bulk terminal and loading facility, has a lease term with 138 months remaining and will expire in September 2029.

Earnings Per Share

3 Months Ended

Mar. 31, 2018

Earnings Per Share [Abstract]

Earnings Per Share

(10) Earnings Per Share

Basic and diluted earnings per share are computed by dividing net income attributable to CVR stockholders by the weighted-average number of shares of common stock outstanding. The components of the basic and diluted earnings per share calculation are as follows:



	Three Months Ended March 31,
	2018		2017
	(in millions, except per share data)
Net income attributable to CVR Energy stockholders	$	66.2	$	22.2

Weighted-average shares of common stock outstanding - Basic and diluted	86.8		86.8

Basic and diluted earnings per share	$	0.76	$	0.26

There were no dilutive awards outstanding during the three months ended March 31, 2018 and 2017, as all unvested awards under the LTIP were liability-classified awards. See Note 4 ("Share-Based Compensation").

Commitments and Contingencies

3 Months Ended

Mar. 31, 2018

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

(11) Commitments and Contingencies

Leases and Unconditional Purchase Obligations

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



	Operating Leases		Unconditional Purchase Obligations⁽¹⁾
	(in millions)
Nine Months Ending December 31, 2018	$	5.9	$	117.2
Year Ending December 31,
2019	7.0		125.1
2020	6.4		99.7
2021	5.8		88.7
2022	5.4		84.2
Thereafter	3.7		538.8
	$	34.2	$	1,053.7

(1)

This amount includes approximately $678.9 million payable ratably over 13 years pursuant to petroleum transportation service agreements between CRRM and each of TransCanada Keystone Pipeline Limited Partnership and TransCanada Keystone Pipeline, LP (together, "TransCanada"). The purchase obligation reflects the exchange rate between the Canadian dollar and the U.S. dollar as of March 31, 2018, where applicable. Under the agreements, CRRM receives transportation of at least 25,000 barrels per day of crude oil with a delivery point at Cushing, Oklahoma for a term of 20 years on TransCanada's Keystone pipeline system.

CVR leases equipment, including railcars and real properties, under long-term operating leases expiring at various dates through 2035. For the three months ended March 31, 2018 and 2017, lease expense totaled approximately $1.9 million and $2.1 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, water and pipeline transportation services. For the three months ended March 31, 2018 and 2017, total expense of approximately $48.5 million and $55.3 million, respectively, was incurred related to long-term commitments.

Crude Oil Supply Agreement

On August 31, 2012, CRRM and Vitol Inc. ("Vitol") entered into an Amended and Restated Crude Oil Supply Agreement (as amended, the "Vitol Agreement"). Under the Vitol Agreement, Vitol supplies the petroleum business with crude oil and intermediation logistics, which helps to reduce the Refining Partnership's inventory position and mitigate crude oil pricing risk. The Vitol Agreement will automatically renew for successive one-year terms (each such term, a "Renewal Term") unless either party provides the other with notice of nonrenewal at least 180 days prior to the expiration of any Renewal Term. The Vitol Agreement currently extends through December 31, 2018.

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. There were no new proceedings or material developments in proceedings that CVR previously reported in its 2017 Form 10-K. In the opinion of management, the ultimate resolution of any other litigation matters is not expected to have a material adverse effect on the accompanying condensed consolidated financial statements. There can be no assurance that management's beliefs or opinions with respect to liability for potential litigation matters will prove to be accurate.

The U.S. Attorney's office for the Southern District of New York contacted CVR Energy in September 2017 seeking production of information pertaining to CVR Refining's, CVR Energy's and Mr. Carl C. Icahn's activities relating to the Renewable Fuel Standard ("RFS") and Mr. Icahn's role as an advisor to the President. CVR Energy is cooperating with the request and is providing information in response to the subpoena. The U.S. Attorney's office has not made any claims or allegations against CVR Energy or Mr. Icahn. CVR Energy maintains a strong compliance program and, while no assurances can be made, CVR Energy does not believe this inquiry will have a material impact on its business, financial condition, results of operations or cash flows.

Environmental, Health and Safety ("EHS") Matters

The petroleum and nitrogen fertilizer businesses are subject to various stringent federal, state, and local EHS rules and regulations. Liabilities related to EHS matters are recognized when the related costs are probable and can be reasonably estimated. Estimates of these costs are based upon currently available facts, existing technology, site-specific costs and currently enacted laws and regulations. In reporting EHS liabilities, no offset is made for potential recoveries.

Except as otherwise described below, there have been no new developments or material changes to the environmental accruals or expected capital expenditures related to compliance with the environmental matters from those provided in the 2017 Form 10-K. The Company believes the petroleum and nitrogen fertilizer businesses are in material compliance with existing EHS rules and regulations. There can be no assurance that the EHS matters described or referenced herein or other EHS matters which may develop in the future will not have a material adverse effect on the Company's business, financial condition or results of operations.

At March 31, 2018, the Company's Condensed Consolidated Balance Sheets included total environmental accruals of $3.6 million, as compared to $3.9 million at December 31, 2017. Management periodically reviews and, as appropriate, revises its environmental accruals. Based on current information and regulatory requirements, management believes that the accruals established for environmental expenditures are adequate.

Environmental expenditures are capitalized when such expenditures are expected to result in future economic benefits. For both the three months ended March 31, 2018 and 2017, capital expenditures were approximately $4.7 million. These expenditures were incurred for environmental compliance and efficiency of the operations.

Renewable Fuel Standards

The petroleum business is subject to the RFS which requires refiners to either blend "renewable fuels" in with their transportation fuels or purchase renewable fuel credits, known as RINs, in lieu of blending. Due to mandates in the RFS requiring increasing volumes of renewable fuels to replace petroleum products in the U.S. transportation fuel market, there may be a decrease in demand for petroleum products. The petroleum business is not able to blend the substantial majority of its transportation fuels and has to purchase RINs on the open market, as well as waiver credits for cellulosic biofuels from the EPA, in order to comply with the RFS.

The price of RINs has been extremely volatile over the last year. The cost of RINs is dependent upon a variety of factors, which include the availability of RINs for purchase, the price at which RINs can be purchased, transportation fuel production levels, the mix of the petroleum business' petroleum products, as well as the fuel blending performed at its refineries and downstream terminals, all of which can vary significantly from period to period.

The net cost of RINs for the three months ended March 31, 2018 and 2017 was a negative $22.7 million and a negative $6.4 million, respectively. The net costs of RINs was a reduction to cost of materials and other in the Condensed Consolidated Statements of Operations. RINs expense includes the purchased cost of RINs, the impact of recognizing the petroleum business' uncommitted biofuel blending obligation at fair value based on market prices at each reporting date and is reduced by the valuation change of RINs purchases in excess of the petroleum business' RFS obligation as of the reporting date. During the three months ended March 31, 2018, the net cost of RINs was favorably impacted by a reduction in the petroleum business' RFS obligation and reduced market pricing. As of March 31, 2018 and December 31, 2017, the petroleum business' biofuel blending obligation was approximately $21.4 million and $28.3 million, respectively, which was recorded in other current liabilities on the Condensed Consolidated Balance Sheets. As of March 31, 2018, the petroleum business recorded a RINs asset within prepaid and other current assets in the Condensed Consolidated Balance Sheet of $59.9 million, representing excess RINs primarily due to a reduction in its RFS obligation.

Affiliate Pension Obligations

Mr. Carl C. Icahn, through certain affiliates, owns approximately 82% of the Company's capital stock. Applicable pension and tax laws make each member of a "controlled group" of entities, generally defined as entities in which there is at least an 80% common ownership interest, jointly and severally liable for certain pension plan obligations of any member of the controlled group. These pension obligations include ongoing contributions to fund the plan, as well as liability for any unfunded liabilities that may exist at the time the plan is terminated. In addition, the failure to pay these pension obligations when due may result in the creation of liens in favor of the pension plan or the Pension Benefit Guaranty Corporation ("PBGC") against the assets of each member of the controlled group.

As a result of the more than 80% ownership interest in CVR Energy by Mr. Icahn's affiliates, the Company is subject to the pension liabilities of all entities in which Mr. Icahn has a direct or indirect ownership interest of at least 80%. Two such entities, ACF Industries LLC ("ACF") and Federal-Mogul, are the sponsors of several pension plans. All the minimum funding requirements of the Code and the Employee Retirement Income Security Act of 1974, as amended by the Pension Protection Act of 2006, for these plans have been met as of March 31, 2018 and December 31, 2017. If the ACF and Federal-Mogul plans were voluntarily terminated, they would be collectively underfunded by approximately $417.1 million and $423.7 million as of March 31, 2018 and December 31, 2017, respectively. These results are based on the most recent information provided by Mr. Icahn's affiliates based on information from the plans' actuaries. These liabilities could increase or decrease, depending on a number of factors, including future changes in benefits, investment returns, and the assumptions used to calculate the liability. As members of the controlled group, CVR Energy would be liable for any failure of ACF and Federal-Mogul to make ongoing pension contributions or to pay the unfunded liabilities upon a termination of their respective pension plans. In addition, other entities now or in the future within the controlled group that includes CVR Energy may have pension plan obligations that are, or may become, underfunded, and the Company would be liable for any failure of such entities to make ongoing pension contributions or to pay the unfunded liabilities upon a termination of such plans. The current underfunded status of the ACF and Federal-Mogul pension plans requires such entities to notify the PBGC of certain "reportable events," such as if CVR Energy were to cease to be a member of the controlled group, or if CVR Energy makes certain extraordinary dividends or stock redemptions. The obligation to report could cause the Company to seek to delay or reconsider the occurrence of such reportable events. Based on the contingent nature of potential exposure related to these affiliate pension obligations, no liability has been recorded in the condensed consolidated financial statements.

Fair Value Measurements

3 Months Ended

Mar. 31, 2018

Fair Value Disclosures [Abstract]

Fair Value Measurements

(12) Fair Value Measurements

In accordance with FASB ASC Topic 820 — Fair Value Measurements and Disclosures ("ASC 820"), the Company utilizes the market approach to measure fair value for its financial assets and liabilities. The market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets, liabilities or a group of assets or liabilities, such as a business.

ASC 820 utilizes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three broad levels. The following is a brief description of those three levels:


•	Level 1 — Quoted prices in active markets for identical assets or liabilities


•	Level 2 — Other significant observable inputs (including quoted prices in active markets for similar assets or liabilities)


•	Level 3 — Significant unobservable inputs (including the Company's own assumptions in determining the fair value)

The following tables set forth the assets and liabilities measured at fair value on a recurring basis, by input level, as of March 31, 2018 and December 31, 2017:



	March 31, 2018
Location and Description	Level 1		Level 2			Level 3		Total
	(in millions)
Cash equivalents	$	15.3	$	—		$	—	$	15.3
Other current assets (investments)	0.1		—			—		0.1
Other current assets (commodity derivatives)	—		3.1			—		3.1
Total Assets	$	15.4	$	3.1		$	—	$	18.5
Other current liabilities (commodity derivatives)	$	—	$	(21.8	)	$	—	$	(21.8	)
Other current liabilities (biofuel blending obligation)	—		(19.5		)	—		(19.5		)
Total Liabilities	$	—	$	(41.3	)	$	—	$	(41.3	)



	December 31, 2017
Location and Description	Level 1		Level 2			Level 3		Total
	(in millions)
Cash equivalents	$	15.2	$	—		$	—	$	15.2
Other current assets (investments)	0.1		—			—		0.1
Total Assets	$	15.3	$	—		$	—	$	15.3
Other current liabilities (commodity derivatives)	$	—	$	(64.3	)	$	—	$	(64.3	)
Other long-term liabilities (biofuel blending obligation)	—		(1.0		)	—		(1.0		)
Total Liabilities	$	—	$	(65.3	)	$	—	$	(65.3	)

As of March 31, 2018 and December 31, 2017, the only financial assets and liabilities that are measured at fair value on a recurring basis are the Company's cash equivalents, investments, derivative instruments and the uncommitted biofuel blending obligation. Additionally, the fair value of the Company's debt issuances is disclosed in Note 9 ("Long-Term Debt").

The Refining Partnership's commodity derivative contracts and the uncommitted biofuel blending obligation, which use fair value measurements and are valued using broker quoted market prices of similar instruments, are considered Level 2 inputs. The Company had no transfers of assets and liabilities between any of the above levels during the three months ended March 31, 2018.

- 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 + Details

Derivative Financial Instruments

3 Months Ended

Mar. 31, 2018

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Financial Instruments

(13) Derivative Financial Instruments

Current period settlements on derivative contracts and Gain on derivatives, net were as follows:



	Three Months Ended March 31,
	2018		2017
	(in millions)
Current period settlements on derivative contracts	$	13.7	$	1.2
Gain on derivatives, net	59.3		12.2

The Refining Partnership and Nitrogen Fertilizer Partnership are subject to price fluctuations caused by supply conditions, weather, economic conditions, interest rate fluctuations and other factors. To manage price risk on crude oil and other inventories and to fix margins on certain future production, the Refining Partnership from time to time enters into various commodity derivative transactions.

The Refining Partnership has adopted accounting standards which impose extensive record-keeping requirements in order to designate a derivative financial instrument as a hedge. The Refining Partnership holds derivative instruments, such as exchange-traded crude oil futures and certain over-the-counter forward swap agreements, which it believes provide an economic hedge on future transactions, but such instruments are not designated as hedges under GAAP. Gains or losses related to the change in fair value and periodic settlements of these derivative instruments are classified as gain (loss) on derivatives, net in the Condensed Consolidated Statements of Operations. There are no premiums paid or received at inception of the derivative contracts and upon settlement, there is no cost recovery associated with these contracts.

The Refining Partnership maintains a margin account to facilitate other commodity derivative activities. A portion of this account may include funds available for withdrawal. These funds are included in cash and cash equivalents within the Condensed Consolidated Balance Sheets. The maintenance margin balance is included within other current assets within the Condensed Consolidated Balance Sheets. Dependent upon the position of the open commodity derivatives, the amounts are accounted for as other current assets or other current liabilities within the Condensed Consolidated Balance Sheets. From time to time, the Refining Partnership may be required to deposit additional funds into this margin account. The fair value of the open commodity positions as of March 31, 2018 was a net loss of $0.2 million included in other current liabilities. For the three months ended March 31, 2018 and 2017, the Refining Partnership recognized net losses of $0.2 million and $0.1 million, respectively, which are recorded in gain on derivatives, net in the Condensed Consolidated Statements of Operations.

Commodity Derivatives

The Refining Partnership enters into commodity swap contracts in order to fix the margin on a portion of future production. Additionally, the Refining Partnership may enter into price and basis swaps in order to fix the price on a portion of its commodity purchases and product sales. The physical volumes are not exchanged and these contracts are net settled with cash. The contract fair value of the commodity swaps is reflected on the Condensed Consolidated Balance Sheets with changes in fair value currently recognized in the Condensed Consolidated Statements of Operations. Quoted prices for similar assets or liabilities in active markets (Level 2) are considered to determine the fair values for the purpose of marking to market the hedging instruments at each period end. At March 31, 2018, the Refining Partnership had open commodity swap instruments consisting of 1.7 million barrels of 2-1-1 crack spreads, 0.6 million barrels of distillate crack spreads and 0.6 million barrels of gasoline crack spreads. At December 31, 2017, the Refining Partnership had open commodity swap instruments consisting of 7.1 million barrels of 2-1-1 crack spreads, 3.6 million barrels of distillate crack spreads, and 3.6 million barrels of gasoline crack spreads. Additionally, as of March 31, 2018 and December 31, 2017, CVR Refining had open forward purchase and sale commitments for 4.2 million barrels and 5.8 million barrels, respectively, of Canadian crude oil priced at fixed differentials that are not considered probable of physical settlement and are accounted for as derivatives. The fair value of the outstanding commodity derivative contracts at March 31, 2018 was a net unrealized loss of $18.5 million, of which $3.1 million is included in other current assets and $21.6 million is included in other current liabilities. The fair value of the outstanding contracts at December 31, 2017 was a net unrealized loss of $64.3 million, of which the entire balance is recorded in other current liabilities. For the three months ended March 31, 2018 and 2017, the Refining Partnership recognized net gains of $59.7 million and $12.3 million, respectively, which are recorded in gain on derivatives, net in the Condensed Consolidated Statements of Operations.

Counterparty Credit Risk

The Refining Partnership's exchange-traded crude oil futures and certain over-the-counter forward swap agreements are potentially exposed to concentrations of credit risk as a result of economic conditions and periods of uncertainty and illiquidity in the credit and capital markets. The Refining Partnership manages credit risk on its exchange-traded crude oil futures by completing trades with an exchange clearinghouse, which subjects the trades to mandatory margin requirements until the contract settles. The Refining Partnership also monitors the creditworthiness of its commodity swap counterparties and assesses the risk of nonperformance on a quarterly basis. Counterparty credit risk identified as a result of this assessment is recognized as a valuation adjustment to the fair value of the commodity swaps recorded in the Condensed Consolidated Balance Sheets. As of March 31, 2018, the counterparty credit risk adjustment was not material to the condensed consolidated financial statements. Additionally, the Refining Partnership does not require any collateral to support commodity swaps into which it enters; however, it does have master netting arrangements that allow for the setoff of amounts receivable from and payable to the same party, which mitigates the risk associated with nonperformance.

Offsetting Assets and Liabilities

The commodity swap agreements discussed above include multiple derivative positions with a number of counterparties for which the Refining Partnership has entered into agreements governing the nature of the derivative transactions. Each of the counterparty agreements provides for the right to setoff each individual derivative position to arrive at the net receivable due from the counterparty or payable owed by the Refining Partnership. As a result of the right to setoff, the Refining Partnership's recognized assets and liabilities associated with the outstanding commodity swap derivative positions have been presented net in the Condensed Consolidated Balance Sheets. The tables below outline the gross amounts of the recognized assets and liabilities and the gross amounts offset in the Condensed Consolidated Balance Sheets for the various types of open derivative positions at the Refining Partnership.

The offsetting assets and liabilities for the Refining Partnership's derivatives as of March 31, 2018 and December 31, 2017 are recorded as current assets and current liabilities in prepaid expenses and other current assets and accrued expenses and other current liabilities, respectively, in the Condensed Consolidated Balance Sheets as follows:



	As of March 31, 2018
Description	Gross Current Assets			Gross Amounts Offset			Net Current Assets Presented			Cash Collateral Not Offset		Net Amount
	(in millions)
Commodity Derivatives	$	8.0		$	(4.9	)	$	3.1		$	—	$	3.1
Total	$	8.0		$	(4.9	)	$	3.1		$	—	$	3.1

	As of March 31, 2018
Description	Gross Current Liabilities			Gross Amounts Offset			Net Current Liabilities Presented			Cash Collateral Not Offset		Net Amount
	(in millions)
Commodity Derivatives	$	(26.7	)	$	4.9		$	(21.8	)	$	—	$	(21.8	)
Total	$	(26.7	)	$	4.9		$	(21.8	)	$	—	$	(21.8	)



	As of December 31, 2017
Description	Gross Current Assets		Gross Amounts Offset			Net Current Assets Presented		Cash Collateral Not Offset		Net Amount
	(in millions)
Commodity Derivatives	$	7.0	$	(7.0	)	$	—	$	—	$	—
Total	$	7.0	$	(7.0	)	$	—	$	—	$	—

	As of December 31, 2017
Description	Gross Current Liabilities		Gross Amounts Offset			Net Current Liabilities Presented		Cash Collateral Not Offset		Net Amount
	(in millions)
Commodity Derivatives	$	71.3	$	(7.0	)	$	64.3	$	—	$	64.3
Total	$	71.3	$	(7.0	)	$	64.3	$	—	$	64.3

Related Party Transactions	3 Months Ended
Related Party Transactions	Mar. 31, 2018
Related Party Transactions [Abstract]
Related Party Transactions	(14) Related Party Transactions Icahn Enterprises In May 2012, IEP announced that it had acquired control of CVR pursuant to a tender offer to purchase all of the issued and outstanding shares of the Company's common stock. As of March 31, 2018, IEP and its affiliates owned approximately 82% of the Company's outstanding common shares. On March 12, 2018, CVR Energy paid a cash dividend to the Company's stockholders of record at the close of business on March 5, 2018 for the fourth quarter of 2017 in the amount of $0.50 per share, or $43.4 million in the aggregate. IEP received $35.6 million in respect of its common shares. Tax Allocation Agreement CVR is a member of the consolidated federal tax group of AEPC, a wholly-owned subsidiary of IEP, and has entered into a Tax Allocation Agreement. Refer to Note 8 ("Income Taxes") for a discussion of related party transactions under the Tax Allocation Agreement. Insight Portfolio Group Insight Portfolio Group LLC ("Insight Portfolio Group") is an entity formed and controlled by Mr. Icahn in order to maximize the potential buying power of a group of entities with which Mr. Icahn has a relationship in negotiating with a wide range of suppliers of goods, services and tangible and intangible property at negotiated rates. CVR Energy became a member of the buying group in 2012. In January 2013, CVR Energy acquired a minority equity interest in Insight Portfolio Group and agreed to pay a portion of Insight Portfolio Group's operating expenses in 2013. The Company paid Insight Portfolio Group approximately $0.2 million and $0.1 million for the three months ended March 31, 2018 and 2017, respectively. The Company may purchase a variety of goods and services as a member of the buying group at prices and terms that management believes would be more favorable than those which would be achieved on a stand-alone basis. Railcar Lease Agreements and Maintenance The Nitrogen Fertilizer Partnership has agreements that expire in 2023 to lease a total of 115 UAN railcars from ARI Leasing, LLC ("ARI"), a company controlled by IEP. In the second quarter of 2017, the Nitrogen Fertilizer Partnership entered into an agreement to lease an additional 70 UAN railcars from ARI which will expire in 2022. The Nitrogen Fertilizer Partnership received the additional 70 leased railcars during the second half of 2017. For the three months ended March 31, 2018 and 2017, rent expense of approximately $0.4 million and $0.2 million, respectively, was recorded in cost of materials and other in the Condensed Consolidated Statement of Operations related to these agreements. American Railcar Industries, Inc., a company controlled by IEP, performed railcar maintenance for the Nitrogen Fertilizer Partnership and the expense associated with this maintenance was approximately $0.2 million for the three months ended March 31, 2017 and was included in cost of materials and other in the Condensed Consolidated Statement of Operations. Expense associated with this maintenance was nominal for the three months ended March 31, 2018. Joint Venture Agreements The Refining Partnership holds a 40% and 50% interest in the VPP and Midway joint ventures, respectively. The joint ventures provide the Refining Partnership with crude oil transportation services. Refer to Note 7 ("Equity Method Investments") for additional discussion of the joint ventures.

Business Segments

3 Months Ended

Mar. 31, 2018

Segment Reporting [Abstract]

Business Segments

(15) Business Segments

Operating segments are defined in FASB ASC Topic 280 - Segment Reporting, as components of an enterprise about which separate financial information is available and evaluated regularly by the chief operating decision maker, or decision-making group, in deciding how to allocate resources and in assessing performance. The Company measures segment profit as operating income for petroleum and nitrogen fertilizer, CVR’s two reporting segments. All intercompany transactions are eliminated in the other segment as described below. All operations of the segments are located within the United States.

Petroleum

Principal products of the petroleum segment include gasoline, diesel fuel, jet fuel, natural gas liquids, asphalt and petroleum refining by-products, including petroleum coke, which are sold to retailers, petroleum jobbers, railroads and other refiners/marketers. The petroleum segment also sells hydrogen and petroleum coke to the nitrogen fertilizer segment pursuant to separate intercompany agreements. Intercompany sales included in petroleum net sales are eliminated in consolidation.

The petroleum segment may also purchase hydrogen from the nitrogen fertilizer segment under an intercompany feedstock and shared services agreement. Receipts of hydrogen from the nitrogen fertilizer segment are reported in petroleum cost of materials and other and are eliminated in consolidation.

Nitrogen Fertilizer

The principal product of the nitrogen fertilizer segment is nitrogen fertilizer. Nitrogen fertilizer is used by farmers to improve the yield and quality of their crops, primarily corn and wheat. The nitrogen fertilizer segment principally produces UAN. The nitrogen fertilizer segment's product sales are sold on a wholesale basis in North America. Intercompany sales to the petroleum segment are primarily hydrogen sales pursuant to the feedstock and shared services agreement. The nitrogen fertilizer segment also receives income from subleasing railcars to the petroleum segment's refineries. All intercompany sales included in nitrogen fertilizer net sales are eliminated in consolidation.

As described above, the nitrogen fertilizer segment purchases hydrogen and petroleum coke from the petroleum segment. Receipts of hydrogen and petroleum coke from the petroleum segment are reported in nitrogen fertilizer cost of materials and other and are eliminated in consolidation.

Other Segment

The other segment reflects intercompany eliminations, corporate cash and cash equivalents, income tax activities and other corporate activities that are not allocated to the operating segments.

The following table summarizes certain operating results and capital expenditures information by segment:



	Three Months Ended March 31,
	2018			2017
	(in millions)
Net sales
Petroleum	$	1,458.2		$	1,423.5
Nitrogen Fertilizer	79.9			85.3
Intersegment elimination	(1.6		)	(1.7		)
Total	$	1,536.5		$	1,507.1
Cost of materials and other
Petroleum	$	1,217.7		$	1,201.3
Nitrogen Fertilizer	22.3			21.8
Intersegment elimination	(1.7		)	(1.9		)
Total	$	1,238.3		$	1,221.2
Direct operating expenses (exclusive of depreciation and amortization)
Petroleum	$	93.0		$	102.1
Nitrogen Fertilizer	38.9			35.9
Other	—			0.1
Total	$	131.9		$	138.1
Depreciation and amortization
Petroleum	$	33.7		$	34.1
Nitrogen Fertilizer	16.4			15.4
Other	1.8			1.6
Total	$	51.9		$	51.1
Operating income (loss)
Petroleum	$	97.2		$	66.0
Nitrogen Fertilizer	(3.4		)	5.3
Other	(3.3		)	(3.7		)
Total	$	90.5		$	67.6
Capital expenditures
Petroleum	$	16.0		$	19.6
Nitrogen Fertilizer	2.7			4.1
Other	1.3			0.5
Total	$	20.0		$	24.2



	As of March 31, 2018		As of December 31, 2017
	(in millions)
Total assets
Petroleum	$	2,295.3	$	2,269.9
Nitrogen Fertilizer	1,239.5		1,234.3
Other	288.5		302.5
Total	$	3,823.3	$	3,806.7
Goodwill
Petroleum	$	—	$	—
Nitrogen Fertilizer	41.0		41.0
Other	—		—
Total	$	41.0	$	41.0

Subsequent Events	3 Months Ended
Subsequent Events	Mar. 31, 2018
Subsequent Events [Abstract]
Subsequent Events	(16) Subsequent Events Dividend On April 25, 2018, the board of directors of the Company declared a cash dividend for the first quarter of 2018 to the Company's stockholders of $0.50 per share, or $43.4 million in the aggregate. The dividend will be paid on May 14, 2018 to stockholders of record at the close of business on May 7, 2018. IEP will receive $35.6 million in respect of its 82% ownership interest in the Company's shares. Refining Partnership Distribution On April 25, 2018, the board of directors of the Refining Partnership's general partner declared a cash distribution for the first quarter of 2018 to the Refining Partnership's unitholders of $0.51 per common unit, or $75.3 million in aggregate. The cash distribution will be paid on May 14, 2018 to unitholders of record at the close of business on May 7, 2018. The Company will receive $49.6 million in respect of its Refining Partnership common units.

Organization and Basis of Presentation (Policies)	3 Months Ended
Organization and Basis of Presentation (Policies)	Mar. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation	The accompanying condensed consolidated financial statements were prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") and in accordance with the rules and regulations of the Securities and Exchange Commission ("SEC"). The condensed consolidated financial statements include the accounts of CVR and its direct and indirect subsidiaries including the Nitrogen Fertilizer Partnership, the Refining Partnership and their respective subsidiaries, as discussed further below. The ownership interests of noncontrolling investors in CVR's subsidiaries are recorded as a noncontrolling interest included as a separate component of equity for all periods presented. All intercompany account balances and transactions have been eliminated in consolidation. Certain information and footnotes required for complete financial statements under GAAP have been condensed or omitted pursuant to SEC rules and regulations. These condensed consolidated financial statements should be read in conjunction with the December 31, 2017 audited consolidated financial statements and notes thereto included in CVR's Annual Report on Form 10-K for the year ended December 31, 2017, which was filed with the SEC on February 26, 2018 (the "2017 Form 10-K"). According to the Financial Accounting Standards Board ("FASB") Accounting Standards Codification ("ASC") Topic 810, Consolidations, the primary beneficiary of a variable interest entity's ("VIE") activities is required 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; limited partnerships and other similar entities are considered a VIE unless the limited partners hold substantive kick-out rights or participating rights; and an ongoing analysis is required to determine whether the variable interest gives rise to a controlling financial interest in the VIE, among other things. Management has determined that the Refining Partnership and the Nitrogen Fertilizer Partnership are VIEs because the limited partners of CVR Refining and CVR Partners lack both substantive kick-out rights and participating rights. Based upon the general partner’s roles and rights as afforded by the partnership agreements and its exposure to losses and benefits of each of the partnerships through its significant limited partner interests, intercompany credit facilities, and services agreements, CVR determined that it is the primary beneficiary of both the Refining Partnership and the Nitrogen Fertilizer Partnership. Based upon that determination, CVR consolidates both the Refining and Nitrogen Fertilizer Partnerships in its consolidated financial statements. In the opinion of the Company's management, the accompanying condensed consolidated financial statements reflect all adjustments (consisting only of normal recurring adjustments) that are necessary to fairly present the financial position of the Company as of March 31, 2018 and December 31, 2017, the results of operations and comprehensive income for the three month periods ended March 31, 2018 and 2017, changes in equity for the three month period ended March 31, 2018 and cash flows of the Company for the three month periods ended March 31, 2018 and 2017. The preparation of the condensed consolidated financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results could differ materially from those estimates. Results of operations and cash flows for the interim periods presented are not necessarily indicative of the results that will be realized for the year ending December 31, 2018 or any other interim or annual period.
Recent Accounting Pronouncements	In February 2016, the FASB issued ASU No. 2016-02, “Leases” (“ASU 2016-02”), creating a new topic, FASB ASC Topic 842, "Leases," which supersedes lease requirements in FASB ASC Topic 840, "Leases." The new standard revises accounting for operating leases by a lessee, among other changes, and requires a lessee to recognize a liability related to future lease payments and an asset representing its right to use the underlying asset for the lease term in the balance sheet. Quantitative and qualitative disclosures, including disclosures regarding significant judgments made by management, will be required. The standard is effective for the first interim and annual periods beginning after December 15, 2018, with early adoption permitted. At adoption, ASU 2016-02 will be applied using the modified retrospective application method and allows for certain practical expedients. The Company expects its assessment and implementation plan to be ongoing during 2018 and is currently unable to reasonably estimate the impact of adopting the new lease standard on its consolidated financial statements and related disclosures. The Company currently believes the most significant change will relate to the recognition of right-of-use assets and leases liability on the balance sheet for existing long-term operating leases, the majority of which are railcar leases, and the potential recognition for agreements that do not currently meet the definition of a lease under ASC Topic 840, which will require an evaluation of the Company's unconditional purchase obligations primarily related to petroleum transportation and storage service agreements. The impact of the new standard on right-of-use assets, leases liability and related disclosures resulting from adoption of the new standard could be material.

Recent Accounting Pronouncements (Tables)

3 Months Ended

Mar. 31, 2018

Accounting Policies [Abstract]

Effect of the change to Condensed Consolidated Balance Sheet and Condensed Consolidated Statement of Operations



	March 31, 2018
Balance Sheet	As Reported		Balances Without Adoption of ASC 606		Effect of Change
			(in millions)
Assets
Accounts Receivable	$	179.3	$	178.6	$	0.7

Liabilities
Deferred Revenue	24.2		23.5		0.7



	Three Months Ended March 31, 2018
Statement of Operations	As Reported		Balances Without Adoption of ASC 606		Effect of Change
			(in millions)
Revenues
Net Sales	$	1,536.5	$	1,536.3	$	0.2

Operating Costs and Expenses
Cost of materials and other	1,238.3		1,238.1		0.2

Revenue (Tables)

3 Months Ended

Mar. 31, 2018

Revenue from Contract with Customer [Abstract]

Revenue disaggregated by major product

The following table presents the Company’s revenue disaggregated by major product. The table includes a reconciliation of the disaggregated revenue with the reportable segments.



	Three Months Ended March 31, 2018
	Petroleum		Nitrogen Fertilizer		Other / Eliminations			Consolidated
	(in millions)
Major Product
Gasoline	$	711.7	$	—	$	—		$	711.7
Distillates	652.2		—		—			652.2
Ammonia	—		11.6		—			11.6
UAN	—		52.8		—			52.8
Urea products	—		4.9		—			4.9
Freight revenue	5.5		8.7		—			14.2
Other (a)	87.3		1.9		(1.6		)	87.6
Revenue from product sales	1,456.7		79.9		(1.6		)	1,535.0

Other revenue (b)	1.5		—		—			1.5
Total revenue	$	1,458.2	$	79.9	$	(1.6	)	$	1,536.5

(a) Other product sales primarily include crude oil, feedstocks and asphalt sales attributable to the petroleum segment and nitric acid and carbon dioxide sales attributable to the nitrogen fertilizer segment.
(b) Other revenue consists primarily of Cushing, OK storage tank lease revenue.

Summary of deferred revenue activity

A summary of the deferred revenue activity during the three months ended March 31, 2018 is presented below:



	Three Months Ended March 31, 2018
	(in millions)
Balance at January 1, 2018	$	34.2
Add:
New prepay contracts entered into during the period	3.4
Less:
Revenue recognized that was included in the contract liability balance at the beginning of the period	11.6
Revenue recognized related to contracts entered into during the period	1.7
Other changes	0.1
Balance at March 31, 2018	$	24.2

Share-Based Compensation (Tables)

3 Months Ended

Mar. 31, 2018

Incentive Unit Award

Share-Based Compensation

Schedule of share-based compensation activity

A summary of incentive unit activity and changes during the three months ended March 31, 2018 is presented below:



	Incentive Units		Weighted-Average Grant-Date Fair Value
Non-vested at December 31, 2017	779,261		$	12.14
Granted	—		—
Vested	(1,445	)	13.65
Forfeited	(38,569	)	11.63
Non-vested at March 31, 2018	739,247		$	12.18

CVR Partners Long Term Incentive Plan

Share-Based Compensation

Schedule of share-based compensation activity

A summary of the phantom unit activity and changes under the CVR Partners LTIP during the three months ended March 31, 2018 is presented below:



	Phantom Units		Weighted-Average Grant-Date Fair Value
Non-vested at December 31, 2017	1,188,206		$	4.35
Granted	18,262		3.29
Vested	—		—
Forfeited	(23,320	)	4.26
Non-vested at March 31, 2018	1,183,148		$	4.34

CVR Refining Long Term Incentive Plan

Share-Based Compensation

Schedule of share-based compensation activity

A summary of phantom unit activity and changes under the CVR Refining LTIP during the three months ended March 31, 2018 is presented below:



	Phantom Units		Weighted-Average Grant-Date Fair Value
Non-vested at December 31, 2017	986,480		$	12.03
Granted	6,658		15.02
Vested	—		—
Forfeited	(7,835	)	12.37
Non-vested at March 31, 2018	985,303		$	12.05

Inventories (Tables)

3 Months Ended

Mar. 31, 2018

Inventory Disclosure [Abstract]

Schedule of inventories

Inventories consisted of the following:



	March 31, 2018		December 31, 2017
	(in millions)
Finished goods	$	177.5	$	172.0
Raw materials and precious metals	133.6		113.8
In-process inventories	36.3		22.4
Parts and supplies	77.0		77.0
Total Inventories	$	424.4	$	385.2

Property, Plant and Equipment (Tables)

3 Months Ended

Mar. 31, 2018

Property, Plant and Equipment [Abstract]

Summary of property, plant and equipment

Property, plant and equipment consisted of the following:



	March 31, 2018		December 31, 2017
	(in millions)
Land and improvements	$	47.4	$	47.4
Buildings	83.9		83.3
Machinery and equipment	3,741.4		3,733.8
Automotive equipment	24.8		24.7
Furniture and fixtures	33.0		32.4
Leasehold improvements	4.6		4.6
Aircraft	3.6		3.6
Railcars	16.8		16.8
Construction in progress	64.7		56.2
	4,020.2		4,002.8
Less: Accumulated depreciation	1,482.6		1,431.0
Total property, plant and equipment, net	$	2,537.6	$	2,571.8

Long-Term Debt (Tables)

3 Months Ended

Mar. 31, 2018

Debt Disclosure [Abstract]

Schedule of long-term debt

Long-term debt consisted of the following:



	March 31, 2018			December 31, 2017
	(in millions)
6.5% Senior Notes due 2022	$	500.0		$	500.0
9.25% Senior Secured Notes due 2023	645.0			645.0
6.5% Senior Notes due 2021	2.2			2.2
Capital lease obligations	44.5			45.0
Total debt	1,191.7			1,192.2
Unamortized debt issuance cost	(11.7		)	(12.2		)
Unamortized debt discount	(13.0		)	(13.5		)
Current portion of capital lease obligations	(2.2		)	(2.1		)
Long-term debt, net of current portion	$	1,164.8		$	1,164.4

- 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 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 2: 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=84159872&loc=d3e21475-112644

Reference 3: 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=75038535&loc=d3e64711-112823

Reference 4: 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=26873400&loc=d3e23780-122690

Reference 5: 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=64930739&loc=d3e28878-108400

Reference 6: 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=84159872&loc=d3e21538-112644

Reference 7: 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=84159872&loc=d3e21506-112644

Reference 8: 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=64930785&loc=d3e28541-108399

Reference 9: 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=64930785&loc=d3e28551-108399

Reference 10: 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=84159872&loc=d3e21521-112644

+ Details

Earnings Per Share (Tables)

3 Months Ended

Mar. 31, 2018

Earnings Per Share [Abstract]

Components of the basic and diluted earnings (loss) per share calculation

The components of the basic and diluted earnings per share calculation are as follows:



	Three Months Ended March 31,
	2018		2017
	(in millions, except per share data)
Net income attributable to CVR Energy stockholders	$	66.2	$	22.2

Weighted-average shares of common stock outstanding - Basic and diluted	86.8		86.8

Basic and diluted earnings per share	$	0.76	$	0.26

Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2018

Commitments and Contingencies Disclosure [Abstract]

Minimum required payments for CVR's lease agreements and unconditional purchase obligations

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



	Operating Leases		Unconditional Purchase Obligations⁽¹⁾
	(in millions)
Nine Months Ending December 31, 2018	$	5.9	$	117.2
Year Ending December 31,
2019	7.0		125.1
2020	6.4		99.7
2021	5.8		88.7
2022	5.4		84.2
Thereafter	3.7		538.8
	$	34.2	$	1,053.7

(1)

Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2018

Fair Value Disclosures [Abstract]

Assets and liabilities measured at fair value on a recurring basis

The following tables set forth the assets and liabilities measured at fair value on a recurring basis, by input level, as of March 31, 2018 and December 31, 2017:



	March 31, 2018
Location and Description	Level 1		Level 2			Level 3		Total
	(in millions)
Cash equivalents	$	15.3	$	—		$	—	$	15.3
Other current assets (investments)	0.1		—			—		0.1
Other current assets (commodity derivatives)	—		3.1			—		3.1
Total Assets	$	15.4	$	3.1		$	—	$	18.5
Other current liabilities (commodity derivatives)	$	—	$	(21.8	)	$	—	$	(21.8	)
Other current liabilities (biofuel blending obligation)	—		(19.5		)	—		(19.5		)
Total Liabilities	$	—	$	(41.3	)	$	—	$	(41.3	)



	December 31, 2017
Location and Description	Level 1		Level 2			Level 3		Total
	(in millions)
Cash equivalents	$	15.2	$	—		$	—	$	15.2
Other current assets (investments)	0.1		—			—		0.1
Total Assets	$	15.3	$	—		$	—	$	15.3
Other current liabilities (commodity derivatives)	$	—	$	(64.3	)	$	—	$	(64.3	)
Other long-term liabilities (biofuel blending obligation)	—		(1.0		)	—		(1.0		)
Total Liabilities	$	—	$	(65.3	)	$	—	$	(65.3	)

Derivative Financial Instruments (Tables)

3 Months Ended

Mar. 31, 2018

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Loss on derivatives, net and current period settlements

Current period settlements on derivative contracts and Gain on derivatives, net were as follows:



	Three Months Ended March 31,
	2018		2017
	(in millions)
Current period settlements on derivative contracts	$	13.7	$	1.2
Gain on derivatives, net	59.3		12.2

Derivative offsetting liabilities



	As of March 31, 2018
Description	Gross Current Assets			Gross Amounts Offset			Net Current Assets Presented			Cash Collateral Not Offset		Net Amount
	(in millions)
Commodity Derivatives	$	8.0		$	(4.9	)	$	3.1		$	—	$	3.1
Total	$	8.0		$	(4.9	)	$	3.1		$	—	$	3.1

	As of March 31, 2018
Description	Gross Current Liabilities			Gross Amounts Offset			Net Current Liabilities Presented			Cash Collateral Not Offset		Net Amount
	(in millions)
Commodity Derivatives	$	(26.7	)	$	4.9		$	(21.8	)	$	—	$	(21.8	)
Total	$	(26.7	)	$	4.9		$	(21.8	)	$	—	$	(21.8	)



	As of December 31, 2017
Description	Gross Current Assets		Gross Amounts Offset			Net Current Assets Presented		Cash Collateral Not Offset		Net Amount
	(in millions)
Commodity Derivatives	$	7.0	$	(7.0	)	$	—	$	—	$	—
Total	$	7.0	$	(7.0	)	$	—	$	—	$	—

	As of December 31, 2017
Description	Gross Current Liabilities		Gross Amounts Offset			Net Current Liabilities Presented		Cash Collateral Not Offset		Net Amount
	(in millions)
Commodity Derivatives	$	71.3	$	(7.0	)	$	64.3	$	—	$	64.3
Total	$	71.3	$	(7.0	)	$	64.3	$	—	$	64.3

Derivative offsetting assets



	As of March 31, 2018
Description	Gross Current Assets			Gross Amounts Offset			Net Current Assets Presented			Cash Collateral Not Offset		Net Amount
	(in millions)
Commodity Derivatives	$	8.0		$	(4.9	)	$	3.1		$	—	$	3.1
Total	$	8.0		$	(4.9	)	$	3.1		$	—	$	3.1

	As of March 31, 2018
Description	Gross Current Liabilities			Gross Amounts Offset			Net Current Liabilities Presented			Cash Collateral Not Offset		Net Amount
	(in millions)
Commodity Derivatives	$	(26.7	)	$	4.9		$	(21.8	)	$	—	$	(21.8	)
Total	$	(26.7	)	$	4.9		$	(21.8	)	$	—	$	(21.8	)



	As of December 31, 2017
Description	Gross Current Assets		Gross Amounts Offset			Net Current Assets Presented		Cash Collateral Not Offset		Net Amount
	(in millions)
Commodity Derivatives	$	7.0	$	(7.0	)	$	—	$	—	$	—
Total	$	7.0	$	(7.0	)	$	—	$	—	$	—

	As of December 31, 2017
Description	Gross Current Liabilities		Gross Amounts Offset			Net Current Liabilities Presented		Cash Collateral Not Offset		Net Amount
	(in millions)
Commodity Derivatives	$	71.3	$	(7.0	)	$	64.3	$	—	$	64.3
Total	$	71.3	$	(7.0	)	$	64.3	$	—	$	64.3

Business Segments (Tables)

3 Months Ended

Mar. 31, 2018

Segment Reporting [Abstract]

Operating results and capital expenditures information by segment

The following table summarizes certain operating results and capital expenditures information by segment:



	Three Months Ended March 31,
	2018			2017
	(in millions)
Net sales
Petroleum	$	1,458.2		$	1,423.5
Nitrogen Fertilizer	79.9			85.3
Intersegment elimination	(1.6		)	(1.7		)
Total	$	1,536.5		$	1,507.1
Cost of materials and other
Petroleum	$	1,217.7		$	1,201.3
Nitrogen Fertilizer	22.3			21.8
Intersegment elimination	(1.7		)	(1.9		)
Total	$	1,238.3		$	1,221.2
Direct operating expenses (exclusive of depreciation and amortization)
Petroleum	$	93.0		$	102.1
Nitrogen Fertilizer	38.9			35.9
Other	—			0.1
Total	$	131.9		$	138.1
Depreciation and amortization
Petroleum	$	33.7		$	34.1
Nitrogen Fertilizer	16.4			15.4
Other	1.8			1.6
Total	$	51.9		$	51.1
Operating income (loss)
Petroleum	$	97.2		$	66.0
Nitrogen Fertilizer	(3.4		)	5.3
Other	(3.3		)	(3.7		)
Total	$	90.5		$	67.6
Capital expenditures
Petroleum	$	16.0		$	19.6
Nitrogen Fertilizer	2.7			4.1
Other	1.3			0.5
Total	$	20.0		$	24.2



	As of March 31, 2018		As of December 31, 2017
	(in millions)
Total assets
Petroleum	$	2,295.3	$	2,269.9
Nitrogen Fertilizer	1,239.5		1,234.3
Other	288.5		302.5
Total	$	3,823.3	$	3,806.7
Goodwill
Petroleum	$	—	$	—
Nitrogen Fertilizer	41.0		41.0
Other	—		—
Total	$	41.0	$	41.0

Organization and Basis of Presentation (Details) - segment	3 Months Ended	18 Months Ended
	Mar. 31, 2018	Sep. 30, 2017
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Number of reportable segments	2
CVR Partners, LP
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of limited partner interest held by the public		66.00%
CVR GP, LLC
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of common units owned by limited partner	100.00%
CVR Refining, LP \| Second Underwritten Offering
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of limited partner interest held by the public	34.00%
IEP Energy LLC
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Ownership percentage held by controlling stockholder	82.00%
IEP Energy LLC \| CVR Refining, LP \| Second Underwritten Offering
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of limited partner interest held by the public	3.90%
CVR Refining Holdings LLC \| CVR Refining, LP \| Second Underwritten Offering
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of common units owned by CRLLC or CVR Refining Holdings	66.00%
CVR Refining Holdings LLC \| CVR Refining GP, LLC \| Second Underwritten Offering
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of common units owned by limited partner	100.00%

Recent Accounting Pronouncements (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Jan. 01, 2018	Dec. 31, 2017
Assets
Accounts Receivable	$ 179.3		$ 31.2	$ 178.7
Liabilities
Deferred Revenue	24.2		34.3	$ 12.9
Revenues
Net sales	1,536.5	$ 1,507.1
Operating Costs and Expenses
Cost of materials and other	1,238.3	$ 1,221.2
Balances Without Adoption of ASC 606
Assets
Accounts Receivable	178.6
Liabilities
Deferred Revenue	23.5
Revenues
Net sales	1,536.3
Operating Costs and Expenses
Cost of materials and other	1,238.1
Effect of Change \| ASU 2014-09
Assets
Accounts Receivable	0.7		21.4
Liabilities
Deferred Revenue	0.7		$ 21.4
Revenues
Net sales	0.2
Operating Costs and Expenses
Cost of materials and other	$ 0.2

Revenue - Revenue Disaggregated by Major Product (Details) $ in Millions	3 Months Ended
	Mar. 31, 2018 USD ($)
Disaggregation of Revenue [Line Items]
Total revenue	$ 1,536.5
Gasoline
Disaggregation of Revenue [Line Items]
Total revenue	711.7
Distillates
Disaggregation of Revenue [Line Items]
Total revenue	652.2
Ammonia
Disaggregation of Revenue [Line Items]
Total revenue	11.6
UAN
Disaggregation of Revenue [Line Items]
Total revenue	52.8
Urea products
Disaggregation of Revenue [Line Items]
Total revenue	4.9
Freight revenue
Disaggregation of Revenue [Line Items]
Total revenue	14.2
Other product sales
Disaggregation of Revenue [Line Items]
Total revenue	87.6
Revenue from product sales
Disaggregation of Revenue [Line Items]
Total revenue	1,535.0
Other revenue
Disaggregation of Revenue [Line Items]
Total revenue	1.5
Petroleum \| Revenue from product sales
Disaggregation of Revenue [Line Items]
Total revenue	1,456.7
Operating Segments \| Petroleum
Disaggregation of Revenue [Line Items]
Total revenue	1,458.2
Operating Segments \| Petroleum \| Gasoline
Disaggregation of Revenue [Line Items]
Total revenue	711.7
Operating Segments \| Petroleum \| Distillates
Disaggregation of Revenue [Line Items]
Total revenue	652.2
Operating Segments \| Petroleum \| Ammonia
Disaggregation of Revenue [Line Items]
Total revenue	0.0
Operating Segments \| Petroleum \| UAN
Disaggregation of Revenue [Line Items]
Total revenue	0.0
Operating Segments \| Petroleum \| Urea products
Disaggregation of Revenue [Line Items]
Total revenue	0.0
Operating Segments \| Petroleum \| Freight revenue
Disaggregation of Revenue [Line Items]
Total revenue	5.5
Operating Segments \| Petroleum \| Other product sales
Disaggregation of Revenue [Line Items]
Total revenue	87.3
Operating Segments \| Petroleum \| Other revenue
Disaggregation of Revenue [Line Items]
Total revenue	1.5
Operating Segments \| Nitrogen Fertilizer
Disaggregation of Revenue [Line Items]
Total revenue	79.9
Operating Segments \| Nitrogen Fertilizer \| Gasoline
Disaggregation of Revenue [Line Items]
Total revenue	0.0
Operating Segments \| Nitrogen Fertilizer \| Distillates
Disaggregation of Revenue [Line Items]
Total revenue	0.0
Operating Segments \| Nitrogen Fertilizer \| Ammonia
Disaggregation of Revenue [Line Items]
Total revenue	11.6
Operating Segments \| Nitrogen Fertilizer \| UAN
Disaggregation of Revenue [Line Items]
Total revenue	52.8
Operating Segments \| Nitrogen Fertilizer \| Urea products
Disaggregation of Revenue [Line Items]
Total revenue	4.9
Operating Segments \| Nitrogen Fertilizer \| Freight revenue
Disaggregation of Revenue [Line Items]
Total revenue	8.7
Operating Segments \| Nitrogen Fertilizer \| Other product sales
Disaggregation of Revenue [Line Items]
Total revenue	1.9
Operating Segments \| Nitrogen Fertilizer \| Revenue from product sales
Disaggregation of Revenue [Line Items]
Total revenue	79.9
Operating Segments \| Nitrogen Fertilizer \| Other revenue
Disaggregation of Revenue [Line Items]
Total revenue	0.0
Other / Eliminations
Disaggregation of Revenue [Line Items]
Total revenue	(1.6)
Other / Eliminations \| Gasoline
Disaggregation of Revenue [Line Items]
Total revenue	0.0
Other / Eliminations \| Distillates
Disaggregation of Revenue [Line Items]
Total revenue	0.0
Other / Eliminations \| Ammonia
Disaggregation of Revenue [Line Items]
Total revenue	0.0
Other / Eliminations \| UAN
Disaggregation of Revenue [Line Items]
Total revenue	0.0
Other / Eliminations \| Urea products
Disaggregation of Revenue [Line Items]
Total revenue	0.0
Other / Eliminations \| Freight revenue
Disaggregation of Revenue [Line Items]
Total revenue	0.0
Other / Eliminations \| Other product sales
Disaggregation of Revenue [Line Items]
Total revenue	(1.6)
Other / Eliminations \| Revenue from product sales
Disaggregation of Revenue [Line Items]
Total revenue	(1.6)
Other / Eliminations \| Other revenue
Disaggregation of Revenue [Line Items]
Total revenue	$ 0.0

Revenue - Additional information (Details) $ in Millions	3 Months Ended
Revenue - Additional information (Details) $ in Millions	Mar. 31, 2018 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 13.3
Petroleum \| Minimum
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Payment terms	2 days
Petroleum \| Maximum
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Payment terms	32 days
Nitrogen Fertilizer \| Minimum
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Payment terms	15 days
Nitrogen Fertilizer \| Maximum
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Payment terms	30 days

Revenue - Remaining Performance Obligation (Details)	3 Months Ended
Revenue - Remaining Performance Obligation (Details)	Mar. 31, 2018
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, percentage	64.00%
Remaining performance obligation, expected timing of satisfaction, period	1 year 9 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-12-31
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, percentage	22.00%
Remaining performance obligation, expected timing of satisfaction, period	1 year

Revenue - Deferred Revenue (Details) $ in Millions	3 Months Ended
Revenue - Deferred Revenue (Details) $ in Millions	Mar. 31, 2018 USD ($)
Change in Contract with Customer, Liability [Roll Forward]
Balance at January 1, 2018	$ 34.2
New prepay contracts entered into during the period	3.4
Revenue recognized that was included in the contract liability balance at the beginning of the period	11.6
Revenue recognized related to contracts entered into during the period	1.7
Other changes	0.1
Balance at March 31, 2018	$ 24.2

Share-Based Compensation - Long-Term Incentive Plan, CVR Energy (Details)		3 Months Ended	12 Months Ended
	Nov. 01, 2017 USD ($) trading_day $ / shares shares	Mar. 31, 2018 USD ($) shares	Dec. 31, 2017 USD ($)
Share-Based Compensation
Personnel accruals		$ 27,700,000	$ 55,900,000
CVR Energy Long Term Incentive Plan
Share-Based Compensation
Common stock authorized for issuance (in shares) \| shares		7,500,000
CVR Energy Long Term Incentive Plan \| Stock Options
Share-Based Compensation
Common stock authorized for issuance (in shares) \| shares		1,000,000
Chief Executive Officer \| 2016 Performance Unit Award Agreement \| Performance Unit Awards
Share-Based Compensation
Compensation expense (benefit)			1,800,000
Personnel accruals			1,800,000
Share-based compensation costs paid		$ 1,800,000
Chief Executive Officer \| 2017 Performance Unit Agreement \| Performance Unit Awards
Share-Based Compensation
Awards granted (in shares) \| shares	1,500
Cash amount granted per unit of performance factor achieved	$ 1,000
Compensation expense (benefit)		400,000
Personnel accruals		400,000
Chief Executive Officer \| 2017 Performance Unit Award Agreement \| Performance Unit Awards
Share-Based Compensation
Compensation expense (benefit)		600,000
Personnel accruals		$ 600,000
Maximum cash payment	$ 10,000,000.0
Period for determination of cash payment value \| trading_day	30
Maximum price per share to trigger maximum cash payment (in dollars per share) \| $ / shares	$ 60
Unrecognized compensation expense			$ 9,400,000
Weighted-average period for amortization of unrecognized compensation cost			3 years 9 months 18 days

Share-Based Compensation - Long-Term Incentive Plan, CVR Partners (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Mar. 31, 2018	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2017
Share-Based Compensation
Personnel accruals	$ 27.7			$ 55.9
CVR Partners Long Term Incentive Plan \| CVR Partners, LP
Share-Based Compensation
Common stock authorized for issuance (in shares)	5,000,000
Common stock available for issuance (in shares)	4,820,215
Number of share right to receive cash payment on vesting equal to fair market value is received per award (in shares)	1
CVR Partners Long Term Incentive Plan \| CVR Partners, LP \| Phantom Units
Share-Based Compensation
Vesting period	3 years
Unrecognized compensation expense	$ 2.4
Weighted-average period for amortization of unrecognized compensation cost	1 year 6 months
CVR Partners Long Term Incentive Plan \| CVR Partners, LP \| Phantom Units \| Tranche One
Share-Based Compensation
Vesting rights percentage	33.33%
CVR Partners Long Term Incentive Plan \| CVR Partners, LP \| Phantom Units \| Tranche Two
Share-Based Compensation
Vesting rights percentage	33.33%
CVR Partners Long Term Incentive Plan \| CVR Partners, LP \| Phantom Units \| Tranche Three
Share-Based Compensation
Vesting rights percentage	33.33%
CVR Partners Long Term Incentive Plan \| CVR Partners, LP \| Phantom Unit and Common Units
Share-Based Compensation
Compensation expense (benefit)		$ 0.4	$ 0.3
CVR Partners Long Term Incentive Plan \| CVR Partners, LP \| Phantom Unit and Common Units \| Personnel Accruals
Share-Based Compensation
Personnel accruals	$ 1.1			$ 0.7

Share-Based Compensation - Summary of Phantom Unit Activity and Changes Under CVR Partners LTIP (Details) - CVR Partners, LP - CVR Partners Long Term Incentive Plan - Phantom Units	3 Months Ended
	Mar. 31, 2018 $ / shares shares
Phantom Units
Non-vested at the beginning of the period (in shares) \| shares	1,188,206
Granted (in shares) \| shares	18,262
Vested (in shares) \| shares	0
Forfeited (in shares) \| shares	(23,320)
Non-vested at the end of the period (in shares) \| shares	1,183,148
Weighted-Average Grant-Date Fair Value
Non-vested at the beginning of the period (in dollars per share) \| $ / shares	$ 4.35
Granted (in dollars per share) \| $ / shares	3.29
Vested (in dollars per share) \| $ / shares	0.00
Forfeited (in dollars per share) \| $ / shares	4.26
Non-vested at the end of the period (in dollars per share) \| $ / shares	$ 4.34

Share-Based Compensation - Long-Term Incentive Plan, CVR Refining (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Mar. 31, 2018	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2017
Share-Based Compensation
Personnel accruals	$ 27.7			$ 55.9
CVR Refining, LP \| CVR Refining Long Term Incentive Plan
Share-Based Compensation
Common stock authorized for issuance (in shares)	11,070,000
Vesting period	3 years
Number of share right to receive cash payment on vesting equal to fair market value is received per award (in shares)	1
CVR Refining, LP \| CVR Refining Long Term Incentive Plan \| Phantom Unit Plan
Share-Based Compensation
Unrecognized compensation expense	$ 8.7
Weighted-average period for amortization of unrecognized compensation cost	1 year 5 months
Compensation expense (benefit)		$ 0.8	$ 1.0
CVR Refining, LP \| CVR Refining Long Term Incentive Plan \| Phantom Unit Plan \| Personnel Accruals
Share-Based Compensation
Personnel accruals	$ 4.6			$ 3.7
CVR Refining, LP \| CVR Refining Long Term Incentive Plan \| Tranche One
Share-Based Compensation
Vesting rights percentage	33.33%
CVR Refining, LP \| CVR Refining Long Term Incentive Plan \| Tranche Two
Share-Based Compensation
Vesting rights percentage	33.33%
CVR Refining, LP \| CVR Refining Long Term Incentive Plan \| Tranche Three
Share-Based Compensation
Vesting rights percentage	33.33%

Share-Based Compensation - Summary of Phantom Unit Activity and Changes Under CVR Refining LTIP (Details) - CVR Refining, LP - CVR Refining Long Term Incentive Plan - Phantom Unit Plan	3 Months Ended
	Mar. 31, 2018 $ / shares shares
Phantom Units
Non-vested at the beginning of the period (in shares) \| shares	986,480
Granted (in shares) \| shares	6,658
Vested (in shares) \| shares	0
Forfeited (in shares) \| shares	(7,835)
Non-vested at the end of the period (in shares) \| shares	985,303
Weighted-Average Grant-Date Fair Value
Non-vested at the beginning of the period (in dollars per share) \| $ / shares	$ 12.03
Granted (in dollars per share) \| $ / shares	15.02
Vested (in dollars per share) \| $ / shares	0.00
Forfeited (in dollars per share) \| $ / shares	12.37
Non-vested at the end of the period (in dollars per share) \| $ / shares	$ 12.05

Share-Based Compensation - Incentive Unit Awards (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Share-Based Compensation
Personnel accruals	$ 27.7		$ 55.9
Incentive Unit Award
Share-Based Compensation
Vesting period	3 years
Number of share right to receive cash payment on vesting equal to fair market value is received per award (in shares)	1
Unrecognized compensation expense	$ 4.0
Weighted-average period for amortization of unrecognized compensation cost	1 year 5 months
Compensation expense (benefit)	$ (0.7)	$ 1.2
Incentive Unit Award \| Personnel Accruals
Share-Based Compensation
Personnel accruals	$ 2.5		$ 3.3
Incentive Unit Award \| Tranche One
Share-Based Compensation
Vesting rights percentage	33.33%
Incentive Unit Award \| Tranche Two
Share-Based Compensation
Vesting rights percentage	33.33%
Incentive Unit Award \| Tranche Three
Share-Based Compensation
Vesting rights percentage	33.33%

Share-Based Compensation - Summary of Incentive Unit Activity and Changes (Details) - Incentive Unit Award	3 Months Ended
	Mar. 31, 2018 $ / shares shares
Incentive Units
Non-vested at the beginning of the period (in shares) \| shares	779,261
Granted (in shares) \| shares	0
Vested (in shares) \| shares	(1,445)
Forfeited (in shares) \| shares	(38,569)
Non-vested at the end of the period (in shares) \| shares	739,247
Weighted-Average Grant-Date Fair Value
Non-vested at the beginning of the period (in dollars per share) \| $ / shares	$ 12.14
Granted (in dollars per share) \| $ / shares	0.00
Vested (in dollars per share) \| $ / shares	13.65
Forfeited (in dollars per share) \| $ / shares	11.63
Non-vested at the end of the period (in dollars per share) \| $ / shares	$ 12.18

Inventories (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Inventory Disclosure [Abstract]
Finished goods	$ 177.5	$ 172.0
Raw materials and precious metals	133.6	113.8
In-process inventories	36.3	22.4
Parts and supplies	77.0	77.0
Total Inventories	$ 424.4	$ 385.2

Property, Plant and Equipment (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Property, Plant, and Equipment
Total property, plant and equipment, gross	$ 4,020.2		$ 4,002.8
Less: Accumulated depreciation	1,482.6		1,431.0
Total property, plant and equipment, net	2,537.6		2,571.8
Capitalized interest	0.5	$ 0.3
Original carrying value of assets under capital lease obligations	24.8		24.8
Land and improvements
Property, Plant, and Equipment
Total property, plant and equipment, gross	47.4		47.4
Buildings
Property, Plant, and Equipment
Total property, plant and equipment, gross	83.9		83.3
Machinery and equipment
Property, Plant, and Equipment
Total property, plant and equipment, gross	3,741.4		3,733.8
Automotive equipment
Property, Plant, and Equipment
Total property, plant and equipment, gross	24.8		24.7
Furniture and fixtures
Property, Plant, and Equipment
Total property, plant and equipment, gross	33.0		32.4
Leasehold improvements
Property, Plant, and Equipment
Total property, plant and equipment, gross	4.6		4.6
Aircraft
Property, Plant, and Equipment
Total property, plant and equipment, gross	3.6		3.6
Railcars
Property, Plant, and Equipment
Total property, plant and equipment, gross	16.8		16.8
Construction in progress
Property, Plant, and Equipment
Total property, plant and equipment, gross	$ 64.7		$ 56.2

Equity Method Investment (Details) bbl / d in Thousands, $ in Millions		1 Months Ended	3 Months Ended		6 Months Ended	12 Months Ended
	Sep. 19, 2016 bbl / d mi	Nov. 30, 2017 USD ($)	Mar. 31, 2018 USD ($) bbl / d	Mar. 31, 2017 USD ($)	Mar. 31, 2017 USD ($)	Dec. 31, 2017 USD ($)	Oct. 31, 2017 mi
Related Party Transaction [Line Items]
Equity method investments in affiliates of VIEs			$ 83.5			$ 82.8
Investment in joint venture			0.0	$ 1.4
Income from equity method investment			0.4
CVR Refining Limited Partnership [Member] \| Plains All American Pipeline, L.P. [Member] \| Midway Transportation Agreement
Related Party Transaction [Line Items]
Related party costs			$ 3.1
Transportation agreement, average barrels per day \| bbl / d			73
CRRM \| Velocity Central Oklahoma Pipeline LLC \| Velocity Transportation Agreement
Related Party Transaction [Line Items]
Initial term of agreement						20 years
Related party costs			$ 1.5
Transportation agreement, average barrels per day \| bbl / d			41
Due to related party			$ 0.5			$ 0.3
Velocity Pipeline Partners, LLC \| Coffeyville Resources Pipeline, LLC
Related Party Transaction [Line Items]
Pipeline capacity, barrels per day \| bbl / d	65
Joint venture interest			40.00%
Equity method investments in affiliates of VIEs			$ 6.1			6.1
Investment in joint venture					$ 7.0	1.4
Distribution received from equity method investment			$ 0.4
Velocity Pipeline Partners, LLC \| Velocity Central Oklahoma Pipeline LLC
Related Party Transaction [Line Items]
Joint venture interest held by others			60.00%
Midway Pipeline LLC
Related Party Transaction [Line Items]
Ownership percentage in joint venture							50.00%
Midway Pipeline LLC \| Coffeyville Resources Pipeline, LLC
Related Party Transaction [Line Items]
Joint venture interest			50.00%
Midway Pipeline LLC \| CVR Refining Limited Partnership [Member]
Related Party Transaction [Line Items]
Pipeline length (in miles) \| mi	25						100
Equity method investments in affiliates of VIEs			$ 77.3			$ 76.7
Investment in joint venture		$ 76.0
Income from equity method investment			1.1
Distribution received from equity method investment			$ 0.5

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended
Income Taxes (Details) - USD ($) $ in Millions	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Income Taxes [Line Items]
Due to related party	$ 14.3		$ 0.0
Unrecognized tax benefits	28.7
Unrecognized tax benefits which, if recognized, would impact the company's effective tax rate	22.7
Unrecognized tax benefits netted with deferred tax asset carryforwards	25.8
Accrued interest	$ 1.1
Effective tax rate	16.70%	27.90%
Federal and state combined statutory tax rate	26.10%	39.30%
AEPC
Income Taxes [Line Items]
Due to related party	$ 14.3

Long-Term Debt - Schedule of Debt (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Total debt	$ 1,191.7	$ 1,192.2
Unamortized debt issuance cost	(11.7)	(12.2)
Unamortized debt discount	(13.0)	(13.5)
Current portion of capital lease obligations	(2.2)	(2.1)
Long-term debt, net of current portion	1,164.8	1,164.4
Senior Notes \| 6.5% Senior Notes due 2022
Debt Instrument [Line Items]
Total debt	$ 500.0	500.0
Stated interest rate	6.50%
Senior Notes \| 9.25% Senior Secured Notes due 2023
Debt Instrument [Line Items]
Total debt	$ 645.0	645.0
Stated interest rate	9.25%
Senior Notes \| 6.5% Senior Notes due 2021
Debt Instrument [Line Items]
Total debt	$ 2.2	2.2
Stated interest rate	6.50%
Capital Lease Obligations
Debt Instrument [Line Items]
Total debt	$ 44.5	$ 45.0

Long-Term Debt - 2022 Senior Notes (Details) - Senior Notes - 6.5% Senior Notes due 2022	3 Months Ended
	Mar. 31, 2018 USD ($)	Oct. 23, 2012 USD ($)
Debt Instrument [Line Items]
Stated interest rate	6.50%
CVR Refining LLC
Debt Instrument [Line Items]
Debt instrument face amount	$ 500,000,000.0	$ 500,000,000.0
Stated interest rate		6.50%
Debt issuance costs		$ 8,700,000
Minimum percentage of holder to accelerate if in default	25.00%
Maximum fixed charge coverage ratio required to make restricted payments	2.5
Debt instrument, remaining restricted payments permitted	$ 100,000,000
CVR Refining LLC \| Level 2
Debt Instrument [Line Items]
Estimated fair value	$ 510,000,000

Long-Term Debt - Amended and Restated Asset Based (ABL) Credit Facility (Details) - Amended and Restated ABL Credit Facility	3 Months Ended
	Mar. 31, 2018 USD ($)	Nov. 14, 2017 USD ($)
Credit parties
Debt Instrument [Line Items]
Borrowing capacity		$ 400,000,000.0
Percentage threshold of borrowing base and total commitments for determination of unused capacity commitment fee	15.00%
Maximum fixed charge coverage ratio required to make restricted payments	1.00
Loan term	5 years
Percentage of maximum amount available to be drawn under line of credit deducted to compute fees on commercial letters of credit	0.50%
Letter of credit customary facing fees percentage	0.125%
CVR Refining, LP
Debt Instrument [Line Items]
Aggregate availability	$ 297,900,000
Outstanding letters of credit	6,400,000
Borrowings outstanding	$ 0
Letter of Credit \| Credit parties
Debt Instrument [Line Items]
Borrowing capacity		60,000,000.0
Bridge Loan \| Credit parties
Debt Instrument [Line Items]
Borrowing capacity		$ 40,000,000.0
Quarterly Average Excess Availability Exceeding 50% of Lesser of Borrowing Base and Total Commitments \| Credit parties
Debt Instrument [Line Items]
Percentage threshold of borrowing base and total commitments for determination of unused capacity commitment fee	50.00%
Threshold of borrowing base and total commitments for determination of interest rate, percentage	50.00%
Quarterly Average Excess Availability Exceeding 50% of Lesser of Borrowing Base and Total Commitments \| LIBOR \| Credit parties
Debt Instrument [Line Items]
Basis spread on variable rate	1.50%
Quarterly Average Excess Availability Exceeding 50% of Lesser of Borrowing Base and Total Commitments \| Prime Rate \| Credit parties
Debt Instrument [Line Items]
Basis spread on variable rate	0.50%
Quarterly Average Excess Availability Less than or Equal to 50% of Lesser of Borrowing Base and Total Commitments \| Credit parties
Debt Instrument [Line Items]
Percentage threshold of borrowing base and total commitments for determination of unused capacity commitment fee	50.00%
Threshold of borrowing base and total commitments for determination of interest rate, percentage	50.00%
Quarterly Average Excess Availability Less than or Equal to 50% of Lesser of Borrowing Base and Total Commitments \| LIBOR \| Credit parties
Debt Instrument [Line Items]
Basis spread on variable rate	1.75%
Quarterly Average Excess Availability Less than or Equal to 50% of Lesser of Borrowing Base and Total Commitments \| Prime Rate \| Credit parties
Debt Instrument [Line Items]
Basis spread on variable rate	0.75%
Daily Average Amount of Loans and Letters of Credit Outstanding Equal to or Greater than 50% of Lesser of Borrowing Base and Total Commitments \| Credit parties
Debt Instrument [Line Items]
Unused capacity, commitment fee percentage	0.25%
Daily Average Amount of Loans and Letters of Credit Outstanding Less than 50% of Lesser of Borrowing Base and Total Commitments \| Credit parties
Debt Instrument [Line Items]
Unused capacity, commitment fee percentage	0.375%

Long-Term Debt - 2023 Senior Notes (Details)	Jun. 10, 2016 USD ($)	Mar. 31, 2018 USD ($)	Dec. 31, 2017 USD ($)
Debt Instrument [Line Items]
Unamortized debt discount		$ 13,000,000	$ 13,500,000
Senior Notes \| 9.25% Senior Secured Notes due 2023
Debt Instrument [Line Items]
Stated interest rate		9.25%
Senior Notes \| 9.25% Senior Secured Notes due 2023 \| CVR Partners, LP
Debt Instrument [Line Items]
Debt instrument face amount	$ 645,000,000
Stated interest rate	9.25%
Unamortized debt discount	$ 16,100,000
Debt issuance costs	$ 9,400,000
Maximum fixed charge coverage ratio required to make restricted payments	1.75	1.75
Maximum aggregated restricted payments basket permitted	$ 75,000,000.0
Debt instrument, remaining restricted payments permitted		$ 72,700,000
Interest payable		17,600,000	2,700,000
Senior Notes \| 9.25% Senior Secured Notes due 2023 \| CVR Partners, LP \| Level 2
Debt Instrument [Line Items]
Fair value of debt		$ 686,700,000	$ 694,200,000

Long-Term Debt - 2021 Notes (Details) - Senior Notes - 6.5% Senior Notes due 2021 - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Stated interest rate	6.50%
CVR Partners, LP
Debt Instrument [Line Items]
Outstanding debt		$ 2.2
Interest payable	$ 0.0	$ 0.0

Long-Term Debt - ABL Credit Facility (Details) - Line of Credit - ABL Credit Facility - USD ($)	Sep. 30, 2016	Mar. 31, 2018	Mar. 31, 2017
Revolving Credit Facility
Line of Credit Facility [Line Items]
Debt Instrument, Sub-limit, Percent of Total Facility	10.00%
Revolving Credit Facility \| CVR Partners, LP
Line of Credit Facility [Line Items]
Borrowing capacity			$ 50,000,000
Permitted increase in borrowings			$ 25,000,000
Aggregate availability		$ 49,200,000
Borrowings outstanding		$ 0
Revolving Credit Facility \| CVR Partners, LP \| LIBOR
Line of Credit Facility [Line Items]
Basis spread on variable rate	2.00%
Revolving Credit Facility \| CVR Partners, LP \| Base Rate
Line of Credit Facility [Line Items]
Basis spread on variable rate	1.00%
Variable rate step-down	0.50%
Swingline Loan [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Face Amount	$ 5,000,000.0
Letter of Credit
Line of Credit Facility [Line Items]
Debt Instrument, Face Amount	$ 10,000,000.0

Long-Term Debt - Capital Lease Obligations (Details)	3 Months Ended
Long-Term Debt - Capital Lease Obligations (Details)	Mar. 31, 2018 lease
Debt Instrument [Line Items]
Number of leases	2
Capital Lease related to Excel Pipeline LLC
Debt Instrument [Line Items]
Remaining term of leases	139 months
Capital Lease related to Magellan Pipeline Terminals, L.P.
Debt Instrument [Line Items]
Remaining term of leases	138 months

Earnings Per Share (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Earnings Per Share [Abstract]
Net income attributable to CVR Energy stockholders	$ 66.2	$ 22.2
Weighted-average shares of common stock outstanding - Basic and diluted (in shares)	86,800,000	86,800,000
Basic and diluted earnings per share (in dollars per share)	$ 0.76	$ 0.26
Dilutive awards outstanding (in shares)	0	0

Commitments and Contingencies - Leases and Unconditional Purchase Obligations (Details) $ in Millions	3 Months Ended
	Mar. 31, 2018 USD ($) bbl / d	Mar. 31, 2017 USD ($)
Operating Leases
Nine Months Ending December 31, 2018	$ 5.9
2019	7.0
2020	6.4
2021	5.8
2022	5.4
Thereafter	3.7
Operating leases	34.2
Unconditional Purchase Obligations
Nine Months Ending December 31, 2018	117.2
2019	125.1
2020	99.7
2021	88.7
2022	84.2
Thereafter	538.8
Unconditional purchase obligations	1,053.7
Unrecorded purchase agreements
Lease expenses	1.9	$ 2.1
Expenses related to long-term commitments	48.5	$ 55.3
CRRM \| Petroleum transportation service agreement with TransCanada
Unrecorded purchase agreements
Amount payable related to petroleum transportation service agreements	$ 678.9
Term of agreement	13 years
Minimum quantity of crude oil to be received per day (in barrels) \| bbl / d	25,000
Period over which minimum quantity of crude oil is receivable	20 years

Commitments and Contingencies - Crude Oil Supply Agreement (Details) - CRRM - New Vitol Agreement	Aug. 31, 2012
Loss Contingencies [Line Items]
Renewal term of agreement	1 year
Notice of nonrenewal period prior to expiration	180 days

Commitments and Contingencies - Environmental, Health and Safety ("EHS") Matters (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Loss Contingencies [Line Items]
Environmental expenditures capitalized	$ 4.7	$ 4.7
EHS
Loss Contingencies [Line Items]
Environmental accruals	3.6		$ 3.9
RINs Asset	59.9
EHS \| CRRM
Loss Contingencies [Line Items]
Cost of renewable identification numbers expense	22.7	$ 6.4
Biofuel blending obligation recorded in other current liabilities	$ 21.4		$ 28.3

Commitments and Contingencies - Affiliate Pension Obligations (Details) $ in Millions	3 Months Ended
	Mar. 31, 2018 USD ($) sponsor	Dec. 31, 2017 USD ($)
Loss Contingencies [Line Items]
Minimum ownership interest in CVR Energy by Mr. Icahn's affiliates	80.00%
Number of sponsors of pension plans \| sponsor	2
Affiliate Pension Obligations
Loss Contingencies [Line Items]
Underfunded pension obligation, if ACF and Federal-Mogul plans were voluntarily terminated \| $	$ 417.1	$ 423.7
Majority Shareholder
Loss Contingencies [Line Items]
Ownership percentage held by controlling stockholder	82.00%

Fair Value Measurements - Assets and Liabilities Measured at Fair Value (Details) - Recurring - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Fair value measurements
Cash equivalents	$ 15.3	$ 15.2
Other current assets (investments)	0.1	0.1
Total Assets	18.5	15.3
Total Liabilities	(41.3)	(65.3)
Other derivative agreements
Fair value measurements
Other current assets (commodity derivatives)	3.1
Other current liabilities (other derivative agreements)	(21.8)	(64.3)
Biofuels blending obligation
Fair value measurements
Other liabilities (biofuel blending obligation)	(19.5)
Biofuel blending obligation and benzene obligation
Fair value measurements
Other liabilities (biofuel blending obligation)		(1.0)
Level 1
Fair value measurements
Cash equivalents	15.3	15.2
Other current assets (investments)	0.1	0.1
Total Assets	15.4	15.3
Total Liabilities	0.0	0.0
Level 1 \| Other derivative agreements
Fair value measurements
Other current assets (commodity derivatives)	0.0
Other current liabilities (other derivative agreements)	0.0	0.0
Level 1 \| Biofuels blending obligation
Fair value measurements
Other liabilities (biofuel blending obligation)	0.0
Level 1 \| Biofuel blending obligation and benzene obligation
Fair value measurements
Other liabilities (biofuel blending obligation)		0.0
Level 2
Fair value measurements
Cash equivalents	0.0	0.0
Other current assets (investments)	0.0	0.0
Total Assets	3.1	0.0
Total Liabilities	(41.3)	(65.3)
Level 2 \| Other derivative agreements
Fair value measurements
Other current assets (commodity derivatives)	3.1
Other current liabilities (other derivative agreements)	(21.8)	(64.3)
Level 2 \| Biofuels blending obligation
Fair value measurements
Other liabilities (biofuel blending obligation)	(19.5)
Level 2 \| Biofuel blending obligation and benzene obligation
Fair value measurements
Other liabilities (biofuel blending obligation)		(1.0)
Level 3
Fair value measurements
Cash equivalents	0.0	0.0
Other current assets (investments)	0.0	0.0
Total Assets	0.0	0.0
Total Liabilities	0.0	0.0
Level 3 \| Other derivative agreements
Fair value measurements
Other current assets (commodity derivatives)	0.0
Other current liabilities (other derivative agreements)	0.0	0.0
Level 3 \| Biofuels blending obligation
Fair value measurements
Other liabilities (biofuel blending obligation)	$ 0.0
Level 3 \| Biofuel blending obligation and benzene obligation
Fair value measurements
Other liabilities (biofuel blending obligation)		$ 0.0

Derivative Financial Instruments - Schedule of Gains (Losses) on Derivatives and Current Period Settlements (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Current period settlements on derivative contracts	$ 13.7	$ 1.2
Gain on derivatives, net	$ 59.3	$ 12.2

Derivative Financial Instruments - Additional Information (Details) bbl in Millions, $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2018 USD ($) bbl	Mar. 31, 2017 USD ($)	Dec. 31, 2017 USD ($) bbl
Derivative Financial Instruments
Gain on derivatives, net	$ 59.3	$ 12.2
CVR Refining, LP \| Commodity Derivatives
Derivative Financial Instruments
Derivative position, loss	0.2
Gain on derivatives, net	$ 0.2	(0.1)
CVR Refining, LP \| Crack Spreads \| Not Designated as Hedges
Derivative Financial Instruments
Number of barrels \| bbl			3.6
CVR Refining, LP \| 2-1-1 Crack Spreads \| Not Designated as Hedges
Derivative Financial Instruments
Number of barrels \| bbl	1.7		7.1
CVR Refining, LP \| Distillate Crack Spreads \| Not Designated as Hedges
Derivative Financial Instruments
Number of barrels \| bbl	0.6
CVR Refining, LP \| Gasoline Crack Spreads \| Not Designated as Hedges
Derivative Financial Instruments
Number of barrels \| bbl	0.6		3.6
CVR Refining, LP \| Derivative Canadian Crude Oil \| Not Designated as Hedges
Derivative Financial Instruments
Number of barrels \| bbl	4.2
CVR Refining, LP \| Commodity Swap, Not Considered Probable Of Settlement \| Not Designated as Hedges
Derivative Financial Instruments
Number of barrels \| bbl			5.8
CVR Refining, LP \| Commodity Derivatives
Derivative Financial Instruments
Gain on derivatives, net	$ 59.7	$ 12.3
CVR Refining, LP \| Commodity Derivatives \| Not Designated as Hedges
Derivative Financial Instruments
Derivative position, loss	18.5		$ 64.3
Other Current Assets \| CVR Refining, LP \| Commodity Derivatives \| Not Designated as Hedges
Derivative Financial Instruments
Derivative position, loss	3.1
Other Current Liabilities \| CVR Refining, LP \| Commodity Derivatives \| Not Designated as Hedges
Derivative Financial Instruments
Derivative position, loss	$ 21.6

Derivative Financial Instruments - Schedule of Offsetting Liabilities (Details) - CVR Refining, LP - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Current Assets
Offsetting assets
Gross Current Assets	$ 8.0	$ 7.0
Gross Amounts Offset	(4.9)	(7.0)
Net Current Assets Presented	3.1	0.0
Cash Collateral Not Offset	0.0	0.0
Net Amount	3.1	0.0
Current Assets \| Commodity Derivatives
Offsetting assets
Gross Current Assets	8.0	7.0
Gross Amounts Offset	(4.9)	(7.0)
Net Current Assets Presented	3.1	0.0
Cash Collateral Not Offset	0.0	0.0
Net Amount	3.1	0.0
Current Liabilities
Offsetting liabilities
Gross Current Liabilities	26.7	71.3
Gross Amounts Offset	(4.9)	(7.0)
Net Current Liabilities Presented	21.8	64.3
Cash Collateral Not Offset	0.0	0.0
Net Amount	21.8	64.3
Current Liabilities \| Commodity Derivatives
Offsetting liabilities
Gross Current Liabilities	26.7	71.3
Gross Amounts Offset	(4.9)	(7.0)
Net Current Liabilities Presented	21.8	64.3
Cash Collateral Not Offset	0.0	0.0
Net Amount	$ 21.8	$ 64.3

Related Party Transactions - Icahn Enterprises (Details) - USD ($) $ / shares in Units, $ in Millions		3 Months Ended
	Mar. 12, 2018	Mar. 31, 2018	Mar. 31, 2017
Related Party Transaction [Line Items]
Dividends paid (in dollars per share)	$ 0.50
Payments of dividends	$ 43.4	$ 43.4	$ 43.4
IEP Energy LLC
Related Party Transaction [Line Items]
Ownership percentage held by controlling stockholder		82.00%
Payments of dividends	$ 35.6

Related Party Transactions - Insight Portfolio Group (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Insight Portfolio Group LLC
Related Party Transaction [Line Items]
Related party payments	$ 0.2	$ 0.1

Related Party Transactions - Railcar Lease Agreements and Maintenance (Details) - Railcar Lease Agreement - CVR Partners, LP - American Railcar Leasing LLC $ in Millions	3 Months Ended
	Mar. 31, 2018 USD ($) railcar	Jun. 30, 2017 railcar	Mar. 31, 2017 USD ($)
Related Party Transaction [Line Items]
Number of railcars leased \| railcar	115
Number of railcars to be leased \| railcar		70
Rent expense \| $	$ 0.4		$ 0.2
Maintenance expense \| $			$ 0.2

Related Party Transactions - Additional Information (Details) - Coffeyville Resources Pipeline, LLC	Mar. 31, 2018
Velocity Pipeline Partners, LLC
Related Party Transaction [Line Items]
Joint venture interest	40.00%
Midway Pipeline LLC
Related Party Transaction [Line Items]
Joint venture interest	50.00%

Business Segments - Additional Information (Details)	3 Months Ended
Business Segments - Additional Information (Details)	Mar. 31, 2018 segment
Segment Reporting [Abstract]
Number of reportable segments	2

Business Segments - Summary of Operating Results and Capital Expenditures by Segment (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Segment Reporting Information [Line Items]
Net sales	$ 1,536.5	$ 1,507.1
Cost of materials and other	1,238.3	1,221.2
Direct operating expenses (exclusive of depreciation and amortization)	131.9	138.1
Depreciation and amortization	51.9	51.1
Operating income (loss)	90.5	67.6
Capital expenditures	20.0	24.2
Total assets	3,823.3		$ 3,806.7
Goodwill	41.0		41.0
Operating Segments \| Petroleum
Segment Reporting Information [Line Items]
Net sales	1,458.2	1,423.5
Cost of materials and other	1,217.7	1,201.3
Direct operating expenses (exclusive of depreciation and amortization)	93.0	102.1
Depreciation and amortization	33.7	34.1
Operating income (loss)	97.2	66.0
Capital expenditures	16.0	19.6
Total assets	2,295.3		2,269.9
Goodwill	0.0		0.0
Operating Segments \| Nitrogen Fertilizer
Segment Reporting Information [Line Items]
Net sales	79.9	85.3
Cost of materials and other	22.3	21.8
Direct operating expenses (exclusive of depreciation and amortization)	38.9	35.9
Depreciation and amortization	16.4	15.4
Operating income (loss)	(3.4)	5.3
Capital expenditures	2.7	4.1
Total assets	1,239.5		1,234.3
Goodwill	41.0		41.0
Intersegment elimination
Segment Reporting Information [Line Items]
Net sales	(1.6)	(1.7)
Cost of materials and other	(1.7)	(1.9)
Other
Segment Reporting Information [Line Items]
Direct operating expenses (exclusive of depreciation and amortization)	0.0	0.1
Depreciation and amortization	1.8	1.6
Operating income (loss)	(3.3)	(3.7)
Capital expenditures	1.3	$ 0.5
Total assets	288.5		302.5
Goodwill	$ 0.0		$ 0.0

Subsequent Events (Details) - USD ($) $ / shares in Units, $ in Millions			3 Months Ended
	May 14, 2018	Apr. 25, 2018	Mar. 31, 2018	Mar. 31, 2017
Subsequent Event [Line Items]
Dividends declared (in dollars per share)			$ 0.5	$ 0.5
Dividends declared			$ 43.4
Forecast
Subsequent Event [Line Items]
Proceeds from distribution	$ 49.6
IEP Energy LLC
Subsequent Event [Line Items]
Ownership percentage held by controlling stockholder			82.00%
Subsequent Event
Subsequent Event [Line Items]
Dividends declared (in dollars per share)		$ 0.50
Dividends declared		$ 43.4
Distributions declared (in dollars per share)		$ 0.51
Distributions declared		$ 75.3
Subsequent Event \| IEP Energy LLC \| IEP Energy LLC
Subsequent Event [Line Items]
Dividends declared	$ 35.6
Ownership percentage held by controlling stockholder	82.00%