CVR Energy (CVI) 10-K 21 Feb 19 2018 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Feb. 19, 2019	Jun. 29, 2018
Document and Entity Information
Entity Registrant Name	CVR ENERGY INC
Entity Central Index Key	1,376,139
Document Type	10-K
Document Period End Date	Dec. 31, 2018
Amendment Flag	false
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Entity Public Float			$ 578
Entity Common Stock, Shares Outstanding		100,530,599
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	FY

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents (including $415 and $223, respectively, of consolidated variable interest entities (VIEs))	$ 668	$ 482
Accounts receivable of VIEs	169	179
Inventories of VIEs	380	369
Prepaid expenses and other current assets (including $56 and $30, respectively, of VIEs)	76	48
Total current assets	1,293	1,078
Property, plant and equipment, net of accumulated depreciation (including $2,429 and $2,543, respectively, of VIEs)	2,445	2,588
Other long-term assets (including $162 and $137, respectively, of VIEs)	169	141
Total assets	3,907	3,807
Current liabilities:
Note payable and capital lease obligations of VIEs	3	2
Accounts payable (including $317 and $329, respectively, of VIEs)	320	334
Other current liabilities (including $154 and $181, respectively, of VIEs)	173	208
Total current liabilities	496	544
Long-term liabilities:
Long-term debt and capital lease obligations of VIEs, net of current portion	1,167	1,164
Deferred income taxes	362	386
Other long-term liabilities (including $7 and $4, respectively, of VIEs)	14	9
Total long-term liabilities	1,543	1,559
Commitments and contingencies (See Note 11)
CVR stockholders’ equity:
Common stock $0.01 par value per share, 350,000,000 shares authorized, 100,629,209 shares issued (86,929,660 shares issued as of December 31, 2017)	1	1
Additional paid-in-capital	1,473	1,197
Retained deficit	(226)	(277)
Treasury stock, 98,610 shares at cost	(2)	(2)
Total CVR stockholders’ equity	1,246	919
Noncontrolling interest	622	785
Total equity	1,868	1,704
Total liabilities and equity	$ 3,907	$ 3,807

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Cash and cash equivalents	$ 668	$ 482
Prepaid expenses and other current assets	76	48
Property, plant and equipment, net of accumulated depreciation	2,445	2,588
Other long-term assets	169	141
Accounts payable	320	334
Other current liabilities	173	208
Other long-term liabilities	$ 14	$ 9
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)	100,629,209	86,929,660
Treasury stock (in shares)	98,610	98,610
Variable Interest Entities
Cash and cash equivalents	$ 415	$ 223
Prepaid expenses and other current assets	56	30
Property, plant and equipment, net of accumulated depreciation	2,429	2,543
Other long-term assets	162	137
Accounts payable	317	329
Other current liabilities	154	181
Other long-term liabilities	$ 7	$ 4

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Millions, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Statement [Abstract]
Net sales	$ 1,737	$ 1,935	$ 1,915	$ 1,536	$ 1,593	$ 1,454	$ 1,434	$ 1,507	$ 7,124	$ 5,988	$ 4,782
Operating costs and expenses:
Cost of materials and other (exclusive of depreciation and amortization shown below)	1,387	1,556	1,560	1,179	1,366	1,149	1,229	1,209	5,683	4,953	3,867
Direct operating expenses (exclusive of depreciation and amortization shown below)	130	120	141	132	175	162	124	138	523	598	541
Depreciation and amortization									202	203	184
Cost of sales									6,408	5,754	4,592
Selling, general and administrative expenses									112	113	110
Depreciation and amortization									11	11	9
Loss on asset disposals									6	3	1
Operating income	138	179	121	150	(36)	61	1	80	587	107	70
Other income (expense):
Interest expense, net									(102)	(109)	(83)
Other income, net									15	2	2
Income (loss) before income taxes									500	0	(11)
Income tax expense (benefit)									89	(217)	(20)
Net income	106	121	80	104	173	25	(19)	38	411	217	9
Less: Net income (loss) attributable to noncontrolling interest	24	31	30	38	(27)	3	(8)	16	122	(18)	(16)
Net income attributable to CVR Energy stockholders	$ 82	$ 90	$ 50	$ 66	$ 200	$ 22	$ (11)	$ 22	$ 289	$ 235	$ 25
Basic and diluted earnings per share (in dollars per share)	$ 0.82	$ 0.94	$ 0.59	$ 0.76	$ 2.31	$ 0.26	$ (0.12)	$ 0.26	$ 3.12	$ 2.70	$ 0.28
Dividends declared per share (in dollars per share)	$ 0.75	$ 0.75	$ 0.5	$ 0.5	$ 0.5	$ 0.5	$ 0.5	$ 0.5	$ 2.5	$ 2	$ 2
Weighted-average common shares outstanding:
Basic and Diluted (in shares)	100.5	95.8	86.8	86.8	86.8	86.8	86.8	86.8	92.5	86.8	86.8

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total	CVR Partners	CVR Refining	Total CVR Stockholders’ Equity	Total CVR Stockholders’ EquityCVR Partners	Common Stock	Additional Paid-In Capital	Additional Paid-In CapitalCVR Partners	Retained Deficit	Treasury Stock	Noncontrolling Interest	Noncontrolling InterestCVR Partners	Noncontrolling InterestCVR Refining
Balance (in shares) at Dec. 31, 2015						86,929,660
Balance at Dec. 31, 2015	$ 1,600			$ 984		$ 1	$ 1,174		$ (189)	$ (2)	$ 616
Increase (Decrease) in Stockholders' Equity
Dividends paid to CVR Energy stockholders	(174)			(174)					(174)
Distributions to public unitholders		$ (41)										$ (41)
Impact of CVR Partners’ common units issuance for the East Dubuque Merger, net of tax of $20		316			$ 23			$ 23				293
Net income (loss)	9			25					25		(16)
Balance (in shares) at Dec. 31, 2016						86,929,660
Balance at Dec. 31, 2016	1,710			858		$ 1	1,197		(338)	(2)	852
Increase (Decrease) in Stockholders' Equity
Dividends paid to CVR Energy stockholders	(174)			(174)					(174)
Distributions to public unitholders		$ (2)	$ (47)									$ (2)	$ (47)
Net income (loss)	217			235					235		(18)
Balance (in shares) at Dec. 31, 2017						86,929,660
Balance at Dec. 31, 2017	1,704			919		$ 1	1,197		(277)	(2)	785
Increase (Decrease) in Stockholders' Equity
Exchange offer impact (in shares)						13,699,549
Exchange offer impact	84			276			276				(192)
Dividends paid to CVR Energy stockholders	(238)			(238)					(238)
Distributions to public unitholders			$ (93)								(93)
Net income (loss)	411			289					289		122
Balance (in shares) at Dec. 31, 2018						100,629,209
Balance at Dec. 31, 2018	$ 1,868			$ 1,246		$ 1	$ 1,473		$ (226)	$ (2)	$ 622

CONSOLIDATED STATEMENTS OF CH_2

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
CVR Partners
Issuance of common units, tax impact	$ 20

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Cash flows from operating activities:
Net income	$ 411	$ 217	$ 9
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	213	214	193
Deferred income taxes	59	(217)	(84)
Loss on asset disposals	6	3	1
Share-based compensation	16	19	9
Other items	3	7	6
Changes in assets and liabilities:
Accounts receivable	56	(27)	(48)
Inventories	(9)	(40)	(9)
Prepaid expenses and other current assets	(29)	34	(3)
Due to (from) parent	2	(16)	22
Accounts payable	(23)	87	(10)
Deferred revenue	11	1	(20)
Other current liabilities	(104)	(113)	203
Other long-term assets and liabilities	8	(1)	(2)
Net cash provided by operating activities	620	168	267
Cash flows from investing activities:
Capital expenditures	(102)	(120)	(133)
Acquisition of CVR Nitrogen, net of cash acquired	0	0	(64)
Investment in affiliates, net of return of investment	0	(76)	(5)
Other investing activities	2	0	1
Net cash provided by (used in) investing activities	(100)	(196)	(201)
Cash flows from financing activities:
Proceeds on issuance of 2023 Notes, net of original issue discount	0	0	629
Principal and premium payments on 2021 Notes	0	0	(322)
Payments of revolving debt	0	0	(49)
Principal payments on CRNF credit facility	0	0	(125)
Dividends to CVR Energy’s stockholders	(238)	(174)	(174)
Other financing activities	(3)	(3)	(12)
Net cash provided by (used in) financing activities	(334)	(226)	(95)
Net increase (decrease) in cash and cash equivalents	186	(254)	(29)
Cash and cash equivalents, beginning of period	482	736	765
Cash and cash equivalents, end of period	668	482	736
CVR Refining
Cash flows from investing activities:
Investment in affiliates, net of return of investment		(77)
Cash flows from financing activities:
Distributions to noncontrolling interest holders	(93)	(47)	0
CVR Partners
Cash flows from financing activities:
Distributions to noncontrolling interest holders	$ 0	$ (2)	$ (42)

Organization and Nature of Busi

Organization and Nature of Business	12 Months Ended
	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Nature of Business	(1) Organization and Nature of Business Organization CVR Energy, Inc. (“CVR Energy,” “CVR,” or the “Company”) 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 “CVRR”) and CVR Partners, LP (“CVR Partners”). CVR Refining is an independent petroleum refiner and marketer of high value transportation fuels. CVR Partners produces and markets nitrogen fertilizers in the form of urea ammonium nitrate (“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.” In August 2018, CVR Energy completed an exchange offer whereby public unitholders tendered a total of 21,625,106 CVR Refining common units in exchange for a total of 13,699,549 shares of CVR Energy common stock (the “CVRR Unit Exchange”). In connection with the CVRR Unit Exchange, the Company incurred a total of $0.7 million of issuance costs, which were capitalized to additional paid-in-capital. Further, due to the change in our ownership of CVR Refining, we recognized an increase of $276 million to additional paid-in-capital and $84 million in deferred tax assets. Following the CVRR Unit Exchange, Icahn Enterprises L.P. (“IEP”) and its affiliates owned approximately 71% of the Company’s outstanding common shares. CVR Refining, LP As of December 31, 2018 , public security holders held approximately 16% of CVR Refining’s common units that were traded on the NYSE under “CVRR” (including units owned by IEP and its affiliates, representing 3.9% of CVR Refining’s outstanding common units). The Company and CVR Refining Holdings, LLC (“CVR Refining Holdings”), an indirect wholly-owned subsidiary of CVR, owned 100% of CVR Refining’s general partner interest and approximately 81% of CVR Refining’s outstanding limited partner interests. The consolidated results of operations and financial position of CVR Refining are reflected as CVR’s petroleum segment (the “Petroleum Segment”). On January 17, 2019, the general partner of CVRR assigned to the Company its right to purchase all of the issued and outstanding CVRR common units not already owned by CVRR’s general partner or its affiliates. On January 29, 2019, the Company purchased all remaining CVRR common units not already owned by the Company or its affiliates for a cash purchase price of $10.50 per unit (the “Call Price”), or approximately $241 million in the aggregate (the “Public Unit Purchase”). In conjunction with the exercise of its call right for all CVRR common units not already owned by the Company or its affiliates, the Company entered into a purchase agreement with American Entertainment Properties Corporation (“AEP”) and IEP, pursuant to which, on January 29, 2019, all of the Common Units held by AEP and IEP were purchased by the Company for a cash price per unit equal to the Call Price, or approximately $60 million in the aggregate (the “Affiliate Unit Purchase” together with the Public Unit Purchase, the “CVRR Unit Purchase”). The total purchase price of $301 million was funded with approximately $105 million in borrowings under a new credit agreement entered into by the Company on January 29, 2019 with the remaining amount being funded from the Company’s cash on hand. Refer to Note 5 (“Long-Term Debt”) for further information on the credit agreement. Effective February 8, 2019, CVRR’s reporting obligations under the Exchange Act were suspended. Upon closing of the CVRR Unit Purchase, the Company executed a full and unconditional guarantee of CVRR’s senior notes due 2022 (the “2022 Senior Notes”). Pursuant to SEC regulations, the Company has elected to provide condensed consolidating financial statements in lieu of providing standalone CVRR financial statements. Refer to Note 14, (“Guarantor Financial Information”) for further discussion and the condensed consolidating financial statements. CVR Partners, LP As of December 31, 2018 , public security holders held approximately 66% of CVR Partners’ outstanding common units that are traded on the NYSE under “UAN.” Coffeyville Resources, LLC (“CRLLC”), a wholly-owned subsidiary of CVR Energy, held approximately 34% of CVR Partners’ outstanding common units. In addition, CRLLC owns 100% of CVR Partners’ general partner, CVR GP, LLC, which holds a general partner interest. The consolidated results of operations and financial position of CVR Partners are reflected as our nitrogen fertilizer segment (the “Nitrogen Fertilizer Segment”). Subsequent Events The Company evaluated subsequent events, if any, that would require an adjustment to the Company’s consolidated financial statements or require disclosure in the notes to the consolidated financial statements through the date of issuance of the consolidated financial statements. Where applicable, the notes to these consolidated financial statements have been updated to discuss all significant subsequent events which have occurred.

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2018
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	(2) Summary of Significant Accounting Policies Principles of Consolidation The accompanying consolidated financial statements include the accounts of the Company and its majority-owned direct and indirect subsidiaries. All intercompany accounts and transactions have been eliminated. The ownership interests of noncontrolling investors in the Company’s subsidiaries are recorded as noncontrolling interests. CVR Energy has not recognized any other comprehensive income for the periods ended December 31, 2018, 2017 and 2016. CVR Refining and CVR Partners are considered variable interest entities (“VIE”). As the 100% owner of the general partner for both CVR Refining and CVR Partners, the Company has the sole ability to direct the activities that most significantly impact the economic performance of both partnerships and is considered to be the primary beneficiary. In January 2019, following the CVRR Unit Purchase, CVR Refining is no longer considered to be a VIE, and will be accounted for as a wholly-owned subsidiary. Investments in entities over which the Company has significant influence, but not control, are accounted for using the equity method of accounting. Income from equity method investments represents CVR Energy’s proportionate share of net income generated by the equity method investees and is recorded in other income, net on the Company’s Consolidated Statements of Operations. Use of Estimates These consolidated financial statements are prepared in conformity with accounting principles generally accepted in the United States of America (“GAAP”), which requires management to make estimates and assumptions that affect the reported amounts and disclosure of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Estimates are reviewed on an ongoing basis, based on currently available information. Changes in facts and circumstances may result in revised estimates and actual results could differ from those estimates. Cash and Cash Equivalents Cash and cash equivalents include cash on hand and on deposit and investments in highly liquid money market accounts and debt instruments with original maturities of three months or less. Accounts Receivable, net Accounts receivable primarily consist of customer accounts receivable recorded at the invoiced amounts and generally do not bear interest. Also included within accounts receivable of the Nitrogen Fertilizer Segment are unbilled fixed price contracts recognized with the adoption of ASC 606 (defined below) as discussed further within the “Recent Accounting Pronouncements - Adoption of Revenue Recognition Standard” section to this note below. Allowances for doubtful accounts are generally recorded when it becomes probable the receivable will not be collected and is booked to bad debt expense. The largest concentration of credit for any one customer at December 31, 2018 and 2017 was approximately 12% and 11% , respectively, of the net accounts receivable balance. Inventories Inventories consist primarily of domestic and foreign crude oil, blending stock and components, work-in-progress, fertilizer products, and refined fuels and by-products. All inventories are valued at the lower of the first-in, first-out (“FIFO”) cost, or net realizable value. Refinery unfinished and finished products inventory values were determined using the ability-to-bear methodology. Other inventories, including other raw materials, spare parts, and supplies, are valued at the lower of moving-average cost, which approximates FIFO, or net realizable value. The cost of inventories includes inbound freight costs. At December 31, 2018 and 2017, inventories on the Consolidated Balance Sheets related to the Nitrogen Fertilizer segment included depreciation of approximately $6 million and $4 million , respectively. Inventories consisted of the following: December 31, (in millions) 2018 2017 Finished goods $ 186 $ 172 Raw materials 105 98 In-process inventories 12 22 Parts and supplies 77 77 Total Inventories $ 380 $ 369 Certain reclassifications have been made on the Consolidated Balance Sheets to reclassify precious metals from inventory to the property, plant and equipment financial statement line item in the amount of $15 million for the year ended December 31, 2018. The prior year balance of $16 million has been reclassified to conform with the current year presentation. Property, Plant and Equipment Additions to property, plant and equipment, including capitalized interest and certain costs allocable to construction and property purchases, are recorded at cost. Expenditures for improvements that increase economic benefit or returns and/or extend useful life are capitalized. Depreciation is computed using the straight-line method over the estimated useful lives of the various classes of depreciable assets. The lives used in computing depreciation for significant asset classes are as follows: Asset Range of Useful Lives, in Years Land improvements 15 to 30 Buildings 20 to 30 Machinery and equipment 5 to 30 Other 5 to 30 Property, plant and equipment consisted of the following: December 31, (in millions) 2018 2017 Land and improvements $ 43 $ 47 Buildings 82 83 Machinery and equipment 3,754 3,734 Other 203 155 4,082 4,019 Less: Accumulated depreciation 1,637 1,431 Total Property, plant and equipment, net $ 2,445 $ 2,588 Leasehold improvements and assets held under capital leases are depreciated or amortized on the straight-line method over the shorter of the contractual lease term or the estimated useful life of the asset. Expenditures for routine maintenance and repair costs are expensed when incurred. Such expenses are reported in direct operating expenses in the Company’s Consolidated Statements of Operations. During the period, the Petroleum Segment began actively marketing certain assets with a carrying value of $33 million at December 31, 2018. The carrying value of these assets held for sale were included in Other Long-term Assets on the Company’s Condensed Consolidated Balance Sheets. No loss has been recognized upon designation of these assets as held for sale. Deferred Financing Costs Lender and other third-party costs associated with debt issuances are deferred and amortized to interest expense and other financing costs using the effective-interest method over the life of the debt. Deferred financing costs related to line-of-credit arrangements are amortized using the straight-line method through the termination date of the facility. The deferred financing costs are included net within long-term debt and in other long-term assets for the line-of-credit arrangements where no debt balance exists. Impairment of Long-Lived Assets Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to estimated undiscounted future net cash flows expected to be generated by the asset. If the carrying amount of an asset exceeds its estimated undiscounted future net cash flows, an impairment charge is recognized for the amount by which the carrying amount of the assets exceeds their fair value. Assets to be disposed of by sale are reported at the lower of their carrying value or fair value less cost to sell. Goodwill represents the excess of the cost of an acquired entity over the fair value of the assets acquired less liabilities assumed. Intangible assets are assets that lack physical substance (excluding financial assets). Goodwill acquired in a business combination and intangible assets with indefinite useful lives are not amortized, and intangible assets with finite useful lives are amortized. Goodwill and intangible assets not subject to amortization are tested for impairment annually or more frequently if events or changes in circumstances indicate the asset might be impaired. November 1 of each year is used as the annual valuation date for its goodwill impairment test. The Company performed its annual impairment review of goodwill for 2018 , 2017 and 2016 and concluded there were no impairments. For the period ended December 31, 2017, the fair value of the Coffeyville, Kansas nitrogen fertilizer business (the “Coffeyville Fertilizer Facility”) reporting unit exceeded its carrying value by approximately 12% based upon the results of the Partnership’s goodwill impairment test. For the period ended December 31, 2018, due to improved market conditions and financial forecasts, the amount by which fair value exceeds the carrying value for the Coffeyville Fertilizer Facility reporting unit is significant. Loss Contingencies In the ordinary course of business, the Company may become party to lawsuits, administrative proceedings and governmental investigations, including environmental, regulatory and other matters. The outcome of these matters cannot always be predicted accurately, but the Company accrues liabilities for these matters if the Company has determined that it is probable a loss has been incurred and the loss can be reasonably estimated. Environmental, Health & Safety (“EHS”) Matters The Petroleum and Nitrogen Fertilizer Segments are subject to various 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, internal and third party assessments of contamination, available remediation technology, site-specific costs, and currently enacted laws and regulations. In reporting environmental liabilities, no offset is made for potential recoveries. Loss contingency accruals, including those for environmental remediation, are subject to revision as further information develops or circumstances change and such accruals can take into account the legal liability of other parties. Environmental expenditures are capitalized at the time of the expenditure when such costs provide future economic benefits. Revenue Recognition The Company recognizes revenue based on consideration specified in contracts or agreements with customers when performance obligations are satisfied by transferring control over products or services to a customer. The adoption of ASC 606, described below, did not materially change the Company’s revenue recognition patterns, which are described below by reportable segment: • Petroleum Segment - The vast majority of Petroleum Segment contracts contain pricing that is based on the market price for the product at the time of delivery. Obligations to deliver product volumes are typically satisfied and revenue is recognized when control of the product transfers to customers. Concurrent with the transfer of control, the right to payment for the delivered product is received, the customer accepts the product and the customer has significant risks and rewards of ownership of the product. Payment terms require customers to pay shortly after delivery and do not contain significant financing components. Any pass-through finished goods delivery costs reimbursed by customers are reported in net sales, while an offsetting expense is included in cost of materials and other. Non-monetary product exchanges and certain buy/sell transactions which are entered into in the normal course of business are included on a net cost basis in operating expenses on the Consolidated Statements of Operations. • Nitrogen Fertilizer Segment - Revenue is recognized when our customers receive control of the product. The adoption of ASC 606 resulted in the recognition of deferred revenue which represents customer prepayments under contracts that guarantee a price and supply of nitrogen fertilizer product in quantities expected to be delivered in the normal course of business. Other considerations - For both segments, excise and other taxes collected from customers and remitted to governmental authorities are excluded from reported revenues. Cost Classifications Cost of materials and other (exclusive of depreciation and amortization) includes cost of crude oil, other feedstocks, blendstocks, purchased refined products, pet coke expenses, renewable identification numbers (“RINs”) expenses, derivative gain or losses and freight and distribution costs. Direct operating expenses (exclusive of depreciation and amortization) consist primarily of energy and other utility costs, direct costs of labor, including applicable share-based compensation expense, property taxes, plant-related maintenance services, including turnaround, and environmental and safety compliance costs as well as catalyst and chemical costs. Selling, general and administrative expenses consist primarily of labor and other direct expenses associated with the Company’s corporate activities, including accounting, finance, information technology, human resources, legal and other related administrative functions. For the Company’s Nitrogen Fertilizer Segment, each of these financial statement line items are also impacted by changes in inventory balances. Certain reclassifications have been made within the Consolidated Statements of Operations to include gain (loss) on derivatives within the Cost of Materials and Other financial statement line item. Prior year balances have been reclassified to conform with the current years presentation. The reclassifications from gain (loss) on derivatives to cost of materials and other totaled $146 million , $(70) million , and $(20) million for the years ended December 31, 2018 , 2017 , and 2016 , respectively. Derivatives and Fair Value of Financial Instruments The Petroleum Segment uses futures contracts, options, and forward contracts primarily to reduce exposure to changes in crude oil and finished goods product prices to provide economic hedges of inventory positions. These derivative instruments do not qualify as hedges for hedge accounting purposes under ASC Topic 815, Derivatives and Hedging , and accordingly are recorded at fair value at the end of each reporting period based on quoted market prices. The Nitrogen Fertilizer Segment may enter into forward contracts with fixed delivery prices to purchase portions of its natural gas requirements. These natural gas contracts are not treated as derivative under normal purchase and normal sale exclusions. Accordingly, the fair value of these contracts are not recorded at the end of each reporting period. Refer to Note 7 (“Derivatives and Fair Value of Financial Instruments”) for further discussion of the Company’s derivative activity. Other financial instruments consisting of cash and cash equivalents, accounts receivable, and accounts payable are carried at cost, which approximates fair value, as a result of the short-term nature of the instruments. Refer to Note 7 (“Derivatives and Fair Value of Financial Instruments”) for further fair value disclosures. Turnaround Expenses The direct-expense method of accounting is used for turnaround activities. Turnarounds represent major maintenance activities that require the shutdown of significant parts of a plant to perform necessary inspection, cleaning, repairs and replacements of assets. Costs incurred for routine repairs and maintenance or unplanned outages at our facilities are expensed as incurred. Planned turnaround activities for the Petroleum Segment vary in frequency dependent on refinery units, but generally occur every four to five years . The frequency of turnarounds in the Nitrogen Fertilizer segment is every two to three years . Costs associated with these turnaround activities were included in Direct Operating Expenses (exclusive of depreciation and amortization) in the Consolidated Statements of Operations. During the years ended December 31, 2018, 2017 and 2016, the Petroleum Segment incurred turnaround expenses of $4 million , $80 million and $31 million , respectively. For the same periods, the Nitrogen Fertilizer Segment incurred turnaround expenses of $6 million , $3 million and $7 million , respectively. Share-Based Compensation The Company accounts for share-based compensation in accordance with ASC Topic 718, Compensation — Stock Compensation (“ASC 718”). Currently, all of the Company’s share-based compensation awards, including those issued by CVR Refining and CVR Partners, are liability-classified and are measured at fair value at the end of each reporting period based on the applicable closing unit price. Compensation expense will fluctuate based on changes in the applicable share or unit prices and expense reversals resulting from employee terminations prior to award vesting. Additionally, the Company has issued certain performance unit awards. The fair value of these performance unit awards is recognized as compensation expense only if the attainment of the performance conditions is considered probable. Uncertainties involved in this estimate include continued employment requirements and whether or not the performance conditions will be attained. The performance objectives are set in accordance with approved levels of the business plan for the fiscal year during the performance cycle and therefore are considered reasonably possible of being achieved. If this assumption proves not to be true and the awards do not vest, compensation expense recognized during the performance cycle will be reversed. Income Taxes Income taxes are accounted for utilizing the asset and liability approach. Under this method, deferred tax assets and liabilities are recognized for the anticipated future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis. Deferred amounts are measured using enacted tax rates expected to apply to taxable income in the year those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. Earnings Per Share There were no dilutive awards outstanding during the years ended December 31, 2018, 2017, and 2016. Recent Accounting Pronouncements - Adoption of New Accounting Standard On January 1, 2018, the Company adopted Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“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 prior 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. The adoption of ASC 606 resulted in changes to how the Nitrogen Fertilizer Segment accounts for prepaid contracts. Prior to the adoption of ASC 606, deferred revenue was recorded upon customer prepayment, however, under the new revenue standard, deferred revenue and an associated receivable is recorded at the point in time in which a prepaid contract is legally enforceable and the associated right to consideration is unconditional. Due to this change, the adoption of ASC 606 resulted in a $21 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 CVR Partners were $34 million and $31 million , respectively, as of January 1, 2018. In addition to the change noted above, the adoption of ASC 606 also resulted in a change in accounting for fees collected from certain customers by the Petroleum Segment that 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 CVR Refining’s customers on product sales and is required under the new standard to be included in the transaction price. The impact of the change in presentation was an increase of $2 million to net sales and cost of materials and other for the period ended December 31, 2018. The following table displays the effect of the changes to the Consolidated Balance Sheet as of December 31, 2018 for the adoption of ASC 606. The Company’s Consolidated Statement of Cash Flows was not impacted due to the adoption of ASC 606 for the period ended December 31, 2018. (in millions) December 31, 2018 As Reported Balances without adoption of ASC 606 Effect of change Assets Accounts Receivable $ 169 $ 124 $ 45 Liabilities Deferred Revenue (1) $ 69 $ 24 $ 45 _____________________________ (1) Deferred Revenues are recorded within the Other Current Liabilities financial statement line item. Recent Accounting Pronouncements - 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” (“ Topic 842 ”) , 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 of the underlying asset for the lease term on the balance sheet. Quantitative and qualitative disclosures, including disclosures regarding significant judgments made by management, will be required. Topic 842 was adopted by the FASB as of January 1, 2019 electing the option to apply the transition provisions at the adoption date instead of the earliest comparative period presented in the financial statements. In connection with the adoption of ASC 842, the following elections were made in the application of Topic 842: • Under the short-term lease exception provided for in the standard, ROU assets and related lease liabilities for leases with a term greater than one year were and will be recognized; • The accounting treatment for existing land easements was carried forward; • Lease and non-lease components were and will not be bifurcated for all of the Company’s asset groups; and • The portfolio approach was and will be used in the selection of the discount rate used to calculate minimum lease payments and the related ROU asset and operating lease liability amounts. Adoption of Topic 842 resulted in the recording of additional ROU assets and lease liabilities of approximately $53 million , in addition to the recognition of a finance lease asset and obligation of approximately $26 million , as of January 1, 2019. The standard will not materially affect the Company’s consolidated net earnings or cash flows. In August 2018, the FASB issued ASU 2018-15, Intangibles-Goodwill and Other-Internal-Use Software (Subtopic 350-40). This ASU addresses customer’s accounting for implementation costs incurred in a cloud computing arrangement that is a service contract and also adds certain disclosure requirements related to implementation costs incurred for internal-use software and cloud computing arrangements. The amendment aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software (and hosting arrangements that include an internal-use software license). This standard is effective for the Company beginning January 1, 2020, with early adoption permitted. The amendments in this standard can be applied either retrospectively or prospectively to all implementation costs incurred after the date of adoption. The Company is evaluating the effect of adopting this new accounting guidance on its consolidated financial statements, but does not expect adoption will have a material impact on the Company’s consolidated financial position or results of operations. In August 2018, the FASB issued ASU 2018-13, Fair Value Measurement (Topic 820). The ASU eliminates such disclosures as the amount of and reasons for transfers between Level 1 and Level 2 of the fair value hierarchy. Certain disclosures are required to be applied on a retrospective basis and others on a prospective basis. This standard is effective for the Company beginning January 1, 2020, with early adoption permitted. The Company is evaluating the effect of adopting this new accounting guidance, but does not expect adoption will have a material impact on the Company's disclosures.

Acquisition

Acquisition	12 Months Ended
	Dec. 31, 2018
Business Combinations [Abstract]
Acquisition	(3) Acquisition On April 1, 2016, CVR Partners acquired the East Dubuque Facility as part of the Agreement and Plan of Merger, dated as of August 9, 2015 (the “East Dubuque Merger”). The East Dubuque Merger was accounted for as an acquisition of a business with CVR Partners as the acquirer. The aggregate merger consideration was approximately $802 million , including the fair value of CVR Partners common units issued of $335 million , cash consideration of $99 million and $368 million fair value of assumed debt. From the date of acquisition, the East Dubuque Facility’s operations contributed net sales of $128 million and an operating loss of $1 million to the Consolidated Statement of Operations for the year ended December 31, 2016.

Equity Method Investments

Equity Method Investments	12 Months Ended
	Dec. 31, 2018
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	(4) Equity Method Investments For each of the following investments, CVR Refining has the ability to exercise influence through its participation in the management committees, which make all significant decisions. However, since CVR Refining has equal or proportionate influence over each committee as a joint partner without regard to its economic interest and does not serve as the day-to-day operator, we have determined that these entities should not be consolidated and apply the equity method of accounting. • Enable South Central Pipeline, LLC (“Enable JV”, formerly Velocity Pipeline Partners, LLC) - CVR Refining owns a 40% interest in Enable JV, which operates a 12-inch 26-mile crude oil pipeline with a capacity of approximately 80,000 barrels per day that is connected to the Wynnewood Refinery. The remaining interest in Enable JV is owned by Enable Midstream Partners, LP. • Midway Pipeline, LLC (“Midway JV”) - CVR Refining owns a 50% interest in Midway JV, which operates a 16-inch 100 mile crude oil pipeline with a capacity of approximately 120,000 barrels per day which connects the Coffeyville Refinery to the Cushing Oklahoma oil hub. (in millions) Enable JV Midway JV Total Balance at December 31, 2016 6 — — 6 Contributions 1 — 76 77 Cash Distributions (1 ) — (1 ) Equity income — — 1 1 Balance at December 31, 2017 6 77 83 Cash Distributions (2 ) (5 ) (7 ) Equity income 2 6 8 Balance at December 31, 2018 $ 6 $ 78 $ 84

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2018
Debt Disclosure [Abstract]
Long-Term Debt	(5) Long-Term Debt (in millions) December 31, 2018 December 31, 2017 CVR Partners: 9.25% Senior Secured Notes due June 2023 (a) $ 645 $ 645 6.50% Senior Notes due April 2021 2 2 Unamortized discount and debt issuance costs (18 ) (22 ) Total CVR Partners Debt $ 629 $ 625 CVR Refining: 6.50% Senior Notes due November 2022 (b) $ 500 $ 500 Capital lease obligations 44 45 Unamortized debt issuance cost (3 ) (4 ) Current portion of capital lease obligations (3 ) (2 ) Total CVR Refining Debt $ 538 $ 539 Total Long-Term Debt $ 1,167 $ 1,164 (a) This debt was issued at a $16 million discount which is being amortized, as interest expense, over the remaining term of the debt. Debt issuance costs associated with this debt totaled $9 million . (b) Debt issuance costs associated with this debt totaled $9 million . On January 29, 2019, the 2022 Senior Notes were amended such that CVR Refining was replaced by CVR Energy Inc. as the primary guarantor, on a senior unsecured basis, of the 2022 Senior Notes. The CVR Energy Inc. guarantee is full and unconditional and joint and several. See Note 15 ("Guarantor") for further discussion and implications of this change to guarantor. Credit Facilities (in millions) Total Capacity Amount Borrowed as of December 31, 2018 Outstanding Letters of Credit Available Capacity as of December 31, 2018 Maturity Date Amended and Restated Asset Based (ABL) Credit Facility (c) $ 400 $ — $ 6 $ 394 November 14, 2022 Asset Based (ABL) Credit Facility (d) 50 — — 50 September 30, 2021 (c) Loans under the Amended and Restated ABL Credit Facility initially bear interest at an annual rate equal to (i) 1.50% plus LIBOR or (ii) 0.50% plus a base rate, subject to quarterly excess availability. (d) 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. Included in other current liabilities on the Consolidated Balance Sheets is accrued interest payable totaling approximately $8 million for both December 31, 2018 and 2017, $5 million relates to the 2022 Notes and $3 million relates to the 2023 Notes. The Company is in compliance with all covenants of the ABL credit facilities and the senior notes as of December 31, 2018 . Amended and Restated Asset Based (ABL) Credit Facility On November 14, 2017, CRLLC, CVR Refining, its wholly-owned subsidiary, CVR Refining, LLC (“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 Amended and Restated ABL Credit Facility is a $400 million asset-based revolving credit facility, with sub-limits for letters of credit and swingline loans of $ 60 million and $40 million , respectively. The Amended and Restated ABL Credit Facility also includes a $200 million uncommitted incremental facility. Asset Based (ABL) Credit Facility On September 30, 2016 , CVR Partners entered into a senior secured asset based revolving credit facility (the “ABL Credit Facility”) with a group of lenders and UBS AG (“UBS”), as administrative agent and collateral agent. The ABL Credit Facility has an aggregate principal amount of availability of up to $50 million with an incremental facility, which permits an increase in borrowings of up to $25 million in the aggregate subject to additional lender commitments and certain other conditions. The ABL Credit Facility is scheduled to mature on September 30, 2021. Credit Agreement On January 29, 2019, the Company entered into a credit agreement (the “Credit Agreement”) with Jefferies Finance LLC to provide a term loan credit facility with a maturity date of March 10, 2019. The borrowings under the Credit Agreement of $105 million were used to fund a portion of the CVRR Unit Purchase. All amounts were repaid on February 11, 2019. Capital Lease Obligations CVR Refining maintains three significant leases, accounted for as a capital lease, which include a pipeline lease, a storage and terminal equipment lease and a bundled truck lease. These leases range in expiry from 44 months to 130 months . As of December 31, 2018 , the outstanding obligation associated with these arrangements totaled approximately $44 million . Future payments required under these capital lease at December 31, 2018 are as follows: Year Ending December 31, Capital Lease (in millions) 2019 - 2023 (annually $7 million) $ 35 Thereafter 37 Total future payments 72 Less: amount representing interest 28 Present value of future minimum payments 44 Less: current portion 3 Long-term portion $ 41

Revenue

Revenue	12 Months Ended
	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Revenue	(6) Revenue On January 1, 2018, the Company adopted Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“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 prior period. The Company did not identify any material differences in its existing revenue recognition methods that required modification under the new standard and, as such, a cumulative effect adjustment of applying the standard using the modified retrospective method was not recorded. The following tables present the Company’s revenue disaggregated by major product. The following tables include a reconciliation of the disaggregated revenue by product and other revenue components for the Company’s reportable segments. Year Ended December 31, 2018 (in millions) Petroleum Nitrogen Fertilizer Other / Eliminations Consolidated Gasoline $ 3,383 $ — $ — $ 3,383 Distillates (a) 3,067 — — 3,067 Ammonia — 66 — 66 UAN — 222 — 222 Other urea products — 21 — 21 Freight revenue 23 34 — 57 Other (b) 206 8 (7 ) 207 Revenue from product sales 6,679 351 (7 ) 7,023 Crude oil sales 96 — — 96 Other revenue (b) 5 — — 5 Total revenue $ 6,780 $ 351 $ (7 ) $ 7,124 (a) Distillates consist primarily of diesel fuel, kerosene and jet fuel. (b) Other revenue consists primarily of feedstock and asphalt sales and Cushing, OK storage tank lease revenue. See Note 2 (“Summary of Significant Accounting Policies”) for further discussion. Petroleum Segment 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 sales tax practical expedient is being applied, whereby qualifying excise and other taxes collected from customers and remitted to governmental authorities are not included in reported Petroleum Segment 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 does not 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 30 days of product delivery or invoice date. The Petroleum Segment’s contracts with customers commonly include a provision which states that the petroleum segment 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. Product returns or refunds are rare and will be accounted for 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 that are re-billed to customers for expenses reflected in cost of materials and other for the transportation and distribution of products to the customer. Nitrogen Fertilizer Segment The Nitrogen Fertilizer Segment sells its products on a wholesale basis under a contract or by purchase order. Contracts with customers, including purchase orders, generally contain fixed pricing and 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 or 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 for freight is included in cost of materials and other. Qualifying taxes collected from customers and remitted to governmental authorities are not included in reported Nitrogen Fertilizer Segment 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, no specific warranty reserve is recorded and activities related to such warranty, if any, are not considered 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. An insignificant portion of the Nitrogen Fertilizer Segment’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 an immaterial amount of 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. Remaining performance obligations As of December 31, 2018, the Nitrogen Fertilizer Segment had approximately $11 million of remaining performance obligations for contracts with an original expected duration of more than one year. Approximately 45% of these performance obligations are expected to be recognized as revenue by the end of 2019 with an additional 27% by 2020 and the remaining balance thereafter. Contract balances Deferred revenue is a contract liability associated with the Nitrogen Fertilizer Segment 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 Nitrogen Fertilizer Segment’s deferred revenue activity during the year ended December 31, 2018 is presented below: (in millions) Year Ended December 31, 2018 Balance at January 1, 2018 $ 34 Add: New prepay contracts entered into during the period, net of adjustments 92 Less: Revenue recognized that was included in the contract liability balance at the beginning of the period 34 Revenue recognized related to contracts entered into during the period 23 Balance at December 31, 2018 $ 69 Major Customers Petroleum Segment - The Petroleum Segment has one customer who comprised 15% , 19% , and 15% of net sales for the years ended December 31, 2018, 2017, and 2016, respectively. Nitrogen Fertilizer Segment - The Nitrogen Fertilizer Segment has two customers who comprised 20% , 16% , and 20% of net sales for the years ended December 31, 2018, 2017, and 2016, respectively. One of these customers comprised 14% , 11% , and 10% of net sales for the same periods, respectively.

Derivative Financial Instrument

Derivative Financial Instruments	12 Months Ended
	Dec. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Financial Instruments	(7) Derivative Financial Instruments Our segments 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 Petroleum Segment from time to time enters into various commodity derivative transactions. The Petroleum Segment 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. There are no premiums paid or received at inception of the derivative contracts and upon settlement. The Petroleum Segment may enter into forward purchase or sale contracts associated with RINs. As of December 31, 2018 , the Petroleum Segment had open commitments to purchase 27 million 2019 year RINs at $4 million and 8 million 2018 year RINs for $3 million . Commodity derivatives include commodity swaps and forward purchase and sale commitments. There were no outstanding commodity swap positions as of December 31, 2018 . The following outlines the gains (losses) recognized on the Company’s derivative activities, all of which are recorded in Cost of Materials and Other on the Consolidated Statements of Operations: Gain (Loss) on Derivatives by Type Year Ended December 31, (in millions) 2018 2017 2016 Forward purchases $ 103 $ (26 ) $ — Swaps 44 (43 ) (19 ) Futures (1 ) (1 ) — Total gain (loss) on derivatives, net $ 146 $ (70 ) $ (19 ) The following outlines the open positions (in millions of barrels) held by the Petroleum Segment as of December 31, 2018 and 2017: Open Commodity Derivative Instruments Year Ended December 31, 2018 2017 Commodity Swap Instruments: 2-1-1 Crack spreads — 7 Distillate Crack spreads — 4 Gasoline Crack spreads — 4 Purchase and Sale Commitments - Futures Contracts: Canadian crude oil 2 6 Offsetting Assets and Liabilities The Company elected to offset the fair value amounts recognized for multiple derivative contracts executed with the same counterparty. These amounts are recognized as current assets and current liabilities within the prepaid expenses and other current assets and accrued expenses and other current liabilities financial statement line items, respectively, in the Consolidated Balance Sheets as follows: Derivative Assets Derivative Liabilities December 31, December 31, (in millions) 2018 2017 2018 2017 Commodity Derivatives $ 8 $ 7 $ 1 $ 71 Less: Counterparty Netting (1 ) (7 ) (1 ) (7 ) Total Net Fair Value of Derivatives $ 7 $ — $ — $ 64 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 table sets forth the assets and liabilities measured or disclosed at fair value on a recurring basis, by input level, as of December 31, 2018 and 2017 : December 31, 2018 (in millions) Level 1 Level 2 Level 3 Total Location and Description Cash equivalents $ 50 $ — $ — $ 50 Other current assets (commodity derivatives) — 7 — 7 Total Assets $ 50 $ 7 $ — $ 57 Other current liabilities (Renewable Fuel Standard “RFS” obligation) — (2 ) — (2 ) Long-term debt — (1,163 ) — (1,163 ) Total Liabilities $ — $ (1,165 ) $ — $ (1,165 ) December 31, 2017 (In millions) Level 1 Level 2 Level 3 Total Location and Description Cash equivalents $ 15 $ — $ — $ 15 Total Assets $ 15 $ — $ — $ 15 Other current liabilities (commodity derivatives) $ — $ (64 ) $ — $ (64 ) Other current liabilities (RFS obligation) — (1 ) — (1 ) Long-term debt — (1,209 ) — (1,209 ) Total Liabilities $ — $ (1,274 ) $ — $ (1,274 ) As of December 31, 2018 and 2017 , the only financial assets and liabilities that are measured at fair value on a recurring basis are the Company’s cash equivalents, derivative instruments, and the RFS obligation. The Petroleum Segment’s commodity derivative contracts and RFS 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 or liabilities between any of the above levels during the year ended December 31, 2018 .

Share-Based Compensation

Share-Based Compensation	12 Months Ended
	Dec. 31, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Share-Based Compensation	(8) Share-Based Compensation Overview CVR Energy, CVR Refining and CVR Partners all have a Long-Term Incentive Plans (collectively, the “LTIPs”) which permit the granting of options, stock and unit appreciation rights (“SARs”), restricted shares, restricted stock units, phantom units, unit awards, substitute awards, other unit-based awards, cash awards, dividend and distribution equivalent rights, share awards and performance awards (including performance share units, performance units and performance-based restricted stock). Individuals who are eligible to receive awards and grants under the LTIP include the Company’s and employees, officers, consultants, advisors and directors of CVR Refining and CVR Partners. Incentive and Phantom Unit Awards Incentive and phantom unit awards have been granted to officers, employees, consultants and directors (collectively, the “Share-Based Awards”) under the LTIPs. As a result, Share-Based Awards that reflect the value and dividend or distributions of CVR Energy, CVR Refining or CVR Partners have been granted and remain outstanding as of December 31, 2018. Each Share-Based Award and the related dividend or distribution equivalent right represents the right to receive, upon vesting, a cash payment equal to (i) the average fair market value of one share or unit, as applicable, in accordance with the award agreement, plus (ii) the per share or unit cash value of all dividends or distributions declared and paid, as applicable, from the grant date to and including the vesting date. The Share-Based Awards are generally graded-vesting awards, which are expected to vest over three years with one-third of the award vesting each year the grantee remains employed by the Company or its subsidiaries. Compensation expense is recognized on ratably based on service provided to the Company and its subsidiaries with the amount recognized fluctuating as a result of the Share-Based Awards being re-measured to fair value at the end of each reporting period due to their liability-award classification. Phantom and Incentive Unit Awards - A summary of activity for the Company’s Share-Based Awards for the years ended December 31, 2018 , 2017 and 2016 is presented below: Shares or Units Weighted- (Per Share or Unit) Aggregate (In Millions) Non-vested at December 31, 2016 2,664,438 $ 10.76 $ 24 Granted 1,713,192 8.52 Vested (1,062,382 ) 11.62 Forfeited (361,301 ) 12.29 Non-vested at December 31, 2017 2,953,947 $ 8.97 $ 33 Granted 1,236,322 16.11 Vested (1,140,423 ) 9.74 Forfeited (617,773 ) 9.39 Non-vested December 31, 2018 2,432,073 $ 12.13 $ 24 Performance Unit Awards Pursuant to an employment agreement with the Company’s current chief executive officer, the Company entered into two performance award agreements on November 1, 2017. In connection with the performance period of January 1, 2018 to December 31, 2018, a performance award was granted with a target value of $1.5 million that is payable in February 2019 (the “2018 CEO Performance Award”). The payout under the 2018 CEO Performance Award is based on the Company’s performance against certain safety, operating and financial measures. Additionally, the Company entered into a performance award agreement (the “CEO Performance Award”). The CEO Performance Award represents the right to receive upon vesting, a cash payment equal to $10 million if the average closing price of the Company’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. An accrual of approximately $2 million has been recognized at December 31, 2018 associated with the 2018 CEO Performance Award. In December 2016, the Company entered into a performance unit award agreement with the Company’s former chief executive officer related to the performance period from January 1, 2017 to December 31, 2017 (the “Former CEO Performance Award ”). As of and for the year ended December 31, 2018, there was no outstanding liability or expense recognized related to the Former CEO Performance Award. Compensation Expense A summary of total share based compensation expense and unrecognized compensation expense related to the Share-Based Awards and Company’s performance awards, the amounts allocated to each of the Company’s segments, and the amounts that were not allocated to segments during the years ended December 31, 2018 , 2017 and 2016 is presented below: Expenses Unrecognized Expense For the year ended December 31, At December 31, 2018 (in millions) 2018 2017 2016 Amount Weighted Average Remaining Years Share based awards Incentive Units $ 4 $ 7 $ 2 $ 15 1.7 Phantom Units 8 8 3 4 1.6 Performance awards CEO Performance Award 2 — — 8 3.0 2018 CEO Performance Award 2 — — — 0.0 Former CEO Performance Award — 4 4 — 0.0 Total expense $ 16 $ 19 $ 9 $ 27 Other Benefit Plans CVR sponsors and administers two defined-contribution 401(k) plans, the CVR Energy 401(k) Plan and the CVR Energy 401(k) Plan for Represented Employees (the “Plans”), in which CVR employees may participate. CVR’s contributions under the Plans were approximately $9 million , $9 million and $8 million for the years ended December 31, 2018 , 2017 and 2016 , respectively.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Income Taxes	(9) Income Taxes Tax Allocation Agreement Prior to the CVRR Unit Exchange, CVR Energy was a member of the consolidated federal tax group of AEP, an affiliate of IEP, and party to a tax allocation agreement with AEP (the “Tax Allocation Agreement”). The Tax Allocation Agreement provides that AEP will pay all consolidated federal income taxes on behalf of the consolidated tax group. As a result, CVR Energy is required to make payments to AEP 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 AEP. Following the CVRR Unit Exchange, IEP and affiliates’ ownership of CVR Energy was reduced below 80% and CVR Energy is no longer eligible to file as a member of the AEP consolidated federal income tax group. Beginning with the tax period after the exchange, CVR Energy became the parent of a new consolidated group for U.S. federal income tax purposes and will file and pay its federal income tax obligations directly to the IRS. Pursuant to the terms of the Tax Allocation Agreement, however, CVR Energy may be required to make payments in respect of taxes owed by AEP for periods prior to the exchange. Similar principles may apply for state or local income tax purposes where CVR Energy filed combined, consolidated for unitary tax returns with AEP. As of December 31, 2018 and 2017, the Company’s Consolidated Balance Sheets reflected a receivable of $4 million and $5 million , respectively, for federal income taxes due from AEP. These amounts are recorded as Other Current Assets in the Consolidated Balance Sheets. As of December 31, 2018, the Company’s Consolidated Balance Sheets also reflected a receivable of $12 million from the IRS and certain state jurisdictions. Income Tax Expense (Benefit) Income tax expense (benefit) is comprised of the following: Year Ended December 31, (in millions) 2018 2017 2016 Current: Federal $ 31 $ (1 ) $ 67 State (7 ) (22 ) (7 ) Total current 24 (23 ) 60 Deferred: Federal 47 (181 ) (61 ) State 18 (13 ) (19 ) Total deferred 65 (194 ) (80 ) Total income tax expense (benefit) $ 89 $ (217 ) $ (20 ) The following is a reconciliation of total income tax expense (benefit) to income tax expense (benefit) computed by applying the statutory federal income tax rate to pretax income (loss): Year Ended December 31, (in millions) 2018 2017 2016 Tax computed at federal statutory rate $ 105 $ — $ (4 ) State income taxes, net of federal tax benefit 14 (16 ) (8 ) State tax incentives, net of federal tax expense (4 ) (7 ) (9 ) Noncontrolling interest (26 ) 6 6 Other, net — — (5 ) Adjustment to deferred tax assets and liabilities for enacted change in federal tax rate (a) — (200 ) — Total income tax expense (benefit) $ 89 $ (217 ) $ (20 ) (a) The income tax benefit for the year ended December 31, 2017 was favorably impacted as a result of the Tax Cuts and Jobs Act legislation that was signed into law in December 2017, reducing the federal income tax rate from 35% to 21% beginning in 2018. As a result, the Company’s net deferred tax liabilities at December 31, 2017 were remeasured to reflect the lower tax rate that will be in effect for the years in which the deferred tax assets and liabilities will be realized. Deferred Tax Assets and Liabilities The income tax effect of temporary differences that give rise to significant portions of the deferred income tax assets and deferred income tax liabilities at December 31, 2018 and 2017 are as follows: December 31, (in millions) 2018 2017 Deferred income tax assets: State tax credit carryforward, net $ 11 $ 11 Net operating loss carryforward — 7 Total gross deferred income tax assets 11 18 Deferred income tax liabilities: Investment in CVR Partners (59 ) (55 ) Investment in CVR Refining (309 ) (345 ) Other (5 ) (4 ) Total gross deferred income tax liabilities (373 ) (404 ) Net deferred income tax liabilities $ (362 ) $ (386 ) In assessing the realizability of deferred tax assets including net operating loss and credit carryforwards, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. Management considers the scheduled reversal of deferred tax liabilities, projected future taxable income, and tax planning strategies in making this assessment. Although realization is not assured, management believes that it is more likely than not that all of the deferred tax assets will be realized and thus, no valuation allowance was provided as of December 31, 2018 and 2017 . As of December 31, 2018, CVR Energy has state credits of approximately $35 million , which are available to reduce future state income taxes. These credits, if not used, will begin expiring in 2033. Uncertain Tax Positions A reconciliation of unrecognized tax benefits is as follows: Year Ended December 31, (in millions) 2018 2017 2016 Balance beginning of year $ 29 $ 44 $ 49 Reductions related to expirations of statute of limitations (6 ) (15 ) (5 ) Balance end of year $ 23 $ 29 $ 44 Included in the balance of unrecognized tax benefits as of December 31, 2018 , 2017 and 2016 are $18 million , $23 million and $29 million , respectively, of tax benefits that, if recognized, would affect the effective tax rate. Approximately $6 million , $15 million and $5 million of the unrecognized tax positions relating to state tax credits were recognized in 2018 , 2017 and 2016, respectively, as a result of a lapse of statute of limitations. Additionally, the Company believes that it is reasonably possible that approximately $3 million of its unrecognized tax positions relating to state tax credits may be recognized by the end of 2019 as a result of a lapse of the statute of limitations. Approximately $22 million and $26 million of unrecognized tax benefits were netted with deferred tax asset carryforwards as of December 31, 2018 and 2017 , respectively. The remaining unrecognized tax benefits are included in Other Long-term Liabilities in the Consolidated Balance Sheets. CVR Energy recognizes interest expense (income) and penalties on uncertain tax positions and income tax deficiencies (refunds) in income tax expense. CVR Energy recognized interest benefit of approximately $1 million during 2018 and has recognized a nominal liability for interest as of December 31, 2018. In 2017, CVR Energy recognized interest expense of approximately $7 million and had recognized a liability for interest of approximately $1 million as of December 31, 2017. In 2016, CVR Energy recognized interest expense of approximately $1 million and had recognized a liability for interest of approximately $8 million as of December 31, 2016. No penalties were recognized during 2018 or 2017. At December 31, 2018, the Company’s tax filings are generally open to examination in the United States for the tax years ended December 31, 2015 through December 31, 2017 and in various individual states for the tax years ended December 31, 2013 through December 31, 2017.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	(10) Commitments and Contingencies Leases The minimum required payments for CVR’s operating lease agreements and unconditional purchase obligations are as follows: Year Ending December 31, Operating Leases Unconditional Purchase Obligations (in millions) 2019 $ 24 $ 129 2020 20 89 2021 18 78 2022 16 76 2023 12 75 Thereafter 26 444 $ 116 $ 891 Leases - The Company leases equipment, including railcars and real properties, under long-term operating leases. For the years ended December 31, 2018, 2017 and 2016, rent expense totaled approximately $10 million , $8 million and $8 million , respectively. Supply Commitments - The Company is a party to various supply agreements with both related and third parties which commit the Company to purchase minimum volumes of crude oil, hydrogen, oxygen, nitrogen, petroleum coke (“pet coke”), and natural gas to run its facilities’ operations. For the years ended December 31, 2018, 2017 and 2016. amounts purchased under these supply agreements totaled approximately $214 million , $209 million , and $151 million , respectively. Crude Oil Supply Agreement On August 31, 2012, an indirect, wholly-owned subsidiary of CVR Refining and Vitol Inc. (“Vitol”) entered into an Amended and Restated Crude Oil Supply Agreement (as amended, the “Crude Oil Supply Agreement”). Under the Crude Oil Supply Agreement, Vitol supplies the Petroleum Segment with crude oil and intermediation logistics helping to reduce the amount of inventory held at a certain point and mitigate crude oil pricing risk. Volumes contracted under the Crude Oil Supply Agreement, as a percentage of the total crude oil purchases (in barrels), was approximately 42% , 55% and 61% for the years ended December 31, 2018, 2017 and 2016, respectively. The Crude Oil Supply Agreement automatically renews for successive one -year terms (each such term, a “Renewal Term”) unless either party provides the other with notice of nonrenewal at least 180 days prior to expiration of any Renewal Term. Contingencies CVRR Unit Purchase - As of February 20, 2019, the Company, CVR Refining and its general partner, CVR Refining Holdings, IEP and certain directors and affiliates have each been named in at least one of six lawsuits filed in the Court of Chancery of the State of Delaware by purported former unitholders of CVR Refining, on behalf of themselves and an alleged class of similarly situated unitholders (the “Call Option Lawsuits”). The Call Option Lawsuits primarily allege breach of contract, tortious interference and breach of the implied covenant of good faith and fair dealing and seek monetary damages and attorneys’ fees, among other remedies, relating to the Company’s exercise of the call option under the CVR Refining Amended and Restated Agreement of Limited Partnership assigned to it by CVR Refining’s general partner. The Call Option Lawsuits are in the earliest stages of litigation. The Company believes the Call Option Lawsuits are without merit and intends to vigorously defend against them. Business Interruption Recovery - In 2018, CVR Partners submitted a business interruption claim for losses under its insurance policies, related to damage and resulting reduced equipment production rates experienced during the second half of 2017 and early 2018. In December 2018, in connection with a signed Claim Settlement and Release Agreement with the underwriters of the insurance policy, CVR Partners recognized a recovery of approximately $6 million . Approximately $5 million was received prior to year end and recorded as Other Income within the Consolidated Statement of Operations. The remaining amount of approximately $1 million was recorded as Accounts Receivable as of December 31, 2018 and was subsequently collected in January 2019. Property Tax Matter - In 2008, CRNF protested the reclassification and reassessment by Montgomery County, Kansas (the “County”) of CRNF’s nitrogen fertilizer plant following expiration of its ten -year property tax abatement that expired on December 31, 2007, which reclassification and reassessment resulted in an increase in CRNF’s annual property tax expense in excess of $10 million per year for the 2008 through 2012 tax years. Despite its protest, CRNF fully accrued and paid these property taxes. In February 2013, the County and CRNF agreed to a settlement for tax years 2009 through 2012 which resulted in decreased property taxes through 2017, leaving 2008 in dispute. In 2013, the Kansas Court of Appeals overturned an adverse ruling of the Kansas Board of Tax Appeals (“BOTA”) and instructed BOTA to classify each CRNF asset on an asset-by-asset basis. In March 2015, BOTA concluded its classification and determined a substantial majority of CRNF’s assets in dispute were personal property for the 2008 tax year. In September 2018, the Kansas Court of Appeals upheld BOTA’s property tax determinations in CRNF’s favor. In October 2018, the County petitioned the Kansas Supreme Court to review the Court of Appeals determination. Subsequent briefs were filed by CRNF and the County. The Kansas Supreme Court has not yet ruled on whether it will hear the County’s appeal. Environmental, Health, and Safety (“EHS”) Matters Clean Air Act Matter - On August 21, 2018, CRRM received a letter from the United States Department of Justice (“DOJ”) on behalf of the EPA and Kansas Department of Health and Environment (“KDHE”) alleging violations of the Clean Air Act (“CAA”) and a 2012 Consent Decree between CRRM, the United States (on behalf of EPA) and KDHE at CRRM’s Coffeyville refinery. In September 2018, CRRM executed a tolling agreement with the DOJ and KDHE extending time for negotiation regarding the agencies’ allegations through March 31, 2019. At this time the Company cannot reasonably estimate the potential penalties, costs, fines or other expenditures that may result from this matter or any subsequent enforcement or litigation relating thereto and, therefore, the Company cannot determine if the ultimate outcome of this matter will have a material impact on the Company’s financial position, results of operations or cash flows. Renewable Fuel Standards - The Company’s Petroleum Segment is subject to the renewable fuel standards (“RFS”) of the Environmental Protection Agency (“EPA”) that require refiners to either blend “renewable fuels” in with their transportation fuels or purchase renewable fuel credits, known as renewable identification numbers (“RINs”), in lieu of blending. CVR Refining is not able to blend the substantial majority of its transportation fuels and has to purchase RINs on the open market, as well as obtain waiver credits for cellulosic biofuels from the EPA in order to comply with the RFS. The Company recognized expense of approximately $60 million , $249 million and $206 million for the years ended December 31, 2018 , 2017 and 2016 , respectively, for the Petroleum Segment’s compliance with RFS. The expense recognized was included within Cost of Materials and Other in the Consolidated Statements of Operations. The Company’s costs to comply with RFS include the purchased cost of RINs, the impact of recognizing CVR Refining’s uncommitted biofuel blending obligation at fair value based on market prices at each reporting date and the valuation change of RINs purchases in excess of CVR Refining’s RFS obligation as of the reporting date. During the year ended December 31, 2018 , the Company’s cost to comply with RFS was favorably impacted by a reduction in CVR Refining’s RFS obligation and reduced market pricing. As of December 31, 2018 and 2017 , CVR Refining’s biofuel blending obligation was approximately $4 million and $28 million , respectively, which is recorded in Other Current Liabilities in the Consolidated Balance Sheets. Environmental Remediation - As of December 31, 2018 and 2017 , environmental accruals representing estimated costs for future remediation efforts at certain Petroleum Segment sites totaled approximately $8 million and $4 million , respectively. These amounts are reflected in Other Current Liabilities or Other Long-Term Liabilities depending when the Company expects to expend such amounts. Wynnewood Refinery Incident - On September 28, 2012, the Petroleum Segment’s Wynnewood refinery, owned and operated by Wynnewood Refining Company, LLC (“WRC”), an indirect wholly-owned subsidiary of CVR Refining, experienced an explosion in a boiler unit during startup after a short outage as part of the turnaround process. Two employees were fatally injured. Damage at the refinery was limited to the boiler. Additionally, there was no environmental impact. The refinery was in the final stages of shutdown for turnaround maintenance at the time of the incident. The Company completed an internal investigation of the incident and cooperated with the Occupational Safety and Health Administration (“OSHA”) in its investigation. OSHA also conducted a general inspection of the facility during the boiler incident investigation. In March 2013, OSHA completed its investigation, communicated its citations, and placed WRC in its Severe Violators Enforcement Program (“SVEP”). The Company is vigorously contesting the citations and OSHA’s placement of WRC in the SVEP. Any penalties associated with OSHA’s citations are not expected to have a material adverse effect on the consolidated financial statements.

Business Segments

Business Segments	12 Months Ended
	Dec. 31, 2018
Segment Reporting [Abstract]
Business Segments	(11) Business Segments The Company as two operating segments: Petroleum and Nitrogen Fertilizer. These operating segments are also the Company’s reportable segments. As discussed in Note 1 (“Organization and Nature of Business”), the Petroleum Segment is comprised entirely of the consolidated operations of CVR Refining and its subsidiaries. The Nitrogen Fertilizer Segment is comprised entirely of the consolidated operations of CVR Partners and its subsidiaries. Other corporate activities, and related costs, are not included in these segments but costs related to such activities are allocated to each segment based on amounts attributable to each. All intercompany transactions are eliminated and are reflect as other below. All operations of the segments are located within the United States. The following tables summarize operating results, capital expenditures, and total asset information by segment: Year Ended December 31, (in millions) 2018 2017 2016 Net sales Petroleum $ 6,780 $ 5,664 $ 4,431 Nitrogen Fertilizer 351 331 356 Other (7 ) (7 ) (5 ) Total net sales $ 7,124 $ 5,988 $ 4,782 Operating income (loss) Petroleum $ 599 $ 134 $ 58 Nitrogen Fertilizer 6 (10 ) 26 Other (18 ) (17 ) (14 ) Total operating income (loss) $ 587 $ 107 $ 70 Interest expense, net (102 ) (109 ) (83 ) Other income, net 15 2 2 Earnings before income taxes 500 — (11 ) Depreciation and amortization Petroleum 134 133 129 Nitrogen Fertilizer 72 74 58 Other 7 7 6 Total depreciation and amortization 213 214 193 Capital expenditures Petroleum $ 79 $ 101 $ 102 Nitrogen fertilizer 19 14 23 Other 4 5 8 Total $ 102 $ 120 $ 133 Year Ended December 31, (in millions) 2018 2017 2016 Total assets Petroleum $ 2,360 $ 2,270 $ 2,332 Nitrogen Fertilizer 1,254 1,234 1,312 Other 293 303 406 Total $ 3,907 $ 3,807 $ 4,050

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	12 Months Ended
	Dec. 31, 2018
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	(12) Supplemental Cash Flow Information Supplemental cash flow information related to income taxes, interest, and capital expenditures is as follows: Year Ended December 31, (in millions) 2018 2017 Supplemental disclosures: Cash paid for income taxes, net of refunds $ 31 $ 15 Cash paid for interest 103 106 Non-cash investing and financing activities: Construction in progress additions included in accounts payable $ 17 $ 8 Change in accounts payable related to construction in progress additions 9 (5 ) Landlord incentives for leasehold improvements — 1

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2018
Related Party Transactions [Abstract]
Related Party Transactions	(13) Related Party Transactions Activity associated with the Company’s related party arrangements for the years ended December 31, 2018 , 2017 , and 2016 is summarized below: Expenses with related parties Year ended December 31, (in millions) 2018 2017 2016 Cost of materials and other Joint Venture Transportation Agreement: Enable JV $ 8 $ 2 $ — Payments made Dividends (1) 179 $ 142 142 Tax Allocation Agreement with AEP 12 15 45 Amounts due to/from related parties (in millions) December 31, 2018 December 31, 2017 Accounts Receivable (Payable) Tax Allocation Agreement with AEP $ 4 $ 5 _____________________________ (1) See below for a summary of the dividends paid to IEP for the periods ended December 31, 2018, 2017, and 2016. Joint Venture Agreement CVR Refining is party to a transportation agreement as part of the Enable JV for an initial term of 20 years under which Enable provides transportation services for crude oil purchased within a defined geographic area. Additionally, CR Refining entered into a terminalling services agreement with Enable JV under which it receives access to Enable JV’s terminal in Lowrance, Oklahoma to unload and pump crude oil into Enable JV’s pipeline for an initial term of 20 years. Dividends IEP and its affiliates, through its ownership of the Company’s common shares, is entitled to receive its share of dividends that are declared and paid by the Company based on the number of shares held at each record date. The following is a summary of the quarterly and special dividends paid to stockholders, including IEP and its affiliates during the years ended December 31, 2018 and 2017 : (in millions) December 31, 2017 March 31, 2018 June 30, 2018 September 30, 2018 Total Dividends Paid in 2018 Amount paid to IEP $ 36 $ 36 $ 53 $ 54 $ 179 Amounts paid to public stockholders 7 8 22 22 59 Total amount paid $ 43 $ 44 $ 75 $ 76 $ 238 Per common share $ 0.50 $ 0.50 $ 0.75 $ 0.75 $ 2.50 (in millions) December 31, 2016 March 31, 2017 June 30, 2017 September 30, 2017 Total Dividends Amount paid to IEP $ 35 $ 36 $ 35 $ 36 $ 142 Amounts paid to public stockholders 8 8 8 8 32 Total amount paid $ 43 $ 44 $ 43 $ 44 $ 174 Per common share $ 0.50 $ 0.50 $ 0.50 $ 0.50 $ 2.00 (in millions) December 31, 2015 March 31, 2016 June 30, 2016 September 30, 2016 Total Dividends Amount paid to IEP $ 35 $ 36 $ 35 $ 36 $ 142 Amounts paid to public stockholders 8 8 8 8 32 Total amount paid $ 43 $ 44 $ 43 $ 44 $ 174 Per common share $ 0.50 $ 0.50 $ 0.50 $ 0.50 $ 2.00 On February 20, 2019 , the Company’s board of directors declared a cash dividend for the fourth quarter of 2018 to the Company’s stockholders of $0.75 per share, or $75 million in the aggregate. The dividend will be paid on March 11, 2019 to stockholders of record at the close of business on March 4, 2019. IEP will receive $53 million in respect of its ownership interest in the Company’s shares. Affiliate Pension Obligations Prior to the exchange offer discussed in Note 1, Mr. Carl C. Icahn, through certain affiliates, owned 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. As a result of the historical ownership interest in CVR Energy by Mr. Icahn’s affiliates (prior to the exchange offer), the Company was subject to the pension liabilities of all entities in which Mr. Icahn had 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. 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. The unfunded plan balances for these sponsors was $435 million and $424 million as of June 30, 2018 and December 31, 2017, respectively. These results are based on the information provided by Mr. Icahn’s affiliates based on information from the plans’ actuaries. As of December 31, 2018 , and following the exchange offer, Mr. Icahn’s affiliates own approximately 71% of the Company’s capital stock and, therefore the Company is no longer considered to be liable for the aforementioned pension obligations of the controlled group. On October 1, 2018, Federal-Mogul was sold by Mr. Icahn’s affiliates to a third party.

Guarantor

Guarantor	12 Months Ended
	Dec. 31, 2018
Condensed Financial Information Disclosure [Abstract]
Guarantor	(14) Guarantor Financial Information On January 29, 2019, in connection with CVRR Unit Purchase, CVR Energy, Inc. became a guarantor of CVR Refining’s 2022 Senior Notes pursuant to a supplemental indenture (the “CVR Energy Guarantee”). The CVR Energy Guarantee is full and unconditional and joint and several. Following the cessation of trading for CVRR’s common units and the execution of the CVR Energy Guarantee, the Company is providing condensed consolidating financial statements in lieu of standalone CVRR financial statements pursuant to Rule 3-10 of Regulation S-X. The guarantor financial information provided below reflects condensed consolidating financial information of the Company. The following outlines the composition of each column in the condensed consolidating financial statements: • Parent - represents CVR Energy, Inc. which, as of January 29, 2019, guarantees the 2022 Senior Notes; • Subsidiary Issuer - represents Refining LLC and Coffeyville Finance, Inc. (“Coffeyville Finance”), which are the issuers of the 2022 Senior Notes. Coffeyville Finance has no assets or operations, thus the columns presents the financial position, results and cash flows of Refining LLC; • Guarantor Subsidiaries - represents the operating subsidiaries of Refining LLC, which also represent the operating subsidiaries of CVR Refining, and CRLLC, an indirect wholly-owned subsidiary of CVR Energy. CRLLC’s activities consist of general and administrative functions for the Company’s operating businesses; and • Non-Guarantor Subsidiaries - represents CVR Partners and other subsidiaries of CVR Energy that do not guarantee the 2022 Senior Notes. For the purposes of this financial information, investments in consolidated subsidiaries are accounted for under the equity method of accounting. Intercompany transactions between entities within each column have been eliminated within the column. Eliminations for transactions with entities reflected in other columns are reflected in the “Intercompany Elimination” column. Condensed Consolidating Balance Sheet December 31, 2018 Parent Subsidiary Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Intercompany Elimination Consolidated (in millions) ASSETS Current assets: Cash and cash equivalents $ 3 $ 340 $ 252 $ 73 $ — $ 668 Accounts receivable — — 107 62 — 169 Intercompany receivable 6 — 4 — (10 ) — Inventories — — 316 64 — 380 Prepaid expenses and other current assets 31 1 47 5 (8 ) 76 Total current assets 40 341 726 — 204 — (18 ) — 1,293 Property, plant and equipment, net of accumulated depreciation — — 1,425 1,020 — 2,445 Investment in and advances from subsidiaries 1,192 1,601 173 1,440 (4,406 ) — Other long-term assets — 1 123 45 — 169 Total assets $ 1,232 $ 1,943 $ 2,447 200,000 $ 2,709 200,000 $ (4,424 ) 200,000 $ 3,907 LIABILITIES AND PARTNERS' CAPITAL Current liabilities: Note payable and capital lease obligations $ — $ — $ 3 $ — $ — $ 3 Accounts payable 1 — 291 29 (1 ) 320 Intercompany payables — — — 10 (10 ) — Other current liabilities 6 7 62 105 (7 ) 173 Total current liabilities 7 7 356 — 144 — (18 ) — 496 Long-term liabilities: Long-term debt and capital lease obligations, net of current portion — 496 42 629 — 1,167 Investment and advances from subsidiaries — — 106 — (106 ) — Deferred income taxes (24 ) — — 386 — 362 Other long-term liabilities 3 — 7 4 — 14 Total long-term liabilities (21 ) 496 155 — 1,019 — (106 ) — 1,543 Commitments and contingencies Equity: Total CVR stockholders’ equity 1,246 1,440 1,936 924 (4,300 ) 1,246 Noncontrolling interest — — — 622 — 622 Total equity 1,246 1,440 1,936 1,546 (4,300 ) 1,868 Total liabilities and equity $ 1,232 $ 1,943 $ 2,447 — $ 2,709 — $ (4,424 ) — $ 3,907 Condensed Consolidating Balance Sheet December 31, 2017 Parent Subsidiary Issuer Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Intercompany Elimination Consolidated (in millions) ASSETS Current assets: Cash and cash equivalents $ 4 $ 163 $ 261 $ 54 $ — $ 482 Accounts receivable — — 169 10 — 179 Intercompany receivables 9 — 8 — (17 ) — Inventories — — 316 53 — 369 Prepaid expenses and other current assets 13 1 23 18 (7 ) 48 Total current assets 26 164 777 — 135 — (24 ) — 1,078 Property, plant and equipment, net of accumulated depreciation — — 1,513 1,075 — 2,588 Investment in and advances from subsidiaries 897 1,596 189 1,259 (3,941 ) — Other long-term assets 1 1 91 48 — 141 Total assets $ 924 $ 1,761 $ 2,570 — $ 2,517 — $ (3,965 ) — $ 3,807 LIABILITIES AND PARTNERS' CAPITAL Current liabilities: Note payable and capital lease obligations $ — $ — $ 2 $ — $ — $ 2 Accounts payable 1 — 310 24 (1 ) 334 Intercompany payables — — — 17 (17 ) — Other current liabilities 12 5 151 46 (6 ) 208 Total current liabilities 13 5 463 — 87 — (24 ) — 544 Long-term liabilities: Long-term debt and capital lease obligations, net of current portion — 496 42 626 — 1,164 Investment and advances from subsidiaries — — 230 — (230 ) — Deferred income taxes (8 ) — — 394 — 386 Other long-term liabilities — — 4 5 — 9 Total long-term liabilities (8 ) 496 276 — 1,025 — (230 ) — 1,559 Commitments and contingencies Equity: Total CVR stockholders’ equity 919 1,260 1,831 620 (3,711 ) 919 Noncontrolling interest — — — 785 — 785 Total equity 919 1,260 1,831 — 1,405 — (3,711 ) — 1,704 Total liabilities and equity $ 924 $ 1,761 $ 2,570 — $ 2,517 — $ (3,965 ) — $ 3,807 Condensed Consolidating Statement of Operations Year Ended December 31, 2018 Parent Subsidiary Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Intercompany Eliminations Consolidated (in millions) Net sales $ — $ — $ 6,779 $ 351 $ (6 ) $ 7,124 Operating costs and expenses: Cost of materials and other — — 5,601 88 (6 ) 5,683 Direct operating expenses — — 364 159 — 523 Depreciation and amortization — — 130 72 — 202 Cost of sales — — 6,095 319 (6 ) 6,408 Selling, general and administrative expenses 17 1 60 34 — 112 Depreciation and amortization — — 8 3 — 11 Loss on asset disposals — — 5 1 — 6 Operating income (loss) (17 ) (1 ) 611 (6 ) — 587 Other income (expense): Interest expense, net — (32 ) (7 ) (63 ) — (102 ) Other income, net — — 9 6 — 15 Income (loss) from subsidiaries 303 611 (46 ) 578 (1,446 ) — Income (loss) before income taxes 286 578 567 515 (1,446 ) 500 Income tax expense (benefit) (3 ) — — 92 — 89 Net income (loss) 289 578 567 423 (1,446 ) 411 Less: Net income attributable to noncontrolling interest — — — 122 — 122 Net income (loss) attributable to CVR Energy stockholders $ 289 $ 578 $ 567 $ 301 $ (1,446 ) $ 289 Condensed Consolidating Statement of Operations Year Ended December 31, 2017 Parent Subsidiary Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Intercompany Elimination Consolidated (in millions) Net sales $ — $ — $ 5,665 $ 331 $ (8 ) $ 5,988 Operating costs and expenses: Cost of materials and other — — 4,876 85 (8 ) 4,953 Direct operating expenses — — 441 157 — 598 Depreciation and amortization — — 129 74 — 203 Cost of sales — — 5,446 316 (8 ) 5,754 Selling, general and administrative expenses 15 1 14 83 — 113 Depreciation and amortization — — 8 3 — 11 Loss on asset disposals — — 3 — — 3 Operating income (loss) (15 ) (1 ) 194 (71 ) — 107 Other income (expense): Interest expense, net — (34 ) (11 ) (64 ) — (109 ) Other income, net — — 1 1 — 2 Income (loss) from subsidiaries 246 184 (88 ) 148 (490 ) — Income (loss) before income taxes 231 149 96 14 (490 ) — Income tax benefit (4 ) — — (213 ) — (217 ) Net income (loss) 235 149 96 227 (490 ) 217 Less: Net loss attributable to noncontrolling interest — — — (18 ) — (18 ) Net income (loss) attributable to CVR Energy stockholders $ 235 $ 149 $ 96 $ 245 $ (490 ) $ 235 Condensed Consolidating Statement of Operations Year Ended December 31, 2016 Parent Subsidiary Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Intercompany Elimination Consolidated (in millions) Net sales $ — $ — $ 4,432 $ 356 $ (6 ) $ 4,782 Operating costs and expenses: Cost of materials and other — — 3,780 93 (6 ) 3,867 Direct operating expenses — — 392 149 — 541 Depreciation and amortization — — 126 58 — 184 Cost of sales — — 4,298 300 (6 ) 4,592 Selling, general and administrative expenses 12 1 15 82 — 110 Depreciation and amortization — — 6 3 — 9 Loss on asset disposals — — — 1 — 1 Operating income (loss) (12 ) (1 ) 113 (30 ) — 70 Other income (expense): Interest expense, net — (32 ) (2 ) (49 ) — (83 ) Other income, net 5 — — (3 ) — 2 Income (loss) from subsidiaries 26 103 (64 ) 78 (143 ) — Income (loss) before income taxes 19 70 47 (4 ) (143 ) (11 ) Income tax benefit (6 ) — — (14 ) — (20 ) Net income (loss) 25 70 47 10 (143 ) 9 Less: Net loss attributable to noncontrolling interest — — — (16 ) — (16 ) Net income (loss) attributable to CVR Energy stockholders $ 25 $ 70 $ 47 $ 26 $ (143 ) $ 25 Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2018 Parent Subsidiary Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Intercompany Elimination Consolidated (in millions) Net cash provided by (used in) operating activities 38 (31 ) 687 (77 ) 3 620 Cash flows from investing activities: Capital expenditures (3 ) — (79 ) (20 ) — (102 ) Investment in affiliates, net of return of investment 202 630 679 435 (1,946 ) — Other investing activities — — — 2 — 2 Net cash provided by (used in) investing activities 199 630 600 417 (1,946 ) (100 ) Cash flows from financing activities: CVR Energy shareholder dividends (238 ) — — — — (238 ) CVR Refining unitholder distributions — — (93 ) — — (93 ) Distributions or intercompany advances to other CVR Energy subsidiaries — (422 ) (1,202 ) (319 ) 1,943 — Other financing activities — — (1 ) (2 ) — (3 ) Net cash provided by (used in) financing activities (238 ) (422 ) (1,296 ) (321 ) 1,943 (334 ) Net increase (decrease) in cash and cash equivalents (1 ) 177 (9 ) 19 — 186 Cash and cash equivalents, beginning of period 4 163 261 54 — 482 Cash and cash equivalents, end of period $ 3 $ 340 $ 252 $ 73 $ — $ 668 Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2017 Parent Subsidiary Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Intercompany Elimination Consolidated (in millions) Net cash provided by (used in) operating activities (30 ) (32 ) 273 (33 ) (10 ) 168 Cash flows from investing activities: Capital expenditures (4 ) — (101 ) (15 ) — (120 ) Investment in affiliates, net of return of investment 207 1,083 112 158 (1,636 ) (76 ) Net cash provided by (used in) investing activities 203 1,083 11 143 (1,636 ) (196 ) Cash flows from financing activities: CVR Energy dividends (174 ) — — — — (174 ) CVR Refining unitholder distributions — — (47 ) — — (47 ) CVR Partners unitholder distributions — — — (2 ) — (2 ) Distributions or intercompany advances to other CVR Energy subsidiaries — (1,190 ) (338 ) (118 ) 1,646 — Other financing activities — — (2 ) (1 ) — (3 ) Net cash provided by (used in) financing activities (174 ) (1,190 ) (387 ) (121 ) 1,646 (226 ) Net decrease in cash and cash equivalents (1 ) (139 ) (103 ) (11 ) — (254 ) Cash and cash equivalents, beginning of period 5 302 364 65 — 736 Cash and cash equivalents, end of period $ 4 $ 163 $ 261 $ 54 $ — $ 482 Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2016 Parent Subsidiary Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Intercompany Elimination Consolidated (in millions) Net cash provided by (used in) operating activities (29 ) (26 ) 380 (45 ) (13 ) 267 Cash flows from investing activities: Capital expenditures (10 ) — (102 ) (21 ) — (133 ) Acquisition of CVR Nitrogen, net of cash acquired — — — (64 ) — (64 ) Investment in affiliates, net of return of investment 214 227 (157 ) 281 (570 ) (5 ) Other investing activities — — 1 — — 1 Net cash provided by (used in) investing activities 204 227 (258 ) 196 (570 ) (201 ) Cash flows from financing activities: Proceeds on issuance of 2023 Notes, net of original issue discount — — — 629 — 629 Principal and premium payments on 2021 Notes — — — (322 ) — (322 ) Payments of revolving debt — — — (49 ) — (49 ) Principal payments on CRNF credit facility — — — (125 ) — (125 ) CVR Energy shareholder dividends (174 ) — — — — (174 ) CVR Partners unitholder distributions — — — (42 ) — (42 ) Distributions or intercompany advances to other CVR Energy subsidiaries — (69 ) (280 ) (234 ) 583 — Other financing activities (11 ) — (1 ) — — (12 ) Net cash provided by (used in) financing activities (185 ) (69 ) (281 ) (143 ) 583 (95 ) Net increase (decrease) in cash and cash equivalents (10 ) 132 (159 ) 8 — (29 ) Cash and cash equivalents, beginning of period 15 170 523 57 — 765 Cash and cash equivalents, end of period $ 5 $ 302 $ 364 $ 65 $ — $ 736

Selected Quarterly Financial In

Selected Quarterly Financial Information	12 Months Ended
	Dec. 31, 2018
Quarterly Financial Information Disclosure [Abstract]
Selected Quarterly Financial Information	(15) Selected Quarterly Financial Information Summarized quarterly financial data for December 31, 2018 and 2017 is as follows: Year Ended December 31, 2018 Quarter (in millions) First Second Third Fourth Net sales $ 1,536 $ 1,915 $ 1,935 $ 1,737 Cost of materials and other (a) 1,179 1,560 1,556 1,387 Direct operating expenses (a) 132 141 120 130 Operating income 150 121 179 138 Net income 104 80 121 106 Net income attributable to noncontrolling interest 38 30 31 24 Net income attributable to CVR Energy stockholders $ 66 $ 50 $ 90 $ 82 Basic and diluted earnings per share $ 0.76 $ 0.59 $ 0.94 $ 0.82 Dividends declared per share $ 0.50 $ 0.50 $ 0.75 $ 0.75 Weighted-average common shares outstanding - basic and diluted 86.8 86.8 95.8 100.5 Year Ended December 31, 2017 Quarter (in millions) First Second Third Fourth Net sales $ 1,507 $ 1,434 $ 1,454 $ 1,593 Cost of materials and other (a) 1,209 1,229 1,149 1,366 Direct operating expenses (a) 138 124 162 175 Operating income (loss) 80 1 61 (36 ) Net income (loss) 38 (19 ) 25 173 Net income (loss) attributable to noncontrolling interest 16 (8 ) 3 (27 ) Net income (loss) attributable to CVR Energy stockholders $ 22 $ (11 ) $ 22 $ 200 Basic and diluted earnings (loss) per share $ 0.26 $ (0.12 ) $ 0.26 $ 2.31 Dividends declared per share $ 0.50 $ 0.50 $ 0.50 $ 0.50 Weighted-average common shares outstanding - basic and diluted 86.8 86.8 86.8 86.8 _______________________________________ (a) Excludes depreciation and amortization expenses.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2018
Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation The accompanying consolidated financial statements include the accounts of the Company and its majority-owned direct and indirect subsidiaries. All intercompany accounts and transactions have been eliminated. The ownership interests of noncontrolling investors in the Company’s subsidiaries are recorded as noncontrolling interests. CVR Energy has not recognized any other comprehensive income for the periods ended December 31, 2018, 2017 and 2016. CVR Refining and CVR Partners are considered variable interest entities (“VIE”). As the 100% owner of the general partner for both CVR Refining and CVR Partners, the Company has the sole ability to direct the activities that most significantly impact the economic performance of both partnerships and is considered to be the primary beneficiary. In January 2019, following the CVRR Unit Purchase, CVR Refining is no longer considered to be a VIE, and will be accounted for as a wholly-owned subsidiary. Investments in entities over which the Company has significant influence, but not control, are accounted for using the equity method of accounting. Income from equity method investments represents CVR Energy’s proportionate share of net income generated by the equity method investees and is recorded in other income, net on the Company’s Consolidated Statements of Operations.
Use of Estimates	Use of Estimates These consolidated financial statements are prepared in conformity with accounting principles generally accepted in the United States of America (“GAAP”), which requires management to make estimates and assumptions that affect the reported amounts and disclosure of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Estimates are reviewed on an ongoing basis, based on currently available information. Changes in facts and circumstances may result in revised estimates and actual results could differ from those estimates.
Cash and Cash Equivalents	Cash and Cash Equivalents Cash and cash equivalents include cash on hand and on deposit and investments in highly liquid money market accounts and debt instruments with original maturities of three months or less.
Accounts Receivable, net	Accounts Receivable, net Accounts receivable primarily consist of customer accounts receivable recorded at the invoiced amounts and generally do not bear interest. Also included within accounts receivable of the Nitrogen Fertilizer Segment are unbilled fixed price contracts recognized with the adoption of ASC 606 (defined below) as discussed further within the “Recent Accounting Pronouncements - Adoption of Revenue Recognition Standard” section to this note below. Allowances for doubtful accounts are generally recorded when it becomes probable the receivable will not be collected and is booked to bad debt expense.
Inventories	Inventories Inventories consist primarily of domestic and foreign crude oil, blending stock and components, work-in-progress, fertilizer products, and refined fuels and by-products. All inventories are valued at the lower of the first-in, first-out (“FIFO”) cost, or net realizable value. Refinery unfinished and finished products inventory values were determined using the ability-to-bear methodology. Other inventories, including other raw materials, spare parts, and supplies, are valued at the lower of moving-average cost, which approximates FIFO, or net realizable value. The cost of inventories includes inbound freight costs.
Property, Plant and Equipment	Property, Plant and Equipment Additions to property, plant and equipment, including capitalized interest and certain costs allocable to construction and property purchases, are recorded at cost. Expenditures for improvements that increase economic benefit or returns and/or extend useful life are capitalized. Depreciation is computed using the straight-line method over the estimated useful lives of the various classes of depreciable assets. The lives used in computing depreciation for significant asset classes are as follows: Asset Range of Useful Lives, in Years Land improvements 15 to 30 Buildings 20 to 30 Machinery and equipment 5 to 30 Other 5 to 30 Property, plant and equipment consisted of the following: December 31, (in millions) 2018 2017 Land and improvements $ 43 $ 47 Buildings 82 83 Machinery and equipment 3,754 3,734 Other 203 155 4,082 4,019 Less: Accumulated depreciation 1,637 1,431 Total Property, plant and equipment, net $ 2,445 $ 2,588 Leasehold improvements and assets held under capital leases are depreciated or amortized on the straight-line method over the shorter of the contractual lease term or the estimated useful life of the asset. Expenditures for routine maintenance and repair costs are expensed when incurred. Such expenses are reported in direct operating expenses in the Company’s Consolidated Statements of Operations. During the period, the Petroleum Segment began actively marketing certain assets with a carrying value of $33 million at December 31, 2018. The carrying value of these assets held for sale were included in Other Long-term Assets on the Company’s Condensed Consolidated Balance Sheets. No loss has been recognized upon designation of these assets as held for sale.
Deferred Financing Costs	Deferred Financing Costs Lender and other third-party costs associated with debt issuances are deferred and amortized to interest expense and other financing costs using the effective-interest method over the life of the debt. Deferred financing costs related to line-of-credit arrangements are amortized using the straight-line method through the termination date of the facility. The deferred financing costs are included net within long-term debt and in other long-term assets for the line-of-credit arrangements where no debt balance exists.
Impairment of Long-Lived Assets	Impairment of Long-Lived Assets Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to estimated undiscounted future net cash flows expected to be generated by the asset. If the carrying amount of an asset exceeds its estimated undiscounted future net cash flows, an impairment charge is recognized for the amount by which the carrying amount of the assets exceeds their fair value. Assets to be disposed of by sale are reported at the lower of their carrying value or fair value less cost to sell. Goodwill represents the excess of the cost of an acquired entity over the fair value of the assets acquired less liabilities assumed. Intangible assets are assets that lack physical substance (excluding financial assets). Goodwill acquired in a business combination and intangible assets with indefinite useful lives are not amortized, and intangible assets with finite useful lives are amortized. Goodwill and intangible assets not subject to amortization are tested for impairment annually or more frequently if events or changes in circumstances indicate the asset might be impaired. November 1 of each year is used as the annual valuation date for its goodwill impairment test.
Loss Contingencies	Loss Contingencies In the ordinary course of business, the Company may become party to lawsuits, administrative proceedings and governmental investigations, including environmental, regulatory and other matters. The outcome of these matters cannot always be predicted accurately, but the Company accrues liabilities for these matters if the Company has determined that it is probable a loss has been incurred and the loss can be reasonably estimated.
Environmental, Health & Safety (EHS) Matters	Environmental, Health & Safety (“EHS”) Matters The Petroleum and Nitrogen Fertilizer Segments are subject to various 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, internal and third party assessments of contamination, available remediation technology, site-specific costs, and currently enacted laws and regulations. In reporting environmental liabilities, no offset is made for potential recoveries. Loss contingency accruals, including those for environmental remediation, are subject to revision as further information develops or circumstances change and such accruals can take into account the legal liability of other parties. Environmental expenditures are capitalized at the time of the expenditure when such costs provide future economic benefits.
Revenue Recognition and Cost Classifications	Revenue Recognition The Company recognizes revenue based on consideration specified in contracts or agreements with customers when performance obligations are satisfied by transferring control over products or services to a customer. The adoption of ASC 606, described below, did not materially change the Company’s revenue recognition patterns, which are described below by reportable segment: • Petroleum Segment - The vast majority of Petroleum Segment contracts contain pricing that is based on the market price for the product at the time of delivery. Obligations to deliver product volumes are typically satisfied and revenue is recognized when control of the product transfers to customers. Concurrent with the transfer of control, the right to payment for the delivered product is received, the customer accepts the product and the customer has significant risks and rewards of ownership of the product. Payment terms require customers to pay shortly after delivery and do not contain significant financing components. Any pass-through finished goods delivery costs reimbursed by customers are reported in net sales, while an offsetting expense is included in cost of materials and other. Non-monetary product exchanges and certain buy/sell transactions which are entered into in the normal course of business are included on a net cost basis in operating expenses on the Consolidated Statements of Operations. • Nitrogen Fertilizer Segment - Revenue is recognized when our customers receive control of the product. The adoption of ASC 606 resulted in the recognition of deferred revenue which represents customer prepayments under contracts that guarantee a price and supply of nitrogen fertilizer product in quantities expected to be delivered in the normal course of business. Other considerations - For both segments, excise and other taxes collected from customers and remitted to governmental authorities are excluded from reported revenues. Cost Classifications Cost of materials and other (exclusive of depreciation and amortization) includes cost of crude oil, other feedstocks, blendstocks, purchased refined products, pet coke expenses, renewable identification numbers (“RINs”) expenses, derivative gain or losses and freight and distribution costs. Direct operating expenses (exclusive of depreciation and amortization) consist primarily of energy and other utility costs, direct costs of labor, including applicable share-based compensation expense, property taxes, plant-related maintenance services, including turnaround, and environmental and safety compliance costs as well as catalyst and chemical costs. Selling, general and administrative expenses consist primarily of labor and other direct expenses associated with the Company’s corporate activities, including accounting, finance, information technology, human resources, legal and other related administrative functions. For the Company’s Nitrogen Fertilizer Segment, each of these financial statement line items are also impacted by changes in inventory balances.
Derivatives and Fair Value of Financial Instruments	Derivatives and Fair Value of Financial Instruments The Petroleum Segment uses futures contracts, options, and forward contracts primarily to reduce exposure to changes in crude oil and finished goods product prices to provide economic hedges of inventory positions. These derivative instruments do not qualify as hedges for hedge accounting purposes under ASC Topic 815, Derivatives and Hedging , and accordingly are recorded at fair value at the end of each reporting period based on quoted market prices. The Nitrogen Fertilizer Segment may enter into forward contracts with fixed delivery prices to purchase portions of its natural gas requirements. These natural gas contracts are not treated as derivative under normal purchase and normal sale exclusions. Accordingly, the fair value of these contracts are not recorded at the end of each reporting period. Refer to Note 7 (“Derivatives and Fair Value of Financial Instruments”) for further discussion of the Company’s derivative activity. Other financial instruments consisting of cash and cash equivalents, accounts receivable, and accounts payable are carried at cost, which approximates fair value, as a result of the short-term nature of the instruments. Refer to Note 7 (“Derivatives and Fair Value of Financial Instruments”) for further fair value disclosures.
Turnaround Expenses	Turnaround Expenses The direct-expense method of accounting is used for turnaround activities. Turnarounds represent major maintenance activities that require the shutdown of significant parts of a plant to perform necessary inspection, cleaning, repairs and replacements of assets. Costs incurred for routine repairs and maintenance or unplanned outages at our facilities are expensed as incurred. Planned turnaround activities for the Petroleum Segment vary in frequency dependent on refinery units, but generally occur every four to five years . The frequency of turnarounds in the Nitrogen Fertilizer segment is every two to three years . Costs associated with these turnaround activities were included in Direct Operating Expenses (exclusive of depreciation and amortization) in the Consolidated Statements of Operations.
Share-Based Compensation	Share-Based Compensation The Company accounts for share-based compensation in accordance with ASC Topic 718, Compensation — Stock Compensation (“ASC 718”). Currently, all of the Company’s share-based compensation awards, including those issued by CVR Refining and CVR Partners, are liability-classified and are measured at fair value at the end of each reporting period based on the applicable closing unit price. Compensation expense will fluctuate based on changes in the applicable share or unit prices and expense reversals resulting from employee terminations prior to award vesting. Additionally, the Company has issued certain performance unit awards. The fair value of these performance unit awards is recognized as compensation expense only if the attainment of the performance conditions is considered probable. Uncertainties involved in this estimate include continued employment requirements and whether or not the performance conditions will be attained. The performance objectives are set in accordance with approved levels of the business plan for the fiscal year during the performance cycle and therefore are considered reasonably possible of being achieved. If this assumption proves not to be true and the awards do not vest, compensation expense recognized during the performance cycle will be reversed.
Income Taxes	Income Taxes Income taxes are accounted for utilizing the asset and liability approach. Under this method, deferred tax assets and liabilities are recognized for the anticipated future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis. Deferred amounts are measured using enacted tax rates expected to apply to taxable income in the year those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date.
Earnings Per Share	Earnings Per Share There were no dilutive awards outstanding during the years ended December 31, 2018, 2017, and 2016.
Recent Accounting Pronouncements	Recent Accounting Pronouncements - Adoption of New Accounting Standard On January 1, 2018, the Company adopted Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“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 prior 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. The adoption of ASC 606 resulted in changes to how the Nitrogen Fertilizer Segment accounts for prepaid contracts. Prior to the adoption of ASC 606, deferred revenue was recorded upon customer prepayment, however, under the new revenue standard, deferred revenue and an associated receivable is recorded at the point in time in which a prepaid contract is legally enforceable and the associated right to consideration is unconditional. Due to this change, the adoption of ASC 606 resulted in a $21 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 CVR Partners were $34 million and $31 million , respectively, as of January 1, 2018. In addition to the change noted above, the adoption of ASC 606 also resulted in a change in accounting for fees collected from certain customers by the Petroleum Segment that 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 CVR Refining’s customers on product sales and is required under the new standard to be included in the transaction price. The impact of the change in presentation was an increase of $2 million to net sales and cost of materials and other for the period ended December 31, 2018. The following table displays the effect of the changes to the Consolidated Balance Sheet as of December 31, 2018 for the adoption of ASC 606. The Company’s Consolidated Statement of Cash Flows was not impacted due to the adoption of ASC 606 for the period ended December 31, 2018. (in millions) December 31, 2018 As Reported Balances without adoption of ASC 606 Effect of change Assets Accounts Receivable $ 169 $ 124 $ 45 Liabilities Deferred Revenue (1) $ 69 $ 24 $ 45 _____________________________ (1) Deferred Revenues are recorded within the Other Current Liabilities financial statement line item. Recent Accounting Pronouncements - 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” (“ Topic 842 ”) , 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 of the underlying asset for the lease term on the balance sheet. Quantitative and qualitative disclosures, including disclosures regarding significant judgments made by management, will be required. Topic 842 was adopted by the FASB as of January 1, 2019 electing the option to apply the transition provisions at the adoption date instead of the earliest comparative period presented in the financial statements. In connection with the adoption of ASC 842, the following elections were made in the application of Topic 842: • Under the short-term lease exception provided for in the standard, ROU assets and related lease liabilities for leases with a term greater than one year were and will be recognized; • The accounting treatment for existing land easements was carried forward; • Lease and non-lease components were and will not be bifurcated for all of the Company’s asset groups; and • The portfolio approach was and will be used in the selection of the discount rate used to calculate minimum lease payments and the related ROU asset and operating lease liability amounts. Adoption of Topic 842 resulted in the recording of additional ROU assets and lease liabilities of approximately $53 million , in addition to the recognition of a finance lease asset and obligation of approximately $26 million , as of January 1, 2019. The standard will not materially affect the Company’s consolidated net earnings or cash flows. In August 2018, the FASB issued ASU 2018-15, Intangibles-Goodwill and Other-Internal-Use Software (Subtopic 350-40). This ASU addresses customer’s accounting for implementation costs incurred in a cloud computing arrangement that is a service contract and also adds certain disclosure requirements related to implementation costs incurred for internal-use software and cloud computing arrangements. The amendment aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software (and hosting arrangements that include an internal-use software license). This standard is effective for the Company beginning January 1, 2020, with early adoption permitted. The amendments in this standard can be applied either retrospectively or prospectively to all implementation costs incurred after the date of adoption. The Company is evaluating the effect of adopting this new accounting guidance on its consolidated financial statements, but does not expect adoption will have a material impact on the Company’s consolidated financial position or results of operations. In August 2018, the FASB issued ASU 2018-13, Fair Value Measurement (Topic 820). The ASU eliminates such disclosures as the amount of and reasons for transfers between Level 1 and Level 2 of the fair value hierarchy. Certain disclosures are required to be applied on a retrospective basis and others on a prospective basis. This standard is effective for the Company beginning January 1, 2020, with early adoption permitted. The Company is evaluating the effect of adopting this new accounting guidance, but does not expect adoption will have a material impact on the Company's disclosures.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2018
Accounting Policies [Abstract]
Schedule of inventories	Inventories consisted of the following: December 31, (in millions) 2018 2017 Finished goods $ 186 $ 172 Raw materials 105 98 In-process inventories 12 22 Parts and supplies 77 77 Total Inventories $ 380 $ 369
Schedule of lives used in computing depreciation for depreciable assets and components of property, plant and equipment	The lives used in computing depreciation for significant asset classes are as follows: Asset Range of Useful Lives, in Years Land improvements 15 to 30 Buildings 20 to 30 Machinery and equipment 5 to 30 Other 5 to 30 Property, plant and equipment consisted of the following: December 31, (in millions) 2018 2017 Land and improvements $ 43 $ 47 Buildings 82 83 Machinery and equipment 3,754 3,734 Other 203 155 4,082 4,019 Less: Accumulated depreciation 1,637 1,431 Total Property, plant and equipment, net $ 2,445 $ 2,588
Effect of the change to Condensed Consolidated Balance Sheet	The following table displays the effect of the changes to the Consolidated Balance Sheet as of December 31, 2018 for the adoption of ASC 606. The Company’s Consolidated Statement of Cash Flows was not impacted due to the adoption of ASC 606 for the period ended December 31, 2018. (in millions) December 31, 2018 As Reported Balances without adoption of ASC 606 Effect of change Assets Accounts Receivable $ 169 $ 124 $ 45 Liabilities Deferred Revenue (1) $ 69 $ 24 $ 45 _____________________________ (1) Deferred Revenues are recorded within the Other Current Liabilities financial statement line item.

Equity Method Investments (Tabl

Equity Method Investments (Tables)	12 Months Ended
	Dec. 31, 2018
Equity Method Investments and Joint Ventures [Abstract]
Schedule of equity method investments	(in millions) Enable JV Midway JV Total Balance at December 31, 2016 6 — — 6 Contributions 1 — 76 77 Cash Distributions (1 ) — (1 ) Equity income — — 1 1 Balance at December 31, 2017 6 77 83 Cash Distributions (2 ) (5 ) (7 ) Equity income 2 6 8 Balance at December 31, 2018 $ 6 $ 78 $ 84

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2018
Debt Disclosure [Abstract]
Schedule of long-term debt	(in millions) December 31, 2018 December 31, 2017 CVR Partners: 9.25% Senior Secured Notes due June 2023 (a) $ 645 $ 645 6.50% Senior Notes due April 2021 2 2 Unamortized discount and debt issuance costs (18 ) (22 ) Total CVR Partners Debt $ 629 $ 625 CVR Refining: 6.50% Senior Notes due November 2022 (b) $ 500 $ 500 Capital lease obligations 44 45 Unamortized debt issuance cost (3 ) (4 ) Current portion of capital lease obligations (3 ) (2 ) Total CVR Refining Debt $ 538 $ 539 Total Long-Term Debt $ 1,167 $ 1,164 (a) This debt was issued at a $16 million discount which is being amortized, as interest expense, over the remaining term of the debt. Debt issuance costs associated with this debt totaled $9 million . (b) Debt issuance costs associated with this debt totaled $9 million . On January 29, 2019, the 2022 Senior Notes were amended such that CVR Refining was replaced by CVR Energy Inc. as the primary guarantor, on a senior unsecured basis, of the 2022 Senior Notes. The CVR Energy Inc. guarantee is full and unconditional and joint and several. See Note 15 ("Guarantor") for further discussion and implications of this change to guarantor. Credit Facilities (in millions) Total Capacity Amount Borrowed as of December 31, 2018 Outstanding Letters of Credit Available Capacity as of December 31, 2018 Maturity Date Amended and Restated Asset Based (ABL) Credit Facility (c) $ 400 $ — $ 6 $ 394 November 14, 2022 Asset Based (ABL) Credit Facility (d) 50 — — 50 September 30, 2021 (c) Loans under the Amended and Restated ABL Credit Facility initially bear interest at an annual rate equal to (i) 1.50% plus LIBOR or (ii) 0.50% plus a base rate, subject to quarterly excess availability. (d) 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.
Schedule of future payments required under capital lease	Future payments required under these capital lease at December 31, 2018 are as follows: Year Ending December 31, Capital Lease (in millions) 2019 - 2023 (annually $7 million) $ 35 Thereafter 37 Total future payments 72 Less: amount representing interest 28 Present value of future minimum payments 44 Less: current portion 3 Long-term portion $ 41

Revenue (Tables)

Revenue (Tables)	12 Months Ended
	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Revenue disaggregated by major product	The following tables present the Company’s revenue disaggregated by major product. The following tables include a reconciliation of the disaggregated revenue by product and other revenue components for the Company’s reportable segments. Year Ended December 31, 2018 (in millions) Petroleum Nitrogen Fertilizer Other / Eliminations Consolidated Gasoline $ 3,383 $ — $ — $ 3,383 Distillates (a) 3,067 — — 3,067 Ammonia — 66 — 66 UAN — 222 — 222 Other urea products — 21 — 21 Freight revenue 23 34 — 57 Other (b) 206 8 (7 ) 207 Revenue from product sales 6,679 351 (7 ) 7,023 Crude oil sales 96 — — 96 Other revenue (b) 5 — — 5 Total revenue $ 6,780 $ 351 $ (7 ) $ 7,124 (a) Distillates consist primarily of diesel fuel, kerosene and jet fuel. (b) Other revenue consists primarily of feedstock and asphalt sales and Cushing, OK storage tank lease revenue. See Note 2 (“Summary of Significant Accounting Policies”) for further discussion.
Summary of deferred revenue activity	A summary of the Nitrogen Fertilizer Segment’s deferred revenue activity during the year ended December 31, 2018 is presented below: (in millions) Year Ended December 31, 2018 Balance at January 1, 2018 $ 34 Add: New prepay contracts entered into during the period, net of adjustments 92 Less: Revenue recognized that was included in the contract liability balance at the beginning of the period 34 Revenue recognized related to contracts entered into during the period 23 Balance at December 31, 2018 $ 69

Derivative Financial Instrume_2

Derivative Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Gain (loss) on derivatives	The following outlines the gains (losses) recognized on the Company’s derivative activities, all of which are recorded in Cost of Materials and Other on the Consolidated Statements of Operations: Gain (Loss) on Derivatives by Type Year Ended December 31, (in millions) 2018 2017 2016 Forward purchases $ 103 $ (26 ) $ — Swaps 44 (43 ) (19 ) Futures (1 ) (1 ) — Total gain (loss) on derivatives, net $ 146 $ (70 ) $ (19 )
Schedule of open commodity derivative instruments	The following outlines the open positions (in millions of barrels) held by the Petroleum Segment as of December 31, 2018 and 2017: Open Commodity Derivative Instruments Year Ended December 31, 2018 2017 Commodity Swap Instruments: 2-1-1 Crack spreads — 7 Distillate Crack spreads — 4 Gasoline Crack spreads — 4 Purchase and Sale Commitments - Futures Contracts: Canadian crude oil 2 6
Derivative offsetting assets	These amounts are recognized as current assets and current liabilities within the prepaid expenses and other current assets and accrued expenses and other current liabilities financial statement line items, respectively, in the Consolidated Balance Sheets as follows: Derivative Assets Derivative Liabilities December 31, December 31, (in millions) 2018 2017 2018 2017 Commodity Derivatives $ 8 $ 7 $ 1 $ 71 Less: Counterparty Netting (1 ) (7 ) (1 ) (7 ) Total Net Fair Value of Derivatives $ 7 $ — $ — $ 64
Derivative offsetting liabilities	These amounts are recognized as current assets and current liabilities within the prepaid expenses and other current assets and accrued expenses and other current liabilities financial statement line items, respectively, in the Consolidated Balance Sheets as follows: Derivative Assets Derivative Liabilities December 31, December 31, (in millions) 2018 2017 2018 2017 Commodity Derivatives $ 8 $ 7 $ 1 $ 71 Less: Counterparty Netting (1 ) (7 ) (1 ) (7 ) Total Net Fair Value of Derivatives $ 7 $ — $ — $ 64
Schedule of assets and liabilities measured at fair value on a recurring basis	The following table sets forth the assets and liabilities measured or disclosed at fair value on a recurring basis, by input level, as of December 31, 2018 and 2017 : December 31, 2018 (in millions) Level 1 Level 2 Level 3 Total Location and Description Cash equivalents $ 50 $ — $ — $ 50 Other current assets (commodity derivatives) — 7 — 7 Total Assets $ 50 $ 7 $ — $ 57 Other current liabilities (Renewable Fuel Standard “RFS” obligation) — (2 ) — (2 ) Long-term debt — (1,163 ) — (1,163 ) Total Liabilities $ — $ (1,165 ) $ — $ (1,165 ) December 31, 2017 (In millions) Level 1 Level 2 Level 3 Total Location and Description Cash equivalents $ 15 $ — $ — $ 15 Total Assets $ 15 $ — $ — $ 15 Other current liabilities (commodity derivatives) $ — $ (64 ) $ — $ (64 ) Other current liabilities (RFS obligation) — (1 ) — (1 ) Long-term debt — (1,209 ) — (1,209 ) Total Liabilities $ — $ (1,274 ) $ — $ (1,274 )

Share-Based Compensation (Table

Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of share-based compensation activity	A summary of total share based compensation expense and unrecognized compensation expense related to the Share-Based Awards and Company’s performance awards, the amounts allocated to each of the Company’s segments, and the amounts that were not allocated to segments during the years ended December 31, 2018 , 2017 and 2016 is presented below: Expenses Unrecognized Expense For the year ended December 31, At December 31, 2018 (in millions) 2018 2017 2016 Amount Weighted Average Remaining Years Share based awards Incentive Units $ 4 $ 7 $ 2 $ 15 1.7 Phantom Units 8 8 3 4 1.6 Performance awards CEO Performance Award 2 — — 8 3.0 2018 CEO Performance Award 2 — — — 0.0 Former CEO Performance Award — 4 4 — 0.0 Total expense $ 16 $ 19 $ 9 $ 27 A summary of activity for the Company’s Share-Based Awards for the years ended December 31, 2018 , 2017 and 2016 is presented below: Shares or Units Weighted- (Per Share or Unit) Aggregate (In Millions) Non-vested at December 31, 2016 2,664,438 $ 10.76 $ 24 Granted 1,713,192 8.52 Vested (1,062,382 ) 11.62 Forfeited (361,301 ) 12.29 Non-vested at December 31, 2017 2,953,947 $ 8.97 $ 33 Granted 1,236,322 16.11 Vested (1,140,423 ) 9.74 Forfeited (617,773 ) 9.39 Non-vested December 31, 2018 2,432,073 $ 12.13 $ 24

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Schedule of income tax expense (benefit)	Income tax expense (benefit) is comprised of the following: Year Ended December 31, (in millions) 2018 2017 2016 Current: Federal $ 31 $ (1 ) $ 67 State (7 ) (22 ) (7 ) Total current 24 (23 ) 60 Deferred: Federal 47 (181 ) (61 ) State 18 (13 ) (19 ) Total deferred 65 (194 ) (80 ) Total income tax expense (benefit) $ 89 $ (217 ) $ (20 )
Schedule of reconciliation of total income tax expense (benefit) to income tax expense (benefit) computed by applying the statutory federal income tax rate to pre-tax income (loss)	The following is a reconciliation of total income tax expense (benefit) to income tax expense (benefit) computed by applying the statutory federal income tax rate to pretax income (loss): Year Ended December 31, (in millions) 2018 2017 2016 Tax computed at federal statutory rate $ 105 $ — $ (4 ) State income taxes, net of federal tax benefit 14 (16 ) (8 ) State tax incentives, net of federal tax expense (4 ) (7 ) (9 ) Noncontrolling interest (26 ) 6 6 Other, net — — (5 ) Adjustment to deferred tax assets and liabilities for enacted change in federal tax rate (a) — (200 ) — Total income tax expense (benefit) $ 89 $ (217 ) $ (20 ) (a) The income tax benefit for the year ended December 31, 2017 was favorably impacted as a result of the Tax Cuts and Jobs Act legislation that was signed into law in December 2017, reducing the federal income tax rate from 35% to 21% beginning in 2018. As a result, the Company’s net deferred tax liabilities at December 31, 2017 were remeasured to reflect the lower tax rate that will be in effect for the years in which the deferred tax assets and liabilities will be realized.
Schedule of income tax effect of temporary differences that give rise to significant portions of the deferred income tax assets and deferred income tax liabilities	The income tax effect of temporary differences that give rise to significant portions of the deferred income tax assets and deferred income tax liabilities at December 31, 2018 and 2017 are as follows: December 31, (in millions) 2018 2017 Deferred income tax assets: State tax credit carryforward, net $ 11 $ 11 Net operating loss carryforward — 7 Total gross deferred income tax assets 11 18 Deferred income tax liabilities: Investment in CVR Partners (59 ) (55 ) Investment in CVR Refining (309 ) (345 ) Other (5 ) (4 ) Total gross deferred income tax liabilities (373 ) (404 ) Net deferred income tax liabilities $ (362 ) $ (386 )
Schedule of reconciliation of the unrecognized tax benefits	A reconciliation of unrecognized tax benefits is as follows: Year Ended December 31, (in millions) 2018 2017 2016 Balance beginning of year $ 29 $ 44 $ 49 Reductions related to expirations of statute of limitations (6 ) (15 ) (5 ) Balance end of year $ 23 $ 29 $ 44

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Schedule of minimum required payments for CVR's operating lease agreements and unconditional purchase obligations	The minimum required payments for CVR’s operating lease agreements and unconditional purchase obligations are as follows: Year Ending December 31, Operating Leases Unconditional Purchase Obligations (in millions) 2019 $ 24 $ 129 2020 20 89 2021 18 78 2022 16 76 2023 12 75 Thereafter 26 444 $ 116 $ 891 Leases - The Company leases equipment, including railcars and real properties, under long-term operating leases. For the years ended December 31, 2018, 2017 and 2016, rent expense totaled approximately $10 million , $8 million and $8 million , respectively. Supply Commitments - The Company is a party to various supply agreements with both related and third parties which commit the Company to purchase minimum volumes of crude oil, hydrogen, oxygen, nitrogen, petroleum coke (“pet coke”), and natural gas to run its facilities’ operations. For the years ended December 31, 2018, 2017 and 2016. amounts purchased under these supply agreements totaled approximately $214 million , $209 million , and $151 million , respectively.

Business Segments (Tables)

Business Segments (Tables)	12 Months Ended
	Dec. 31, 2018
Segment Reporting [Abstract]
Schedule of segment information	The following tables summarize operating results, capital expenditures, and total asset information by segment: Year Ended December 31, (in millions) 2018 2017 2016 Net sales Petroleum $ 6,780 $ 5,664 $ 4,431 Nitrogen Fertilizer 351 331 356 Other (7 ) (7 ) (5 ) Total net sales $ 7,124 $ 5,988 $ 4,782 Operating income (loss) Petroleum $ 599 $ 134 $ 58 Nitrogen Fertilizer 6 (10 ) 26 Other (18 ) (17 ) (14 ) Total operating income (loss) $ 587 $ 107 $ 70 Interest expense, net (102 ) (109 ) (83 ) Other income, net 15 2 2 Earnings before income taxes 500 — (11 ) Depreciation and amortization Petroleum 134 133 129 Nitrogen Fertilizer 72 74 58 Other 7 7 6 Total depreciation and amortization 213 214 193 Capital expenditures Petroleum $ 79 $ 101 $ 102 Nitrogen fertilizer 19 14 23 Other 4 5 8 Total $ 102 $ 120 $ 133 Year Ended December 31, (in millions) 2018 2017 2016 Total assets Petroleum $ 2,360 $ 2,270 $ 2,332 Nitrogen Fertilizer 1,254 1,234 1,312 Other 293 303 406 Total $ 3,907 $ 3,807 $ 4,050

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2018
Supplemental Cash Flow Elements [Abstract]
Schedule of supplemental cash flow information related to income taxes, interest, construction in process and dividends	Supplemental cash flow information related to income taxes, interest, and capital expenditures is as follows: Year Ended December 31, (in millions) 2018 2017 Supplemental disclosures: Cash paid for income taxes, net of refunds $ 31 $ 15 Cash paid for interest 103 106 Non-cash investing and financing activities: Construction in progress additions included in accounts payable $ 17 $ 8 Change in accounts payable related to construction in progress additions 9 (5 ) Landlord incentives for leasehold improvements — 1

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2018
Related Party Transactions [Abstract]
Schedule of related party transactions	Activity associated with the Company’s related party arrangements for the years ended December 31, 2018 , 2017 , and 2016 is summarized below: Expenses with related parties Year ended December 31, (in millions) 2018 2017 2016 Cost of materials and other Joint Venture Transportation Agreement: Enable JV $ 8 $ 2 $ — Payments made Dividends (1) 179 $ 142 142 Tax Allocation Agreement with AEP 12 15 45 Amounts due to/from related parties (in millions) December 31, 2018 December 31, 2017 Accounts Receivable (Payable) Tax Allocation Agreement with AEP $ 4 $ 5 _____________________________ (1) See below for a summary of the dividends paid to IEP for the periods ended December 31, 2018, 2017, and 2016.
Schedule of dividends paid	The following is a summary of the quarterly and special dividends paid to stockholders, including IEP and its affiliates during the years ended December 31, 2018 and 2017 : (in millions) December 31, 2017 March 31, 2018 June 30, 2018 September 30, 2018 Total Dividends Paid in 2018 Amount paid to IEP $ 36 $ 36 $ 53 $ 54 $ 179 Amounts paid to public stockholders 7 8 22 22 59 Total amount paid $ 43 $ 44 $ 75 $ 76 $ 238 Per common share $ 0.50 $ 0.50 $ 0.75 $ 0.75 $ 2.50 (in millions) December 31, 2016 March 31, 2017 June 30, 2017 September 30, 2017 Total Dividends Amount paid to IEP $ 35 $ 36 $ 35 $ 36 $ 142 Amounts paid to public stockholders 8 8 8 8 32 Total amount paid $ 43 $ 44 $ 43 $ 44 $ 174 Per common share $ 0.50 $ 0.50 $ 0.50 $ 0.50 $ 2.00 (in millions) December 31, 2015 March 31, 2016 June 30, 2016 September 30, 2016 Total Dividends Amount paid to IEP $ 35 $ 36 $ 35 $ 36 $ 142 Amounts paid to public stockholders 8 8 8 8 32 Total amount paid $ 43 $ 44 $ 43 $ 44 $ 174 Per common share $ 0.50 $ 0.50 $ 0.50 $ 0.50 $ 2.00

Guarantor (Tables)

Guarantor (Tables)	12 Months Ended
	Dec. 31, 2018
Condensed Financial Information Disclosure [Abstract]
Guarantor Consolidating Balance Sheet	Condensed Consolidating Balance Sheet December 31, 2018 Parent Subsidiary Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Intercompany Elimination Consolidated (in millions) ASSETS Current assets: Cash and cash equivalents $ 3 $ 340 $ 252 $ 73 $ — $ 668 Accounts receivable — — 107 62 — 169 Intercompany receivable 6 — 4 — (10 ) — Inventories — — 316 64 — 380 Prepaid expenses and other current assets 31 1 47 5 (8 ) 76 Total current assets 40 341 726 — 204 — (18 ) — 1,293 Property, plant and equipment, net of accumulated depreciation — — 1,425 1,020 — 2,445 Investment in and advances from subsidiaries 1,192 1,601 173 1,440 (4,406 ) — Other long-term assets — 1 123 45 — 169 Total assets $ 1,232 $ 1,943 $ 2,447 200,000 $ 2,709 200,000 $ (4,424 ) 200,000 $ 3,907 LIABILITIES AND PARTNERS' CAPITAL Current liabilities: Note payable and capital lease obligations $ — $ — $ 3 $ — $ — $ 3 Accounts payable 1 — 291 29 (1 ) 320 Intercompany payables — — — 10 (10 ) — Other current liabilities 6 7 62 105 (7 ) 173 Total current liabilities 7 7 356 — 144 — (18 ) — 496 Long-term liabilities: Long-term debt and capital lease obligations, net of current portion — 496 42 629 — 1,167 Investment and advances from subsidiaries — — 106 — (106 ) — Deferred income taxes (24 ) — — 386 — 362 Other long-term liabilities 3 — 7 4 — 14 Total long-term liabilities (21 ) 496 155 — 1,019 — (106 ) — 1,543 Commitments and contingencies Equity: Total CVR stockholders’ equity 1,246 1,440 1,936 924 (4,300 ) 1,246 Noncontrolling interest — — — 622 — 622 Total equity 1,246 1,440 1,936 1,546 (4,300 ) 1,868 Total liabilities and equity $ 1,232 $ 1,943 $ 2,447 — $ 2,709 — $ (4,424 ) — $ 3,907 Condensed Consolidating Balance Sheet December 31, 2017 Parent Subsidiary Issuer Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Intercompany Elimination Consolidated (in millions) ASSETS Current assets: Cash and cash equivalents $ 4 $ 163 $ 261 $ 54 $ — $ 482 Accounts receivable — — 169 10 — 179 Intercompany receivables 9 — 8 — (17 ) — Inventories — — 316 53 — 369 Prepaid expenses and other current assets 13 1 23 18 (7 ) 48 Total current assets 26 164 777 — 135 — (24 ) — 1,078 Property, plant and equipment, net of accumulated depreciation — — 1,513 1,075 — 2,588 Investment in and advances from subsidiaries 897 1,596 189 1,259 (3,941 ) — Other long-term assets 1 1 91 48 — 141 Total assets $ 924 $ 1,761 $ 2,570 — $ 2,517 — $ (3,965 ) — $ 3,807 LIABILITIES AND PARTNERS' CAPITAL Current liabilities: Note payable and capital lease obligations $ — $ — $ 2 $ — $ — $ 2 Accounts payable 1 — 310 24 (1 ) 334 Intercompany payables — — — 17 (17 ) — Other current liabilities 12 5 151 46 (6 ) 208 Total current liabilities 13 5 463 — 87 — (24 ) — 544 Long-term liabilities: Long-term debt and capital lease obligations, net of current portion — 496 42 626 — 1,164 Investment and advances from subsidiaries — — 230 — (230 ) — Deferred income taxes (8 ) — — 394 — 386 Other long-term liabilities — — 4 5 — 9 Total long-term liabilities (8 ) 496 276 — 1,025 — (230 ) — 1,559 Commitments and contingencies Equity: Total CVR stockholders’ equity 919 1,260 1,831 620 (3,711 ) 919 Noncontrolling interest — — — 785 — 785 Total equity 919 1,260 1,831 — 1,405 — (3,711 ) — 1,704 Total liabilities and equity $ 924 $ 1,761 $ 2,570 — $ 2,517 — $ (3,965 ) — $ 3,807
Guarantor Consolidated Statement of Operations	Condensed Consolidating Statement of Operations Year Ended December 31, 2018 Parent Subsidiary Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Intercompany Eliminations Consolidated (in millions) Net sales $ — $ — $ 6,779 $ 351 $ (6 ) $ 7,124 Operating costs and expenses: Cost of materials and other — — 5,601 88 (6 ) 5,683 Direct operating expenses — — 364 159 — 523 Depreciation and amortization — — 130 72 — 202 Cost of sales — — 6,095 319 (6 ) 6,408 Selling, general and administrative expenses 17 1 60 34 — 112 Depreciation and amortization — — 8 3 — 11 Loss on asset disposals — — 5 1 — 6 Operating income (loss) (17 ) (1 ) 611 (6 ) — 587 Other income (expense): Interest expense, net — (32 ) (7 ) (63 ) — (102 ) Other income, net — — 9 6 — 15 Income (loss) from subsidiaries 303 611 (46 ) 578 (1,446 ) — Income (loss) before income taxes 286 578 567 515 (1,446 ) 500 Income tax expense (benefit) (3 ) — — 92 — 89 Net income (loss) 289 578 567 423 (1,446 ) 411 Less: Net income attributable to noncontrolling interest — — — 122 — 122 Net income (loss) attributable to CVR Energy stockholders $ 289 $ 578 $ 567 $ 301 $ (1,446 ) $ 289 Condensed Consolidating Statement of Operations Year Ended December 31, 2017 Parent Subsidiary Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Intercompany Elimination Consolidated (in millions) Net sales $ — $ — $ 5,665 $ 331 $ (8 ) $ 5,988 Operating costs and expenses: Cost of materials and other — — 4,876 85 (8 ) 4,953 Direct operating expenses — — 441 157 — 598 Depreciation and amortization — — 129 74 — 203 Cost of sales — — 5,446 316 (8 ) 5,754 Selling, general and administrative expenses 15 1 14 83 — 113 Depreciation and amortization — — 8 3 — 11 Loss on asset disposals — — 3 — — 3 Operating income (loss) (15 ) (1 ) 194 (71 ) — 107 Other income (expense): Interest expense, net — (34 ) (11 ) (64 ) — (109 ) Other income, net — — 1 1 — 2 Income (loss) from subsidiaries 246 184 (88 ) 148 (490 ) — Income (loss) before income taxes 231 149 96 14 (490 ) — Income tax benefit (4 ) — — (213 ) — (217 ) Net income (loss) 235 149 96 227 (490 ) 217 Less: Net loss attributable to noncontrolling interest — — — (18 ) — (18 ) Net income (loss) attributable to CVR Energy stockholders $ 235 $ 149 $ 96 $ 245 $ (490 ) $ 235 Condensed Consolidating Statement of Operations Year Ended December 31, 2016 Parent Subsidiary Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Intercompany Elimination Consolidated (in millions) Net sales $ — $ — $ 4,432 $ 356 $ (6 ) $ 4,782 Operating costs and expenses: Cost of materials and other — — 3,780 93 (6 ) 3,867 Direct operating expenses — — 392 149 — 541 Depreciation and amortization — — 126 58 — 184 Cost of sales — — 4,298 300 (6 ) 4,592 Selling, general and administrative expenses 12 1 15 82 — 110 Depreciation and amortization — — 6 3 — 9 Loss on asset disposals — — — 1 — 1 Operating income (loss) (12 ) (1 ) 113 (30 ) — 70 Other income (expense): Interest expense, net — (32 ) (2 ) (49 ) — (83 ) Other income, net 5 — — (3 ) — 2 Income (loss) from subsidiaries 26 103 (64 ) 78 (143 ) — Income (loss) before income taxes 19 70 47 (4 ) (143 ) (11 ) Income tax benefit (6 ) — — (14 ) — (20 ) Net income (loss) 25 70 47 10 (143 ) 9 Less: Net loss attributable to noncontrolling interest — — — (16 ) — (16 ) Net income (loss) attributable to CVR Energy stockholders $ 25 $ 70 $ 47 $ 26 $ (143 ) $ 25
Guarantor Consolidated Statement of Cash Flows	Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2018 Parent Subsidiary Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Intercompany Elimination Consolidated (in millions) Net cash provided by (used in) operating activities 38 (31 ) 687 (77 ) 3 620 Cash flows from investing activities: Capital expenditures (3 ) — (79 ) (20 ) — (102 ) Investment in affiliates, net of return of investment 202 630 679 435 (1,946 ) — Other investing activities — — — 2 — 2 Net cash provided by (used in) investing activities 199 630 600 417 (1,946 ) (100 ) Cash flows from financing activities: CVR Energy shareholder dividends (238 ) — — — — (238 ) CVR Refining unitholder distributions — — (93 ) — — (93 ) Distributions or intercompany advances to other CVR Energy subsidiaries — (422 ) (1,202 ) (319 ) 1,943 — Other financing activities — — (1 ) (2 ) — (3 ) Net cash provided by (used in) financing activities (238 ) (422 ) (1,296 ) (321 ) 1,943 (334 ) Net increase (decrease) in cash and cash equivalents (1 ) 177 (9 ) 19 — 186 Cash and cash equivalents, beginning of period 4 163 261 54 — 482 Cash and cash equivalents, end of period $ 3 $ 340 $ 252 $ 73 $ — $ 668 Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2017 Parent Subsidiary Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Intercompany Elimination Consolidated (in millions) Net cash provided by (used in) operating activities (30 ) (32 ) 273 (33 ) (10 ) 168 Cash flows from investing activities: Capital expenditures (4 ) — (101 ) (15 ) — (120 ) Investment in affiliates, net of return of investment 207 1,083 112 158 (1,636 ) (76 ) Net cash provided by (used in) investing activities 203 1,083 11 143 (1,636 ) (196 ) Cash flows from financing activities: CVR Energy dividends (174 ) — — — — (174 ) CVR Refining unitholder distributions — — (47 ) — — (47 ) CVR Partners unitholder distributions — — — (2 ) — (2 ) Distributions or intercompany advances to other CVR Energy subsidiaries — (1,190 ) (338 ) (118 ) 1,646 — Other financing activities — — (2 ) (1 ) — (3 ) Net cash provided by (used in) financing activities (174 ) (1,190 ) (387 ) (121 ) 1,646 (226 ) Net decrease in cash and cash equivalents (1 ) (139 ) (103 ) (11 ) — (254 ) Cash and cash equivalents, beginning of period 5 302 364 65 — 736 Cash and cash equivalents, end of period $ 4 $ 163 $ 261 $ 54 $ — $ 482 Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2016 Parent Subsidiary Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Intercompany Elimination Consolidated (in millions) Net cash provided by (used in) operating activities (29 ) (26 ) 380 (45 ) (13 ) 267 Cash flows from investing activities: Capital expenditures (10 ) — (102 ) (21 ) — (133 ) Acquisition of CVR Nitrogen, net of cash acquired — — — (64 ) — (64 ) Investment in affiliates, net of return of investment 214 227 (157 ) 281 (570 ) (5 ) Other investing activities — — 1 — — 1 Net cash provided by (used in) investing activities 204 227 (258 ) 196 (570 ) (201 ) Cash flows from financing activities: Proceeds on issuance of 2023 Notes, net of original issue discount — — — 629 — 629 Principal and premium payments on 2021 Notes — — — (322 ) — (322 ) Payments of revolving debt — — — (49 ) — (49 ) Principal payments on CRNF credit facility — — — (125 ) — (125 ) CVR Energy shareholder dividends (174 ) — — — — (174 ) CVR Partners unitholder distributions — — — (42 ) — (42 ) Distributions or intercompany advances to other CVR Energy subsidiaries — (69 ) (280 ) (234 ) 583 — Other financing activities (11 ) — (1 ) — — (12 ) Net cash provided by (used in) financing activities (185 ) (69 ) (281 ) (143 ) 583 (95 ) Net increase (decrease) in cash and cash equivalents (10 ) 132 (159 ) 8 — (29 ) Cash and cash equivalents, beginning of period 15 170 523 57 — 765 Cash and cash equivalents, end of period $ 5 $ 302 $ 364 $ 65 $ — $ 736

Selected Quarterly Financial _2

Selected Quarterly Financial Information (Tables)	12 Months Ended
	Dec. 31, 2018
Quarterly Financial Information Disclosure [Abstract]
Summary of quarterly financial data	Summarized quarterly financial data for December 31, 2018 and 2017 is as follows: Year Ended December 31, 2018 Quarter (in millions) First Second Third Fourth Net sales $ 1,536 $ 1,915 $ 1,935 $ 1,737 Cost of materials and other (a) 1,179 1,560 1,556 1,387 Direct operating expenses (a) 132 141 120 130 Operating income 150 121 179 138 Net income 104 80 121 106 Net income attributable to noncontrolling interest 38 30 31 24 Net income attributable to CVR Energy stockholders $ 66 $ 50 $ 90 $ 82 Basic and diluted earnings per share $ 0.76 $ 0.59 $ 0.94 $ 0.82 Dividends declared per share $ 0.50 $ 0.50 $ 0.75 $ 0.75 Weighted-average common shares outstanding - basic and diluted 86.8 86.8 95.8 100.5 Year Ended December 31, 2017 Quarter (in millions) First Second Third Fourth Net sales $ 1,507 $ 1,434 $ 1,454 $ 1,593 Cost of materials and other (a) 1,209 1,229 1,149 1,366 Direct operating expenses (a) 138 124 162 175 Operating income (loss) 80 1 61 (36 ) Net income (loss) 38 (19 ) 25 173 Net income (loss) attributable to noncontrolling interest 16 (8 ) 3 (27 ) Net income (loss) attributable to CVR Energy stockholders $ 22 $ (11 ) $ 22 $ 200 Basic and diluted earnings (loss) per share $ 0.26 $ (0.12 ) $ 0.26 $ 2.31 Dividends declared per share $ 0.50 $ 0.50 $ 0.50 $ 0.50 Weighted-average common shares outstanding - basic and diluted 86.8 86.8 86.8 86.8 _______________________________________ (a) Excludes depreciation and amortization expenses.

Organization and Nature of Bu_2

Organization and Nature of Business - Narrative (Details)	Jan. 29, 2019USD ($)$ / shares	Aug. 31, 2018USD ($)shares	Dec. 31, 2018USD ($)segment	Dec. 31, 2017USD ($)
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Number of business segments | segment			2
Increase in deferred tax assets			$ 11,000,000	$ 18,000,000
Subsequent Event | Term Loan Facility
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Borrowing capacity	$ 105,000,000
Subsequent Event | CVR Refining, LP
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Cash purchase price	$ 301,000,000
Subsequent Event | CVRR Public Unit Purchase
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Cash purchase price (in dollars per share) | $ / shares	$ 10.50
Cash purchase price	$ 241,000,000
Subsequent Event | CVRR Affiliate Unit Purchase | AEP and IEP
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Cash purchase price	$ 60,000,000
CVR Refining, LP
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of interest held by public			16.00%
CVR Energy, Inc. and CVR Refining Holdings LLC | CVR Refining, LP
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of common units owned by wholly-owned subsidiary			81.00%
CVR Energy, Inc. and CVR Refining Holdings LLC | CVR GP, LLC
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of common units owned by general partner			100.00%
CVR Partners
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of interest held by public			66.00%
Coffeyville Resources LLC (CRLLC) | CVR Partners
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of common units owned by wholly-owned subsidiary			34.00%
Coffeyville Resources LLC (CRLLC) | CVR GP, LLC
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of common units owned by general partner			100.00%
Affiliates
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Ownership percentage held by controlling stockholder		71.00%
Affiliates | CVR Refining, LP
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of interest held by public			3.90%
Exchange Offer, CVR Refining Common Units for CVR Energy Common Stock
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Common stock exchanged in the exchange offer (in shares) | shares		13,699,549
Issuance costs incurred in connection with exchange offer		$ 700,000
Increase in deferred tax assets		$ 84,000,000
Exchange Offer, CVR Refining Common Units for CVR Energy Common Stock | CVR Refining, LP
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Number of shares tendered in exchange offer (in shares) | shares		21,625,106
Exchange Offer, CVR Refining Common Units for CVR Energy Common Stock | Additional Paid-In Capital
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Impact of CVRR unit exchange, increase to additional paid-in capital		$ 276,000,000

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Principles of Consolidation (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Accounting Policies [Abstract]
Other comprehensive income	$ 0	$ 0	$ 0

Summary of Significant Accoun_5

Summary of Significant Accounting Policies - Accounts Receivable, net (Details)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Accounts receivable | Credit concentration
Accounts Receivable, net
Customers individually representing greater than this percentage for disclosure	12.00%	11.00%

Summary of Significant Accoun_6

Summary of Significant Accounting Policies - Schedule of Inventories (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Accounting Policies [Abstract]
Depreciation of inventories included on Consolidated Balance Sheets	$ 6	$ 4
Finished goods	186	172
Raw materials	105	98
In-process inventories	12	22
Parts and supplies	77	77
Total Inventories	380	369
Inventory
Inventory [Line Items]
Precious metals inventory	(15)	(16)
Property, plant and equipment, net
Inventory [Line Items]
Precious metals inventory	$ 15	$ 16

Summary of Significant Accoun_7

Summary of Significant Accounting Policies - Property, Plant and Equipment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment	$ 4,082	$ 4,019
Less: Accumulated depreciation	1,637	1,431
Total Property, plant and equipment, net	2,445	2,588
Land and improvements
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment	43	47
Buildings
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment	82	83
Machinery and equipment
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment	3,754	3,734
Other
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment	$ 203	$ 155
Minimum | Land improvements
Property, Plant and Equipment [Line Items]
Useful life	15 years
Minimum | Buildings
Property, Plant and Equipment [Line Items]
Useful life	20 years
Minimum | Machinery and equipment
Property, Plant and Equipment [Line Items]
Useful life	5 years
Minimum | Other
Property, Plant and Equipment [Line Items]
Useful life	5 years
Maximum | Land improvements
Property, Plant and Equipment [Line Items]
Useful life	30 years
Maximum | Buildings
Property, Plant and Equipment [Line Items]
Useful life	30 years
Maximum | Machinery and equipment
Property, Plant and Equipment [Line Items]
Useful life	30 years
Maximum | Other
Property, Plant and Equipment [Line Items]
Useful life	30 years
Petroleum Segment | Assets Held for Sale
Property, Plant and Equipment [Line Items]
Carrying value of assets held for sale	$ 33

Summary of Significant Accoun_8

Summary of Significant Accounting Policies - Impairment of Long-Lived Assets (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Accounting Policies [Abstract]
Goodwill impairment	$ 0	$ 0	$ 0
Coffeyville reporting unit, percentage of fair value in excess of carrying value		12.00%

Summary of Significant Accoun_9

Summary of Significant Accounting Policies - Cost Classifications (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Derivative Instruments, Gain (Loss) [Line Items]
Reclassified gain (loss) on derivatives, net	$ 146	$ (70)	$ (19)
Cost of Materials and other | Commodity Derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Reclassified gain (loss) on derivatives, net	$ 146	$ (70)	$ (20)

Summary of Significant Accou_10

Summary of Significant Accounting Policies - Turnaround Expenses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Petroleum Segment
Planned Major Maintenance Activities [Line Items]
Turnaround costs	$ 4	$ 80	$ 31
Petroleum Segment | Minimum
Planned Major Maintenance Activities [Line Items]
Frequency of planned major maintenance activities	4 years
Petroleum Segment | Maximum
Planned Major Maintenance Activities [Line Items]
Frequency of planned major maintenance activities	5 years
Nitrogen Fertilizer Segment
Planned Major Maintenance Activities [Line Items]
Turnaround costs	$ 6	$ 3	$ 7
Nitrogen Fertilizer Segment | Minimum
Planned Major Maintenance Activities [Line Items]
Frequency of planned major maintenance activities	2 years
Nitrogen Fertilizer Segment | Maximum
Planned Major Maintenance Activities [Line Items]
Frequency of planned major maintenance activities	3 years

Summary of Significant Accou_11

Summary of Significant Accounting Policies - Earnings Per Share (Details) - shares	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Accounting Policies [Abstract]
Dilutive awards outstanding (in shares)	0	0	0

Summary of Significant Accou_12

Summary of Significant Accounting Policies - Recent Accounting Pronouncements (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jan. 01, 2019	Jan. 01, 2018
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Net sales	$ 1,737	$ 1,935	$ 1,915	$ 1,536	$ 1,593	$ 1,454	$ 1,434	$ 1,507	$ 7,124	$ 5,988	$ 4,782
Cost of materials and other	1,387	$ 1,556	$ 1,560	$ 1,179	1,366	$ 1,149	$ 1,229	$ 1,209	5,683	4,953	$ 3,867
Assets
Accounts Receivable	169				$ 179				169	$ 179
Liabilities
Deferred Revenue	69								69
Accounting Standards Update 2016-02 | Subsequent Event
Liabilities
ROU assets												$ 53
Lease liabilities												53
Finance lease asset												26
Finance lease obligation												$ 26
Balances without adoption of ASC 606
Assets
Accounts Receivable	124								124
Liabilities
Deferred Revenue	24								24
Effect of change | Accounting Standards Update 2014-09
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Net sales									2
Cost of materials and other									2
Assets
Accounts Receivable	45								45				$ 21
Liabilities
Deferred Revenue	$ 45								$ 45				21
CVR Partners
Assets
Accounts Receivable													31
Liabilities
Deferred Revenue													$ 34

Acquisition - Additional Inform

Acquisition - Additional Information (Details) - USD ($) $ in Millions	Apr. 01, 2016	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Business Acquisition [Line Items]
Net sales		$ 1,737	$ 1,935	$ 1,915	$ 1,536	$ 1,593	$ 1,454	$ 1,434	$ 1,507	$ 7,124	$ 5,988	$ 4,782
Operating loss		$ 138	$ 179	$ 121	$ 150	$ (36)	$ 61	$ 1	$ 80	$ 587	$ 107	$ 70
CVR Partners | East Dubuque Merger
Business Acquisition [Line Items]
Aggregate merger consideration	$ 802
Fair value of common units issued in a business combination	335
Cash consideration	99
Fair value of debt assumed	368
Net sales	128
Operating loss	$ 1

Equity Method Investments (Deta

Equity Method Investments (Details) - CVR Refining bbl / d in Thousands	12 Months Ended
	Dec. 31, 2018bbl / dmi
Enable South Central Pipeline, LLC
Related Party Transaction [Line Items]
Pipeline capacity, barrels per day	80
Midway Pipeline LLC
Related Party Transaction [Line Items]
Pipeline capacity, barrels per day	120
Pipeline length (in miles) | mi	100
Enable South Central Pipeline, LLC | Enable South Central Pipeline, LLC
Related Party Transaction [Line Items]
Joint venture interest	40.00%
Midway Pipeline LLC | Midway Pipeline LLC
Related Party Transaction [Line Items]
Joint venture interest	50.00%

Equity Method Investments - Sch

Equity Method Investments - Schedule of Equity Method Investments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Equity Method Investments [Roll Forward]
Contributions	$ 0	$ 76	$ 5
CVR Refining
Equity Method Investments [Roll Forward]
Balance at beginning of period	83	6
Contributions		77
Cash Distributions	(7)	(1)
Equity income	8	1
Balance at end of period	84	83	6
CVR Refining | Enable JV
Equity Method Investments [Roll Forward]
Balance at beginning of period	6	6
Contributions		1
Cash Distributions	(2)	(1)
Equity income	2	0
Balance at end of period	6	6	6
CVR Refining | Midway JV
Equity Method Investments [Roll Forward]
Balance at beginning of period	77	0
Contributions		76
Cash Distributions	(5)	0
Equity income	6	1
Balance at end of period	$ 78	$ 77	$ 0

Long-Term Debt - Schedule of De

Long-Term Debt - Schedule of Debt (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Total Long-Term Debt	$ 1,167	$ 1,164
Capital Lease Obligations
Debt Instrument [Line Items]
Current portion of capital lease obligations	(3)
CVR Partners
Debt Instrument [Line Items]
Unamortized discount and debt issuance costs	(18)	(22)
Total Long-Term Debt	629	625
CVR Partners | Senior Notes | 9.25% Senior Secured Notes due June 2023
Debt Instrument [Line Items]
Total long-term debt, before debt issuance costs, discount and current portion of capital lease obligations	$ 645	645
Stated interest rate	9.25%
Unamortized debt discount	$ 16
Debt issuance costs	9
CVR Partners | Senior Notes | 6.50% Senior Notes due April 2021
Debt Instrument [Line Items]
Total long-term debt, before debt issuance costs, discount and current portion of capital lease obligations	$ 2	2
Stated interest rate	6.50%
CVR Refining
Debt Instrument [Line Items]
Unamortized discount and debt issuance costs	$ (3)	(4)
Current portion of capital lease obligations	(3)	(2)
Total Long-Term Debt	538	539
CVR Refining | Senior Notes | 6.50% Senior Notes due November 2022
Debt Instrument [Line Items]
Total long-term debt, before debt issuance costs, discount and current portion of capital lease obligations	$ 500	500
Stated interest rate	6.50%
Debt issuance costs	$ 9
CVR Refining | Capital Lease Obligations
Debt Instrument [Line Items]
Total long-term debt, before debt issuance costs, discount and current portion of capital lease obligations	$ 44	$ 45

Long-Term Debt - Credit Facilit

Long-Term Debt - Credit Facilities Outstanding (Details) - Line of Credit - Revolving Credit Facility	12 Months Ended
	Dec. 31, 2018USD ($)
Amended and Restated Asset Based (ABL) Credit Facility
Line of Credit Facility [Line Items]
Total Capacity	$ 400,000,000
Amount Borrowed	0
Outstanding Letters of Credit	6,000,000
Available Capacity	$ 394,000,000
Amended and Restated Asset Based (ABL) Credit Facility | LIBOR
Line of Credit Facility [Line Items]
Basis spread on variable rate	1.50%
Amended and Restated Asset Based (ABL) Credit Facility | Base Rate
Line of Credit Facility [Line Items]
Basis spread on variable rate	0.50%
Asset Based (ABL) Credit Facility
Line of Credit Facility [Line Items]
Total Capacity	$ 50,000,000
Amount Borrowed	0
Outstanding Letters of Credit	0
Available Capacity	$ 50,000,000
Asset Based (ABL) Credit Facility | LIBOR
Line of Credit Facility [Line Items]
Basis spread on variable rate	2.00%
Asset Based (ABL) Credit Facility | Base Rate
Line of Credit Facility [Line Items]
Basis spread on variable rate	1.00%
Step-down rate	0.50%

Long-Term Debt - Additional Inf

Long-Term Debt - Additional Information (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Accrued interest payable	$ 8	$ 8
CVR Refining | Senior Notes | 6.50% Senior Notes due November 2022
Debt Instrument [Line Items]
Accrued interest payable	5
CVR Partners | Senior Notes | 9.25% Senior Secured Notes due June 2023
Debt Instrument [Line Items]
Accrued interest payable	$ 3

Long-Term Debt - Amended and Re

Long-Term Debt - Amended and Restated Asset Based (ABL) Credit Facility (Details) - Amended and Restated ABL Credit Facility - Credit parties	Nov. 14, 2017USD ($)
Debt Instrument [Line Items]
Borrowing capacity	$ 400,000,000
Uncommitted incremental facility	200,000,000
Letter of Credit
Debt Instrument [Line Items]
Borrowing capacity	60,000,000
Swingline Loans
Debt Instrument [Line Items]
Borrowing capacity	$ 40,000,000

Long-Term Debt - ABL Credit Fac

Long-Term Debt - ABL Credit Facility (Details) - Line of Credit - ABL Credit Facility - Revolving Credit Facility	Sep. 30, 2016USD ($)
Line of Credit Facility [Line Items]
Debt instrument face amount	$ 50,000,000
Available increase in borrowing limit	$ 25,000,000

Long-Term Debt - Credit Agreeme

Long-Term Debt - Credit Agreement (Details) - Term Loan Facility - Subsequent Event	Jan. 29, 2019USD ($)
Debt Instrument [Line Items]
Borrowing capacity	$ 105,000,000
Credit Agreement
Debt Instrument [Line Items]
Borrowing capacity	$ 105,000,000

Long-Term Debt - Capital Lease

Long-Term Debt - Capital Lease Obligations (Details) - Capital Lease Obligations $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)lease	Dec. 31, 2017
Capital Leased Assets [Line Items]
Number of leases acquired | lease	3
Capital lease obligations	$ 44
Capital Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
2019 - 2023 (annually $7 million)	35
2,019	7
2,020	7
2,021	7
2,022	7
2,023	7
Thereafter	37
Total future payments	72
Less: amount representing interest	28
Present value of future minimum payments	44
Less: current portion	3
Long-term portion	$ 41
Minimum
Capital Leased Assets [Line Items]
Remaining term of leases	44 months
Maximum
Capital Leased Assets [Line Items]
Remaining term of leases		130 months

Revenue - Revenue Disaggregate

Revenue - Revenue Disaggregated by Major Product (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disaggregation of Revenue [Line Items]
Total revenue	$ 1,737	$ 1,935	$ 1,915	$ 1,536	$ 1,593	$ 1,454	$ 1,434	$ 1,507	$ 7,124	$ 5,988	$ 4,782
Revenue from product sales
Disaggregation of Revenue [Line Items]
Revenue from product sales									7,023
Gasoline
Disaggregation of Revenue [Line Items]
Revenue from product sales									3,383
Distillates
Disaggregation of Revenue [Line Items]
Revenue from product sales									3,067
Ammonia
Disaggregation of Revenue [Line Items]
Revenue from product sales									66
UAN
Disaggregation of Revenue [Line Items]
Revenue from product sales									222
Other urea products
Disaggregation of Revenue [Line Items]
Revenue from product sales									21
Freight revenue
Disaggregation of Revenue [Line Items]
Revenue from product sales									57
Other
Disaggregation of Revenue [Line Items]
Revenue from product sales									207
Crude oil sales
Disaggregation of Revenue [Line Items]
Revenue from product sales									96
Other revenue
Disaggregation of Revenue [Line Items]
Other revenue									5
Operating Segments | Petroleum
Disaggregation of Revenue [Line Items]
Total revenue									6,780	5,664	4,431
Operating Segments | Petroleum | Revenue from product sales
Disaggregation of Revenue [Line Items]
Revenue from product sales									6,679
Operating Segments | Petroleum | Gasoline
Disaggregation of Revenue [Line Items]
Revenue from product sales									3,383
Operating Segments | Petroleum | Distillates
Disaggregation of Revenue [Line Items]
Revenue from product sales									3,067
Operating Segments | Petroleum | Ammonia
Disaggregation of Revenue [Line Items]
Revenue from product sales									0
Operating Segments | Petroleum | UAN
Disaggregation of Revenue [Line Items]
Revenue from product sales									0
Operating Segments | Petroleum | Other urea products
Disaggregation of Revenue [Line Items]
Revenue from product sales									0
Operating Segments | Petroleum | Freight revenue
Disaggregation of Revenue [Line Items]
Revenue from product sales									23
Operating Segments | Petroleum | Other
Disaggregation of Revenue [Line Items]
Revenue from product sales									206
Operating Segments | Petroleum | Crude oil sales
Disaggregation of Revenue [Line Items]
Revenue from product sales									96
Operating Segments | Petroleum | Other revenue
Disaggregation of Revenue [Line Items]
Other revenue									5
Operating Segments | Nitrogen Fertilizer
Disaggregation of Revenue [Line Items]
Total revenue									351	$ 331	$ 356
Operating Segments | Nitrogen Fertilizer | Revenue from product sales
Disaggregation of Revenue [Line Items]
Revenue from product sales									351
Operating Segments | Nitrogen Fertilizer | Gasoline
Disaggregation of Revenue [Line Items]
Revenue from product sales									0
Operating Segments | Nitrogen Fertilizer | Distillates
Disaggregation of Revenue [Line Items]
Revenue from product sales									0
Operating Segments | Nitrogen Fertilizer | Ammonia
Disaggregation of Revenue [Line Items]
Revenue from product sales									66
Operating Segments | Nitrogen Fertilizer | UAN
Disaggregation of Revenue [Line Items]
Revenue from product sales									222
Operating Segments | Nitrogen Fertilizer | Other urea products
Disaggregation of Revenue [Line Items]
Revenue from product sales									21
Operating Segments | Nitrogen Fertilizer | Freight revenue
Disaggregation of Revenue [Line Items]
Revenue from product sales									34
Operating Segments | Nitrogen Fertilizer | Other
Disaggregation of Revenue [Line Items]
Revenue from product sales									8
Operating Segments | Nitrogen Fertilizer | Crude oil sales
Disaggregation of Revenue [Line Items]
Revenue from product sales									0
Operating Segments | Nitrogen Fertilizer | Other revenue
Disaggregation of Revenue [Line Items]
Other revenue									0
Other / Eliminations
Disaggregation of Revenue [Line Items]
Total revenue									(7)
Other / Eliminations | Revenue from product sales
Disaggregation of Revenue [Line Items]
Revenue from product sales									(7)
Other / Eliminations | Gasoline
Disaggregation of Revenue [Line Items]
Revenue from product sales									0
Other / Eliminations | Distillates
Disaggregation of Revenue [Line Items]
Revenue from product sales									0
Other / Eliminations | Ammonia
Disaggregation of Revenue [Line Items]
Revenue from product sales									0
Other / Eliminations | UAN
Disaggregation of Revenue [Line Items]
Revenue from product sales									0
Other / Eliminations | Other urea products
Disaggregation of Revenue [Line Items]
Revenue from product sales									0
Other / Eliminations | Freight revenue
Disaggregation of Revenue [Line Items]
Revenue from product sales									0
Other / Eliminations | Other
Disaggregation of Revenue [Line Items]
Revenue from product sales									(7)
Other / Eliminations | Crude oil sales
Disaggregation of Revenue [Line Items]
Revenue from product sales									0
Other / Eliminations | Other revenue
Disaggregation of Revenue [Line Items]
Other revenue									$ 0

Revenue - Additional informati

Revenue - Additional information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)
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	30 days
Nitrogen Fertilizer
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 11
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 Performanc

Revenue - Remaining Performance Obligation (Details) - Nitrogen Fertilizer Segment	Dec. 31, 2018
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, percentage	45.00%
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, percentage	27.00%
Remaining performance obligation, expected timing of satisfaction, period	1 year

Revenue - Deferred Revenue (De

Revenue - Deferred Revenue (Details) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)
Less:
Balance at December 31, 2018	$ 69
Nitrogen Fertilizer Segment
Change in Contract with Customer, Liability [Roll Forward]
Balance at January 1, 2018	34
Add:
New prepay contracts entered into during the period, net of adjustments	92
Less:
Revenue recognized that was included in the contract liability balance at the beginning of the period	34
Revenue recognized related to contracts entered into during the period	23
Balance at December 31, 2018	$ 69

Revenue - Major Customers (Deta

Revenue - Major Customers (Details) - Sales - Customer concentration	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Petroleum | One Customer
Major Customers and Suppliers
Concentration risk	15.00%	19.00%	15.00%
Nitrogen Fertilizer | Two Customers
Major Customers and Suppliers
Concentration risk	20.00%	16.00%	20.00%
Nitrogen Fertilizer | One Customer
Major Customers and Suppliers
Concentration risk	14.00%	11.00%	10.00%

Derivative Financial Instrume_3

Derivative Financial Instruments - Schedule of Gains (Losses) on Derivatives (Details) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)derivative	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivatives, net	$ 146	$ (70)	$ (19)
Forward purchases
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivatives, net	$ 103	(26)	0
Forward Contracts, 2019 RINs
Derivative Instruments, Gain (Loss) [Line Items]
Outstanding positions | derivative	27,000,000
Forward purchase price	$ 4
Forward Contracts, 2018 RINs
Derivative Instruments, Gain (Loss) [Line Items]
Outstanding positions | derivative	8,000,000
Forward purchase price	$ 3
Swaps
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivatives, net	$ 44	(43)	(19)
Commodity Swap
Derivative Instruments, Gain (Loss) [Line Items]
Outstanding positions | derivative	0
Futures
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivatives, net	$ (1)	$ (1)	$ 0

Derivative Financial Instrume_4

Derivative Financial Instruments - Open Commodity Derivative Instruments (Details) - bbl bbl in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
2-1-1 Crack spreads
Derivative [Line Items]
Number of barrels	0	7
Distillate Crack spreads
Derivative [Line Items]
Number of barrels	0	4
Gasoline Crack spreads
Derivative [Line Items]
Number of barrels	0	4
Canadian crude oil
Derivative [Line Items]
Number of barrels	2	6

Derivative Financial Instrume_5

Derivative Financial Instruments - Schedule of Offsetting Assets and Liabilities (Details) - Commodity Derivatives - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Current Assets
Derivative Assets
Commodity Derivatives	$ 8	$ 7
Less: Counterparty Netting	(1)	(7)
Total Net Fair Value of Derivatives	7	0
Current Liabilities
Derivative Liabilities
Commodity Derivatives	1	71
Less: Counterparty Netting	(1)	(7)
Total Net Fair Value of Derivatives	$ 0	$ 64

Derivative Financial Instrume_6

Derivative Financial Instruments - Assets and Liabilities Measured at Fair Value (Details) - Recurring - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	$ 50	$ 15
Total Assets	57	15
Long-term debt	(1,163)	(1,209)
Total Liabilities	(1,165)	(1,274)
Commodity derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other current assets (commodity derivatives)	7
Other current liabilities		(64)
Renewable Fuel Standard RFS obligation
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other current liabilities	(2)	(1)
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	50	15
Total Assets	50	15
Long-term debt	0	0
Total Liabilities	0	0
Level 1 | Commodity derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other current assets (commodity derivatives)	0
Other current liabilities		0
Level 1 | Renewable Fuel Standard RFS obligation
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other current liabilities	0	0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	0	0
Total Assets	7	0
Long-term debt	(1,163)	(1,209)
Total Liabilities	(1,165)	(1,274)
Level 2 | Commodity derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other current assets (commodity derivatives)	7
Other current liabilities		(64)
Level 2 | Renewable Fuel Standard RFS obligation
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other current liabilities	(2)	(1)
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	0	0
Total Assets	0	0
Long-term debt	0	0
Total Liabilities	0	0
Level 3 | Commodity derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other current assets (commodity derivatives)	0
Other current liabilities		0
Level 3 | Renewable Fuel Standard RFS obligation
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other current liabilities	$ 0	$ 0

Share-Based Compensation (Detai

Share-Based Compensation (Details)	Nov. 01, 2017USD ($)trading_dayagreement$ / shares	Dec. 31, 2018USD ($)planshares	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares right to receive cash payment on vesting equal to fair market value is received per award (in shares) | shares		1
Vesting period		3 years
Number of defined-contribution 401(k) plans | plan		2
Matching contributions made by the company		$ 9,000,000	$ 9,000,000	$ 8,000,000
2018 CEO Performance Award | Performance awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of performance award agreements entered into | agreement	2
Target value of awards granted		1,500,000
Maximum cash payment	$ 10,000,000
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
Outstanding liability		2,000,000
Former CEO Performance Award | Performance awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding liability		$ 0
Vesting Year One
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting percentage		33.33%
Vesting Year Two
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting percentage		33.33%
Vesting Year Three
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting percentage		33.33%

Share-Based Compensation - Summ

Share-Based Compensation - Summary of Phantom and Incentive Unit Awards Activity (Details) - Phantom and Incentive Unit Awards - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Shares or Units
Non-vested at the beginning of the period (in shares)	2,953,947	2,664,438
Granted (in shares)	1,236,322	1,713,192
Vested (in shares)	(1,140,423)	(1,062,382)
Forfeited (in shares)	(617,773)	(361,301)
Non-vested at the end of the period (in shares)	2,432,073	2,953,947
Weighted- Average Grant-Date Fair Value (Per Share or Unit)
Non-vested at the beginning of the period (in dollars per share)	$ 8.97	$ 10.76
Granted (in dollars per share)	16.11	8.52
Vested (in dollars per share)	9.74	11.62
Forfeited (in dollars per share)	9.39	12.29
Non-vested at the end of the period (in dollars per share)	$ 12.13	$ 8.97
Aggregate Intrinsic Value	$ 24	$ 33	$ 24

Share-Based Compensation - Sche

Share-Based Compensation - Schedule of Share-based Compensation (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expenses	$ 16	$ 19	$ 9
Unrecognized Expense	27
Incentive Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expenses	4	7	2
Unrecognized Expense	$ 15
Weighted Average Remaining Years	1 year 8 months 12 days
Phantom Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expenses	$ 8	8	3
Unrecognized Expense	$ 4
Weighted Average Remaining Years	1 year 7 months 6 days
Performance awards | CEO Performance Award
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expenses	$ 2	0	0
Unrecognized Expense	$ 8
Weighted Average Remaining Years	3 years
Performance awards | 2018 CEO Performance Award
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expenses	$ 2	0	0
Unrecognized Expense	$ 0
Weighted Average Remaining Years	0 years
Performance awards | Former CEO Performance Award
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expenses	$ 0	$ 4	$ 4
Unrecognized Expense	$ 0
Weighted Average Remaining Years	0 years

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Taxes [Line Items]
Minimum ownership interest in CVR Energy for eligibility to file as member of AEPC consolidated federal income tax group	80.00%
Receivable from the IRS and state jurisdictions	$ 12,000,000
Valuation allowance	0	$ 0
Unrecognized tax benefits which, if recognized, would impact the company's effective tax rate	18,000,000	23,000,000	$ 29,000,000
Reductions related to expirations of statute of limitations	6,000,000	15,000,000	5,000,000
Unrecognized tax benefits reasonably possible to be recognized in next fiscal year	3,000,000
Unrecognized tax benefits netted with deferred tax asset carryforwards	22,000,000	26,000,000
Interest on income recognized on uncertain tax positions	1,000,000	7,000,000	1,000,000
Accrued interest	0	1,000,000	$ 8,000,000
Penalties recognized on uncertain tax positions	0	0
State
Income Taxes [Line Items]
Tax credit carry-forwards	35,000,000
AEP
Income Taxes [Line Items]
Due from parent	$ 4,000,000	$ 5,000,000
AEP | Majority Shareholder
Income Taxes [Line Items]
Minimum ownership interest in CVR Energy for eligibility to file as member of AEPC consolidated federal income tax group	80.00%

Income Taxes - Income Tax Expen

Income Taxes - Income Tax Expense (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Current:
Federal	$ 31	$ (1)	$ 67
State	(7)	(22)	(7)
Total current	24	(23)	60
Deferred:
Federal	47	(181)	(61)
State	18	(13)	(19)
Total deferred	65	(194)	(80)
Total income tax expense (benefit)	$ 89	$ (217)	$ (20)

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Total Income Tax Expense (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Tax computed at federal statutory rate	$ 105	$ 0	$ (4)
State income taxes, net of federal tax benefit	14	(16)	(8)
State tax incentives, net of federal tax expense	(4)	(7)	(9)
Noncontrolling interest	(26)	6	6
Other, net	0	0	(5)
Adjustment to deferred tax assets and liabilities for enacted change in federal tax rate (a)	0	(200)	0
Total income tax expense (benefit)	$ 89	$ (217)	$ (20)

Income Taxes - Income Tax Effec

Income Taxes - Income Tax Effect of Temporary Differences (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Deferred income tax assets:
State tax credit carryforward, net	$ 11	$ 11
Net operating loss carryforward	0	7
Total gross deferred income tax assets	11	18
Deferred income tax liabilities:
Other	(5)	(4)
Total gross deferred income tax liabilities	(373)	(404)
Net deferred income tax liabilities	(362)	(386)
CVR Partners
Deferred income tax liabilities:
Investment in CVR Partners and CVR Refining	(59)	(55)
CVR Refining
Deferred income tax liabilities:
Investment in CVR Partners and CVR Refining	$ (309)	$ (345)

Income Taxes - Reconciliation_2

Income Taxes - Reconciliation of the Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Reconciliation of the unrecognized tax benefits
Balance beginning of year	$ 29	$ 44	$ 49
Reductions related to expirations of statute of limitations	(6)	(15)	(5)
Balance end of year	$ 23	$ 29	$ 44

Commitments and Contingencies -

Commitments and Contingencies - Leases and Unconditional Purchase Obligations (Details) $ in Millions	Dec. 31, 2018USD ($)
Operating Leases
2,019	$ 24
2,020	20
2,021	18
2,022	16
2,023	12
Thereafter	26
Operating Leases	116
Unconditional Purchase Obligations
2,019	129
2,020	89
2,021	78
2,022	76
2,023	75
Thereafter	444
Unconditional Purchase Obligations	$ 891

Commitments and Contingencies_2

Commitments and Contingencies - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Rent expense	$ 10	$ 8	$ 8
Amounts purchased under supply agreements	$ 214	$ 209	$ 151

Commitments and Contingencies_3

Commitments and Contingencies - Crude Oil Supply Agreement (Details) - Crude Oil Supply Agreement	Aug. 31, 2012	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Unrecorded Unconditional Purchase Obligation [Line Items]
Renewal term of agreement	1 year
Number of days for prior notice of nonrenewal	180 days
Petroleum Segment | Contracted Volume | Supplier Concentration Risk
Unrecorded Unconditional Purchase Obligation [Line Items]
Volume contracted throughout Vitol as percentage of total crude oil purchases		42.00%	55.00%	61.00%

Commitments and Contingencies_4

Commitments and Contingencies - Contingencies (Details) $ in Millions	Dec. 31, 2007	Jan. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2012USD ($)	Dec. 31, 2011USD ($)	Dec. 31, 2010USD ($)	Dec. 31, 2009USD ($)	Dec. 31, 2008USD ($)	Feb. 20, 2019lawsuit
Litigation | Coffeyville Facility
Loss Contingencies [Line Items]
Property tax abatement period	10 years
Increase in property tax expenses (in excess of)				$ 10	$ 10	$ 10	$ 10	$ 10
Insurance Settlement | CVR Partners
Loss Contingencies [Line Items]
Total consideration to be paid by the underwriters			$ 6
Amount received			5
Amount recorded as receivable			$ 1
Subsequent Event | Insurance Settlement | CVR Partners
Loss Contingencies [Line Items]
Amount received		$ 1
Call Option Lawsuits | Subsequent Event | CVR Energy, CVR Refining, CVR Refining Holdings, and IEP and Certain Directors and Affiliates
Loss Contingencies [Line Items]
Number of lawsuits filed | lawsuit									6

Commitments and Contingencies_5

Commitments and Contingencies - Renewable Fuel Standards and Environmental Remediation (Details) - EHS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Loss Contingencies [Line Items]
Environmental accruals	$ 8	$ 4
CVR Refining
Loss Contingencies [Line Items]
Biofuel blending obligation recorded in other current liabilities	4	28
Petroleum Segment
Loss Contingencies [Line Items]
Cost of renewable identification numbers	$ 60	$ 249	$ 206

Commitments and Contingencies_6

Commitments and Contingencies - Wynnewood Refinery Incident (Details )	Sep. 28, 2012employee
Wynnewood Refinery Incident
Loss Contingencies [Line Items]
Number of employees fatally injured	2

Business Segments - Additional

Business Segments - Additional Information (Details)	12 Months Ended
	Dec. 31, 2018segment
Segment Reporting [Abstract]
Number of operating segments	2
Number of reportable segments	2

Business Segments - Summary of

Business Segments - Summary of Operating Results and Capital Expenditures by Segment (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Net sales	$ 1,737	$ 1,935	$ 1,915	$ 1,536	$ 1,593	$ 1,454	$ 1,434	$ 1,507	$ 7,124	$ 5,988	$ 4,782
Operating income (loss)	138	$ 179	$ 121	$ 150	(36)	$ 61	$ 1	$ 80	587	107	70
Interest expense, net									(102)	(109)	(83)
Other income, net									15	2	2
Income (loss) before income taxes									500	0	(11)
Depreciation and amortization									213	214	193
Capital expenditures									102	120	133
Total assets	3,907				3,807				3,907	3,807	4,050
Operating Segments | Petroleum
Segment Reporting Information [Line Items]
Net sales									6,780	5,664	4,431
Operating income (loss)									599	134	58
Depreciation and amortization									134	133	129
Capital expenditures									79	101	102
Total assets	2,360				2,270				2,360	2,270	2,332
Operating Segments | Nitrogen Fertilizer
Segment Reporting Information [Line Items]
Net sales									351	331	356
Operating income (loss)									6	(10)	26
Depreciation and amortization									72	74	58
Capital expenditures									19	14	23
Total assets	1,254				1,234				1,254	1,234	1,312
Other
Segment Reporting Information [Line Items]
Net sales									(7)	(7)	(5)
Operating income (loss)									(18)	(17)	(14)
Depreciation and amortization									7	7	6
Capital expenditures									4	5	8
Total assets	$ 293				$ 303				$ 293	$ 303	$ 406

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Supplemental disclosures:
Cash paid for income taxes, net of refunds	$ 31	$ 15
Cash paid for interest	103	106
Non-cash investing and financing activities:
Construction in progress additions included in accounts payable	17	8
Change in accounts payable related to construction in progress additions	9	(5)
Landlord incentives for leasehold improvements	$ 0	$ 1

Related Party Transactions - Ex

Related Party Transactions - Expenses Incurred and Payments Made to Related Parties (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Cost of materials and other	$ 1,387	$ 1,556	$ 1,560	$ 1,179	$ 1,366	$ 1,149	$ 1,229	$ 1,209	$ 5,683	$ 4,953	$ 3,867
Dividends									238	174	174
Enable JV | Joint Venture Transportation Agreement
Related Party Transaction [Line Items]
Cost of materials and other									8	2	0
Amount paid to IEP
Related Party Transaction [Line Items]
Dividends									179	142	142
AEP | Tax Allocation Agreement
Related Party Transaction [Line Items]
Payments made									$ 12	$ 15	$ 45

Related Party Transactions - Pa

Related Party Transactions - Payables Due To/From Related Parties (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Tax Allocation Agreement | AEP
Related Party Transaction [Line Items]
Accounts Receivable (Payable)	$ 4	$ 5

Related Party Transactions - Na

Related Party Transactions - Narrative (Details) $ in Millions	Dec. 31, 2018sponsor	Jul. 31, 2018	Aug. 31, 2018	Dec. 31, 2018sponsor	Jun. 30, 2018USD ($)	Dec. 31, 2017USD ($)
Related Party Transaction [Line Items]
Minimum ownership interest in CVR Energy for eligibility to file as member of AEPC consolidated federal income tax group	80.00%			80.00%
Number of sponsors of pension plans | sponsor	2			2
Affiliate Pension Obligations
Related Party Transaction [Line Items]
Aggregate underfunded pension obligation if pension plans voluntarily terminated by affiliate | $					$ 435	$ 424
Majority Shareholder
Related Party Transaction [Line Items]
Ownership percentage held by controlling stockholder			71.00%
IEP Energy LLC | Majority Shareholder
Related Party Transaction [Line Items]
Ownership percentage held by controlling stockholder	71.00%	82.00%
AEPC | Majority Shareholder
Related Party Transaction [Line Items]
Minimum ownership interest in CVR Energy for eligibility to file as member of AEPC consolidated federal income tax group	80.00%			80.00%
Joint Venture Agreement | CVR Refining | Enable JV
Related Party Transaction [Line Items]
Initial term of agreement				20 years

Related Party Transactions - Di

Related Party Transactions - Dividends (Details) - USD ($) $ / shares in Units, $ in Millions	Mar. 11, 2019	Feb. 20, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Schedule Of Dividends Paid Table [Line Items]
Per common share (in dollars per share)			$ 0.75	$ 0.75	$ 0.5	$ 0.5	$ 0.5	$ 0.5	$ 0.5	$ 0.5						$ 2.5	$ 2	$ 2
Total dividends paid																$ 238	$ 174	$ 174
Total dividends paid per common share (in dollars per share)																$ 2.5	$ 2	$ 2
Cash dividends																$ 238	$ 174	$ 174
Subsequent Event
Schedule Of Dividends Paid Table [Line Items]
Per common share (in dollars per share)		$ 0.75
Cash dividends		$ 75
Amount paid to IEP
Schedule Of Dividends Paid Table [Line Items]
Total dividends paid																179	142	142
Amount paid to IEP | Subsequent Event
Schedule Of Dividends Paid Table [Line Items]
Cash dividends	$ 53
Amounts paid to public stockholders
Schedule Of Dividends Paid Table [Line Items]
Total dividends paid																$ 59	$ 32	$ 32
Quarterly
Schedule Of Dividends Paid Table [Line Items]
Total amount paid				$ 76	$ 75	$ 44	$ 43	$ 44	$ 43	$ 44	$ 43	$ 44	$ 43	$ 44	$ 43
Per common share (in dollars per share)				$ 0.75	$ 0.75	$ 0.5	$ 0.5	$ 0.5	$ 0.5	$ 0.5	$ 0.5	$ 0.5	$ 0.5	$ 0.5	$ 0.5
Quarterly | Amount paid to IEP
Schedule Of Dividends Paid Table [Line Items]
Total amount paid				$ 54	$ 53	$ 36	$ 36	$ 36	$ 35	$ 36	$ 35	$ 36	$ 35	$ 36	$ 35
Quarterly | Amounts paid to public stockholders
Schedule Of Dividends Paid Table [Line Items]
Total amount paid				$ 22	$ 22	$ 8	$ 7	$ 8	$ 8	$ 8	$ 8	$ 8	$ 8	$ 8	$ 8

Guarantor - Condensed Consolid

Guarantor - Condensed Consolidating Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 668	$ 482	$ 736	$ 765
Accounts receivable	169	179
Intercompany receivable	0	0
Inventories	380	369
Prepaid expenses and other current assets	76	48
Total current assets	1,293	1,078
Property, plant and equipment, net of accumulated depreciation	2,445	2,588
Investment in and advances from subsidiaries	0	0
Other long-term assets	169	141
Total assets	3,907	3,807	4,050
Current liabilities:
Note payable and capital lease obligations	3	2
Accounts payable	320	334
Intercompany payables	0	0
Other current liabilities	173	208
Total current liabilities	496	544
Long-term liabilities:
Long-term debt and capital lease obligations, net of current portion	1,167	1,164
Investment and advances from subsidiaries	0	0
Deferred income taxes	362	386
Other long-term liabilities	14	9
Total long-term liabilities	1,543	1,559
Commitments and contingencies
Equity:
Total CVR stockholders’ equity	1,246	919
Noncontrolling interest	622	785
Total equity	1,868	1,704	1,710	1,600
Total liabilities and equity	3,907	3,807
Intercompany Elimination
Current assets:
Cash and cash equivalents	0	0	0	0
Accounts receivable	0	0
Intercompany receivable	(10)	(17)
Inventories	0	0
Prepaid expenses and other current assets	(8)	(7)
Total current assets	(18)	(24)
Property, plant and equipment, net of accumulated depreciation	0	0
Investment in and advances from subsidiaries	(4,406)	(3,941)
Other long-term assets	0	0
Total assets	(4,424)	(3,965)
Current liabilities:
Note payable and capital lease obligations	0	0
Accounts payable	(1)	(1)
Intercompany payables	(10)	(17)
Other current liabilities	(7)	(6)
Total current liabilities	(18)	(24)
Long-term liabilities:
Long-term debt and capital lease obligations, net of current portion	0	0
Investment and advances from subsidiaries	(106)	(230)
Deferred income taxes	0	0
Other long-term liabilities	0	0
Total long-term liabilities	(106)	(230)
Commitments and contingencies
Equity:
Total CVR stockholders’ equity	(4,300)	(3,711)
Noncontrolling interest	0	0
Total equity	(4,300)	(3,711)
Total liabilities and equity	(4,424)	(3,965)
Parent | Reportable Legal Entities
Current assets:
Cash and cash equivalents	3	4	5	15
Accounts receivable	0	0
Intercompany receivable	6	9
Inventories	0	0
Prepaid expenses and other current assets	31	13
Total current assets	40	26
Property, plant and equipment, net of accumulated depreciation	0	0
Investment in and advances from subsidiaries	1,192	897
Other long-term assets	0	1
Total assets	1,232	924
Current liabilities:
Note payable and capital lease obligations	0	0
Accounts payable	1	1
Intercompany payables	0	0
Other current liabilities	6	12
Total current liabilities	7	13
Long-term liabilities:
Long-term debt and capital lease obligations, net of current portion	0	0
Investment and advances from subsidiaries	0	0
Deferred income taxes	(24)	(8)
Other long-term liabilities	3	0
Total long-term liabilities	(21)	(8)
Commitments and contingencies
Equity:
Total CVR stockholders’ equity	1,246	919
Noncontrolling interest	0	0
Total equity	1,246	919
Total liabilities and equity	1,232	924
Subsidiary Issuer | Reportable Legal Entities
Current assets:
Cash and cash equivalents	340	163	302	170
Accounts receivable	0	0
Intercompany receivable	0	0
Inventories	0	0
Prepaid expenses and other current assets	1	1
Total current assets	341	164
Property, plant and equipment, net of accumulated depreciation	0	0
Investment in and advances from subsidiaries	1,601	1,596
Other long-term assets	1	1
Total assets	1,943	1,761
Current liabilities:
Note payable and capital lease obligations	0	0
Accounts payable	0	0
Intercompany payables	0	0
Other current liabilities	7	5
Total current liabilities	7	5
Long-term liabilities:
Long-term debt and capital lease obligations, net of current portion	496	496
Investment and advances from subsidiaries	0	0
Deferred income taxes	0	0
Other long-term liabilities	0	0
Total long-term liabilities	496	496
Commitments and contingencies
Equity:
Total CVR stockholders’ equity	1,440	1,260
Noncontrolling interest	0	0
Total equity	1,440	1,260
Total liabilities and equity	1,943	1,761
Guarantor Subsidiaries | Reportable Legal Entities
Current assets:
Cash and cash equivalents	252	261	364	523
Accounts receivable	107	169
Intercompany receivable	4	8
Inventories	316	316
Prepaid expenses and other current assets	47	23
Total current assets	726	777
Property, plant and equipment, net of accumulated depreciation	1,425	1,513
Investment in and advances from subsidiaries	173	189
Other long-term assets	123	91
Total assets	2,447	2,570
Current liabilities:
Note payable and capital lease obligations	3	2
Accounts payable	291	310
Intercompany payables	0	0
Other current liabilities	62	151
Total current liabilities	356	463
Long-term liabilities:
Long-term debt and capital lease obligations, net of current portion	42	42
Investment and advances from subsidiaries	106	230
Deferred income taxes	0	0
Other long-term liabilities	7	4
Total long-term liabilities	155	276
Commitments and contingencies
Equity:
Total CVR stockholders’ equity	1,936	1,831
Noncontrolling interest	0	0
Total equity	1,936	1,831
Total liabilities and equity	2,447	2,570
Non-Guarantor Subsidiaries | Reportable Legal Entities
Current assets:
Cash and cash equivalents	73	54	$ 65	$ 57
Accounts receivable	62	10
Intercompany receivable	0	0
Inventories	64	53
Prepaid expenses and other current assets	5	18
Total current assets	204	135
Property, plant and equipment, net of accumulated depreciation	1,020	1,075
Investment in and advances from subsidiaries	1,440	1,259
Other long-term assets	45	48
Total assets	2,709	2,517
Current liabilities:
Note payable and capital lease obligations	0	0
Accounts payable	29	24
Intercompany payables	10	17
Other current liabilities	105	46
Total current liabilities	144	87
Long-term liabilities:
Long-term debt and capital lease obligations, net of current portion	629	626
Investment and advances from subsidiaries	0	0
Deferred income taxes	386	394
Other long-term liabilities	4	5
Total long-term liabilities	1,019	1,025
Commitments and contingencies
Equity:
Total CVR stockholders’ equity	924	620
Noncontrolling interest	622	785
Total equity	1,546	1,405
Total liabilities and equity	$ 2,709	$ 2,517

Guarantor - Condensed Consolida

Guarantor - Condensed Consolidated Statement of Operations (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Condensed Income Statements, Captions [Line Items]
Net sales	$ 1,737	$ 1,935	$ 1,915	$ 1,536	$ 1,593	$ 1,454	$ 1,434	$ 1,507	$ 7,124	$ 5,988	$ 4,782
Operating costs and expenses:
Cost of materials and other	1,387	1,556	1,560	1,179	1,366	1,149	1,229	1,209	5,683	4,953	3,867
Direct operating expenses (exclusive of depreciation and amortization shown below)	130	120	141	132	175	162	124	138	523	598	541
Depreciation and amortization									202	203	184
Cost of sales									6,408	5,754	4,592
Selling, general and administrative expenses									112	113	110
Depreciation and amortization									11	11	9
Loss on asset disposals									6	3	1
Operating income	138	179	121	150	(36)	61	1	80	587	107	70
Other income (expense):
Interest expense, net									(102)	(109)	(83)
Other income, net									15	2	2
Income (loss) from subsidiaries									0	0	0
Income (loss) before income taxes									500	0	(11)
Income tax expense (benefit)									89	(217)	(20)
Net income	106	121	80	104	173	25	(19)	38	411	217	9
Less: Net income (loss) attributable to noncontrolling interest	24	31	30	38	(27)	3	(8)	16	122	(18)	(16)
Net income attributable to CVR Energy stockholders	$ 82	$ 90	$ 50	$ 66	$ 200	$ 22	$ (11)	$ 22	289	235	25
Intercompany Elimination
Condensed Income Statements, Captions [Line Items]
Net sales									(6)	(8)	(6)
Operating costs and expenses:
Cost of materials and other									(6)	(8)	(6)
Direct operating expenses (exclusive of depreciation and amortization shown below)									0	0	0
Depreciation and amortization									0	0	0
Cost of sales									(6)	(8)	(6)
Selling, general and administrative expenses									0	0	0
Depreciation and amortization									0	0	0
Loss on asset disposals									0	0	0
Operating income									0	0	0
Other income (expense):
Interest expense, net									0	0	0
Other income, net									0	0	0
Income (loss) from subsidiaries									(1,446)	(490)	(143)
Income (loss) before income taxes									(1,446)	(490)	(143)
Income tax expense (benefit)									0	0	0
Net income									(1,446)	(490)	(143)
Less: Net income (loss) attributable to noncontrolling interest									0	0	0
Net income attributable to CVR Energy stockholders									(1,446)	(490)	(143)
Parent | Reportable Legal Entities
Condensed Income Statements, Captions [Line Items]
Net sales									0	0	0
Operating costs and expenses:
Cost of materials and other									0	0	0
Direct operating expenses (exclusive of depreciation and amortization shown below)									0	0	0
Depreciation and amortization									0	0	0
Cost of sales									0	0	0
Selling, general and administrative expenses									17	15	12
Depreciation and amortization									0	0	0
Loss on asset disposals									0	0	0
Operating income									(17)	(15)	(12)
Other income (expense):
Interest expense, net									0	0	0
Other income, net									0	0	5
Income (loss) from subsidiaries									303	246	26
Income (loss) before income taxes									286	231	19
Income tax expense (benefit)									(3)	(4)	(6)
Net income									289	235	25
Less: Net income (loss) attributable to noncontrolling interest									0	0	0
Net income attributable to CVR Energy stockholders									289	235	25
Subsidiary Issuer | Reportable Legal Entities
Condensed Income Statements, Captions [Line Items]
Net sales									0	0	0
Operating costs and expenses:
Cost of materials and other									0	0	0
Direct operating expenses (exclusive of depreciation and amortization shown below)									0	0	0
Depreciation and amortization									0	0	0
Cost of sales									0	0	0
Selling, general and administrative expenses									1	1	1
Depreciation and amortization									0	0	0
Loss on asset disposals									0	0	0
Operating income									(1)	(1)	(1)
Other income (expense):
Interest expense, net									(32)	(34)	(32)
Other income, net									0	0	0
Income (loss) from subsidiaries									611	184	103
Income (loss) before income taxes									578	149	70
Income tax expense (benefit)									0	0	0
Net income									578	149	70
Less: Net income (loss) attributable to noncontrolling interest									0	0	0
Net income attributable to CVR Energy stockholders									578	149	70
Guarantor Subsidiaries | Reportable Legal Entities
Condensed Income Statements, Captions [Line Items]
Net sales									6,779	5,665	4,432
Operating costs and expenses:
Cost of materials and other									5,601	4,876	3,780
Direct operating expenses (exclusive of depreciation and amortization shown below)									364	441	392
Depreciation and amortization									130	129	126
Cost of sales									6,095	5,446	4,298
Selling, general and administrative expenses									60	14	15
Depreciation and amortization									8	8	6
Loss on asset disposals									5	3	0
Operating income									611	194	113
Other income (expense):
Interest expense, net									(7)	(11)	(2)
Other income, net									9	1	0
Income (loss) from subsidiaries									(46)	(88)	(64)
Income (loss) before income taxes									567	96	47
Income tax expense (benefit)									0	0	0
Net income									567	96	47
Less: Net income (loss) attributable to noncontrolling interest									0	0	0
Net income attributable to CVR Energy stockholders									567	96	47
Non-Guarantor Subsidiaries | Reportable Legal Entities
Condensed Income Statements, Captions [Line Items]
Net sales									351	331	356
Operating costs and expenses:
Cost of materials and other									88	85	93
Direct operating expenses (exclusive of depreciation and amortization shown below)									159	157	149
Depreciation and amortization									72	74	58
Cost of sales									319	316	300
Selling, general and administrative expenses									34	83	82
Depreciation and amortization									3	3	3
Loss on asset disposals									1	0	1
Operating income									(6)	(71)	(30)
Other income (expense):
Interest expense, net									(63)	(64)	(49)
Other income, net									6	1	(3)
Income (loss) from subsidiaries									578	148	78
Income (loss) before income taxes									515	14	(4)
Income tax expense (benefit)									92	(213)	(14)
Net income									423	227	10
Less: Net income (loss) attributable to noncontrolling interest									122	(18)	(16)
Net income attributable to CVR Energy stockholders									$ 301	$ 245	$ 26

Guarantor - Condensed Consoli_2

Guarantor - Condensed Consolidated Statement of Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	$ 620	$ 168	$ 267
Cash flows from investing activities:
Capital expenditures	(102)	(120)	(133)
Acquisition of CVR Nitrogen, net of cash acquired	0	0	(64)
Investment in affiliates, net of return of investment	0	(76)	(5)
Other investing activities	2	0	1
Net cash provided by (used in) investing activities	(100)	(196)	(201)
Cash flows from financing activities:
Proceeds on issuance of 2023 Notes, net of original issue discount	0	0	629
Principal and premium payments on 2021 Notes	0	0	(322)
Payments of revolving debt	0	0	(49)
Principal payments on CRNF credit facility	0	0	(125)
CVR Energy shareholder dividends	(238)	(174)	(174)
Distributions or intercompany advances to other CVR Energy subsidiaries	0	0	0
Other financing activities	(3)	(3)	(12)
Net cash provided by (used in) financing activities	(334)	(226)	(95)
Net increase (decrease) in cash and cash equivalents	186	(254)	(29)
Cash and cash equivalents, beginning of period	482	736	765
Cash and cash equivalents, end of period	668	482	736
CVR Refining
Cash flows from investing activities:
Investment in affiliates, net of return of investment		(77)
Cash flows from financing activities:
Shareholder dividends/Unitholder distributions	(93)	(47)	0
CVR Partners
Cash flows from financing activities:
Shareholder dividends/Unitholder distributions	0	(2)	(42)
Intercompany Elimination
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	3	(10)	(13)
Cash flows from investing activities:
Capital expenditures	0	0	0
Acquisition of CVR Nitrogen, net of cash acquired			0
Investment in affiliates, net of return of investment	(1,946)	(1,636)	(570)
Other investing activities	0		0
Net cash provided by (used in) investing activities	(1,946)	(1,636)	(570)
Cash flows from financing activities:
Proceeds on issuance of 2023 Notes, net of original issue discount			0
Principal and premium payments on 2021 Notes			0
Payments of revolving debt			0
Principal payments on CRNF credit facility			0
CVR Energy shareholder dividends	0	0	0
Distributions or intercompany advances to other CVR Energy subsidiaries	1,943	1,646	583
Other financing activities	0	0	0
Net cash provided by (used in) financing activities	1,943	1,646	583
Net increase (decrease) in cash and cash equivalents	0	0	0
Cash and cash equivalents, beginning of period	0	0	0
Cash and cash equivalents, end of period	0	0	0
Intercompany Elimination | CVR Refining
Cash flows from financing activities:
Shareholder dividends/Unitholder distributions	0	0
Intercompany Elimination | CVR Partners
Cash flows from financing activities:
Shareholder dividends/Unitholder distributions		0	0
Parent | Reportable Legal Entities
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	38	(30)	(29)
Cash flows from investing activities:
Capital expenditures	(3)	(4)	(10)
Acquisition of CVR Nitrogen, net of cash acquired			0
Investment in affiliates, net of return of investment	202	207	214
Other investing activities	0		0
Net cash provided by (used in) investing activities	199	203	204
Cash flows from financing activities:
Proceeds on issuance of 2023 Notes, net of original issue discount			0
Principal and premium payments on 2021 Notes			0
Payments of revolving debt			0
Principal payments on CRNF credit facility			0
CVR Energy shareholder dividends	(238)	(174)	(174)
Distributions or intercompany advances to other CVR Energy subsidiaries	0	0	0
Other financing activities	0	0	(11)
Net cash provided by (used in) financing activities	(238)	(174)	(185)
Net increase (decrease) in cash and cash equivalents	(1)	(1)	(10)
Cash and cash equivalents, beginning of period	4	5	15
Cash and cash equivalents, end of period	3	4	5
Parent | Reportable Legal Entities | CVR Refining
Cash flows from financing activities:
Shareholder dividends/Unitholder distributions	0	0
Parent | Reportable Legal Entities | CVR Partners
Cash flows from financing activities:
Shareholder dividends/Unitholder distributions		0	0
Subsidiary Issuer | Reportable Legal Entities
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	(31)	(32)	(26)
Cash flows from investing activities:
Capital expenditures	0	0	0
Acquisition of CVR Nitrogen, net of cash acquired			0
Investment in affiliates, net of return of investment	630	1,083	227
Other investing activities	0		0
Net cash provided by (used in) investing activities	630	1,083	227
Cash flows from financing activities:
Proceeds on issuance of 2023 Notes, net of original issue discount			0
Principal and premium payments on 2021 Notes			0
Payments of revolving debt			0
Principal payments on CRNF credit facility			0
CVR Energy shareholder dividends	0	0	0
Distributions or intercompany advances to other CVR Energy subsidiaries	(422)	(1,190)	(69)
Other financing activities	0	0	0
Net cash provided by (used in) financing activities	(422)	(1,190)	(69)
Net increase (decrease) in cash and cash equivalents	177	(139)	132
Cash and cash equivalents, beginning of period	163	302	170
Cash and cash equivalents, end of period	340	163	302
Subsidiary Issuer | Reportable Legal Entities | CVR Refining
Cash flows from financing activities:
Shareholder dividends/Unitholder distributions	0	0
Subsidiary Issuer | Reportable Legal Entities | CVR Partners
Cash flows from financing activities:
Shareholder dividends/Unitholder distributions		0	0
Guarantor Subsidiaries | Reportable Legal Entities
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	687	273	380
Cash flows from investing activities:
Capital expenditures	(79)	(101)	(102)
Acquisition of CVR Nitrogen, net of cash acquired			0
Investment in affiliates, net of return of investment	679	112	(157)
Other investing activities	0		1
Net cash provided by (used in) investing activities	600	11	(258)
Cash flows from financing activities:
Proceeds on issuance of 2023 Notes, net of original issue discount			0
Principal and premium payments on 2021 Notes			0
Payments of revolving debt			0
Principal payments on CRNF credit facility			0
CVR Energy shareholder dividends	0	0	0
Distributions or intercompany advances to other CVR Energy subsidiaries	(1,202)	(338)	(280)
Other financing activities	(1)	(2)	(1)
Net cash provided by (used in) financing activities	(1,296)	(387)	(281)
Net increase (decrease) in cash and cash equivalents	(9)	(103)	(159)
Cash and cash equivalents, beginning of period	261	364	523
Cash and cash equivalents, end of period	252	261	364
Guarantor Subsidiaries | Reportable Legal Entities | CVR Refining
Cash flows from financing activities:
Shareholder dividends/Unitholder distributions	(93)	(47)
Guarantor Subsidiaries | Reportable Legal Entities | CVR Partners
Cash flows from financing activities:
Shareholder dividends/Unitholder distributions		0	0
Non-Guarantor Subsidiaries | Reportable Legal Entities
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	(77)	(33)	(45)
Cash flows from investing activities:
Capital expenditures	(20)	(15)	(21)
Acquisition of CVR Nitrogen, net of cash acquired			(64)
Investment in affiliates, net of return of investment	435	158	281
Other investing activities	2		0
Net cash provided by (used in) investing activities	417	143	196
Cash flows from financing activities:
Proceeds on issuance of 2023 Notes, net of original issue discount			629
Principal and premium payments on 2021 Notes			(322)
Payments of revolving debt			(49)
Principal payments on CRNF credit facility			(125)
CVR Energy shareholder dividends	0	0	0
Distributions or intercompany advances to other CVR Energy subsidiaries	(319)	(118)	(234)
Other financing activities	(2)	(1)	0
Net cash provided by (used in) financing activities	(321)	(121)	(143)
Net increase (decrease) in cash and cash equivalents	19	(11)	8
Cash and cash equivalents, beginning of period	54	65	57
Cash and cash equivalents, end of period	73	54	65
Non-Guarantor Subsidiaries | Reportable Legal Entities | CVR Refining
Cash flows from financing activities:
Shareholder dividends/Unitholder distributions	$ 0	0
Non-Guarantor Subsidiaries | Reportable Legal Entities | CVR Partners
Cash flows from financing activities:
Shareholder dividends/Unitholder distributions		$ (2)	$ (42)

Selected Quarterly Financial _3

Selected Quarterly Financial Information - Summarized Quarterly Financial Data (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
Net sales	$ 1,737	$ 1,935	$ 1,915	$ 1,536	$ 1,593	$ 1,454	$ 1,434	$ 1,507	$ 7,124	$ 5,988	$ 4,782
Cost of materials and other	1,387	1,556	1,560	1,179	1,366	1,149	1,229	1,209	5,683	4,953	3,867
Direct operating expenses (exclusive of depreciation and amortization shown below)	130	120	141	132	175	162	124	138	523	598	541
Operating income	138	179	121	150	(36)	61	1	80	587	107	70
Net income	106	121	80	104	173	25	(19)	38	411	217	9
Net income attributable to noncontrolling interest	24	31	30	38	(27)	3	(8)	16	122	(18)	(16)
Net income attributable to CVR Energy stockholders	$ 82	$ 90	$ 50	$ 66	$ 200	$ 22	$ (11)	$ 22	$ 289	$ 235	$ 25
Basic and diluted earnings per share (in dollars per share)	$ 0.82	$ 0.94	$ 0.59	$ 0.76	$ 2.31	$ 0.26	$ (0.12)	$ 0.26	$ 3.12	$ 2.70	$ 0.28
Dividends declared per share (in dollars per share)	$ 0.75	$ 0.75	$ 0.5	$ 0.5	$ 0.5	$ 0.5	$ 0.5	$ 0.5	$ 2.5	$ 2	$ 2
Weighted-average common shares outstanding - basic and diluted (in shares)	100.5	95.8	86.8	86.8	86.8	86.8	86.8	86.8	92.5	86.8	86.8